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US11692416

Wear resistant downhole piston

Feb 17, 2021

Anan Noel

SCHLUMBERGER TECHNOLOGY CORPORATION

NPL References not found.

2743781; May 1956; Lane; 2959225; November 1960; Roberts; 3989554; November 2, 1976; Wisler; 4015100; March 29, 1977; Gnanamuthu; 4194031; March 18, 1980; Cullum; 4690229; September 1, 1987; Raney; 4781770; November 1, 1988; Kar; 5511627; April 30, 1996; Anderson; 5535838; July 16, 1996; Keshavan; 5553678; September 10, 1996; Barr; 5819862; October 13, 1998; Matthias; 9085941; July 21, 2015; Hall et al.; 9200485; December 1, 2015; Eason; 10632713; April 28, 2020; Walker et al.; 10633924; April 28, 2020; Haugvaldstad; 20080164070; July 10, 2008; Keshavan; 20100044026; February 25, 2010; Head; 20100307838; December 9, 2010; Stevens; 20130068449; March 21, 2013; Pillai; 20130206390; August 15, 2013; Hall; 20150017394; January 15, 2015; Johnson; 20150132539; May 14, 2015; Bailey; 20150354290; December 10, 2015; Lakkashetti; 20170081944; March 23, 2017; Wang; 20180202233; July 19, 2018; Cleboski; 20180223435; August 9, 2018; Johnson; 20200332607; October 22, 2020; Panda

Foreign Citations not found.

['A piston for use in a rotary steerable system includes a body formed from a first material.', 'A sealing surface extends around the circumferential wall of the body.', 'The sealing surface is formed from a plurality of layers of a second material.', 'The second material is harder than the first material.', 'The piston can be within a downhole piston assembly that also includes a housing, and the piston being longitudinally movable in a bore in the housing.', 'A method for producing a piston includes preparing a piston formed from a first material, with the piston including a first end.', 'A sealing surface is applied to the piston using laser cladding, with the sealing surface including a second material harder than the first material.', 'The sealing surface is finished to a sealing surface diameter.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application claims the benefit of, and priority to, U.S. Patent Application No. 62/979,533, filed Feb. 21, 2020, which application is expressly incorporated herein by this reference in its entirety.', 'BACKGROUND\n \nRotary steerable systems (“RSS”) can include pistons that extend to engage with a wellbore wall.', 'Contact with the piston and the wellbore wall may help to change the trajectory of a bit.', 'The pistons may extend and retract through hundreds of thousands or millions of cycles during a single drilling run.', 'This may cause wear on the sealing surfaces of the pistons.', 'SUMMARY\n \nIn some embodiments, a piston for use in a downhole valve includes a body formed of a first material.', 'The body includes a first end, a second end, and a circumferential wall.', 'A sealing surface may extend around the circumferential wall.', 'The sealing surface is formed by laser cladding a second material to the body and is harder than the first material.', 'In some embodiments, the piston may be longitudinally movable in a housing bore.', 'The sealing surface may form a seal with the inner surface of the bore between the first end and the second end of the body.', 'In some embodiments, a method for manufacturing a piston includes preparing a piston having a first end.', 'The piston is formed from a first material.', 'A sealing surface is applied to the piston via laser cladding.', 'The sealing surface includes a second material that is harder than the first material.', 'The sealing surface is finished to a sealing surface diameter.', 'This summary is provided to introduce a selection of concepts that are further described in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Additional features and aspects of embodiments of the disclosure will be set forth herein, and in part will be obvious from the description, or may be learned by the practice of such embodiments.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'In order to describe the manner in which the above-recited and other features of the disclosure can be obtained, a more particular description will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings.', 'For better understanding, the like elements have been designated by like reference numbers throughout the various accompanying figures.', 'While some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale.', 'Understanding that the drawings depict some example embodiments, the embodiments will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:\n \nFIG.', '1\n is a representation of a drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '1\n-\n1\n is a representation of a bit and rotary steerable system, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n is a representation of a piston, according to at least one embodiment of the present disclosure;\n \nFIG.', '3\n-\n1\n and \nFIG.', '3\n-\n2\n are representations of another piston, according to at least one embodiment of the present disclosure;\n \nFIG.', '4\n is a representation of a piston receiving laser cladding, according to at least one embodiment of the present disclosure;\n \nFIG.', '5\n is a representation of yet another piston, according to at least one embodiment of the present disclosure;\n \nFIG.', '6\n is a representation of still another piston, according to at least one embodiment of the present disclosure;\n \nFIG.', '7\n is a representation of a further piston, according to at least one embodiment of the present disclosure;\n \nFIG.', '8\n-\n1\n is a representation of a piston assembly in the retracted position, according to at least one embodiment of the present disclosure;\n \nFIG.', '8\n-\n2\n is a representation of the piston assembly of \nFIG.', '8\n-\n1\n in the extended position; and\n \nFIG.', '9\n is a representation of a method for manufacturing a piston, according to at least one embodiment of the present disclosure.', 'DETAILED DESCRIPTION', 'This disclosure generally relates to devices, systems, and methods for wear resistant pistons for use in downhole drilling operations.', 'Downhole pistons include one or more wear and/or sealing surfaces.', 'The sealing surface engages the inner surface of a housing, and may form a tolerance seal with the inner surface.', 'During operation, the sealing surface may experience wear, which may cause the seal to lose integrity and may cause the piston to lose efficiency and/or break.', 'According to embodiments of the present disclosure, a piston may include a sealing surface made from a hard material applied using laser cladding.', 'This sealing surface may have a strong bond to the sealing surface.', 'Furthermore, the sealing surface may not experience any wear over hundreds of thousands of piston cycles, or may experience reduced wear such that the operational lifetime of the piston is increased.\n \nFIG.', '1\n shows one example of a drilling system \n100\n for drilling an earth formation \n101\n to form a wellbore \n102\n.', 'The drilling system \n100\n includes a drill rig \n103\n used to turn a drilling tool assembly \n104\n which extends downward into the wellbore \n102\n.', 'The drilling tool assembly \n104\n may include a drill string \n105\n, a bottomhole assembly (“BHA”) \n106\n, and a bit \n110\n, attached to the downhole end of drill string \n105\n.', 'The drill string \n105\n may include several joints of drill pipe \n108\n connected end-to-end through tool joints \n109\n.', 'The drill string \n105\n transmits drilling fluid through a central bore and transmits rotational power from the drill rig \n103\n to the BHA \n106\n.', 'In some embodiments, the drill string \n105\n may further include additional components such as subs, pup joints, etc.', 'The drill pipe \n108\n provides a hydraulic passage through which drilling fluid is pumped from the surface.', 'The drilling fluid discharges through selected-size nozzles, jets, or other orifices in the bit \n110\n for the purposes of cooling the bit \n110\n and cutting structures thereon, and for lifting cuttings out of the wellbore \n102\n as it is being drilled.', 'The BHA \n106\n may include the bit \n110\n or other components.', 'An example BHA \n106\n may include additional or other components (e.g., coupled between to the drill string \n105\n and the bit \n110\n).', 'Examples of additional BHA components include drill collars, stabilizers, measurement-while-drilling (“MWD”) tools, logging-while-drilling (“LWD”) tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'The BHA \n106\n may further include an RSS.', 'The RSS may include directional drilling tools that change a direction of the bit \n110\n, and thereby the trajectory of the wellbore.', 'At least a portion of the RSS may maintain a geostationary position relative to an absolute reference frame, such as gravity, magnetic north, and/or true north.', 'Using measurements obtained with the geostationary position, the RSS may locate the bit \n110\n, change the course of the bit \n110\n, and direct the directional drilling tools on a projected trajectory.', 'In general, the drilling system \n100\n may include other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves).', 'Additional components included in the drilling system \n100\n may be considered a part of the drilling tool assembly \n104\n, the drill string \n105\n, or a part of the BHA \n106\n depending on their locations in the drilling system \n100\n.', 'The bit \n110\n in the BHA \n106\n may be any type of bit suitable for degrading downhole materials.', 'For instance, the bit \n110\n may be a drill bit suitable for drilling the earth formation \n101\n.', 'Example types of drill bits used for drilling earth formations are fixed-cutter or drag bits.', 'In other embodiments, the bit \n110\n may be a mill used for removing metal, composite, elastomer, other materials downhole, or combinations thereof.', 'For instance, the bit \n110\n may be used with a whipstock to mill into casing \n107\n lining the wellbore \n102\n.', 'The bit \n110\n may also be a junk mill used to mill away tools, plugs, cement, other materials within the wellbore \n102\n, or combinations thereof.', 'Swarf or other cuttings formed by use of a mill may be lifted to surface, or may be allowed to fall downhole.', 'FIG.', '1\n-\n1\n is a perspective view of the downhole end of an embodiment of a bit \n110\n and connected RSS \n111\n.', 'The bit \n110\n may include a bit body \n113\n from which a plurality of blades \n115\n may protrude.', 'At least one of the blades \n115\n may have a plurality of cutting elements \n117\n connected thereto.', 'In some embodiments, at least one of the cutting elements may be a planar cutting element, such as a shear cutting element.', 'In other embodiments, at least one of the cutting elements may be a non-planar cutting element, such as a conical cutting element or a ridged cutting element.', 'The RSS \n111\n may include one or more steering devices \n119\n.', 'In some embodiments, the steering device \n119\n may include one or more pistons \n112\n that are actuatable to move in a radial direction from a longitudinal axis \n121\n of the bit \n110\n and RSS \n111\n.', 'In other embodiments, the steering device \n119\n may be or include an actuatable surface or ramp that moves in a radial direction from the longitudinal axis \n121\n.', 'The bit \n110\n and RSS \n111\n may rotate about the longitudinal axis \n121\n, and the one or more steering devices \n119\n may actuate in a timed manner with the rotation to urge the bit \n110\n in direction perpendicular to the longitudinal axis \n121\n.\n \nFIG.', '2\n is a representation of a piston \n212\n for a downhole drilling system (such as the piston \n112\n shown in \nFIG.', '1\n-\n1\n), according to at least one embodiment of the present disclosure.', 'The piston \n212\n may be any piston used in a downhole drilling system.', 'For example, the piston \n212\n may be the steering pad of a directional drilling system such as an RSS, or a steering pad of another tool.', 'In some examples, the piston \n212\n may be the piston in an expandable stabilizer or other expandable tool.', 'The piston \n212\n includes a body \n214\n.', 'The body \n214\n includes a first end \n216\n, a second end \n218\n, and a circumferential wall \n220\n.', 'In some embodiments, the piston \n212\n may be configured to extend in a longitudinal direction along the longitudinal axis \n224\n (e.g., the extension axis).', 'For example, the first end \n216\n may be a contact surface, and be configured to contact a wellbore wall.', 'The piston \n212\n may extend such that the first end \n216\n moves away from a housing along the longitudinal axis \n224\n toward the wellbore wall.', 'When the first end \n216\n contacts the wellbore wall, the first end \n216\n may push against the wellbore wall, thereby causing a bit to change direction and/or inclination.', 'In some embodiments, the body \n214\n may be cylindrical.', 'Thus, the transverse cross-sectional shape of the body \n214\n may be circular.', 'In some embodiments, the body \n214\n may have a transverse cross-sectional shape that is any shape, including elliptical, triangular (3-sided), square (4-sided), pentagonal (5-sided), hexagonal (6-sided), heptagonal (7-sided), octagonal (8-sided), 9-sided, 10-sided, polygonal of any number sides, irregularly shaped, or any other shape.', 'The circumferential wall \n220\n may extend around an entirety of the body \n214\n between the first end \n216\n and the second end \n218\n.', 'Thus, regardless of the number of sides that the transverse cross-sectional shape includes, the circumferential wall \n220\n may extend around the perimeter of the body between the first end \n216\n and the second end \n218\n.', 'The piston \n212\n shown includes a sealing surface \n222\n.', 'The sealing surface \n222\n may extend around the circumferential wall \n220\n.', 'In other words, the sealing surface \n222\n may extend around the perimeter of the body \n214\n between the first end \n216\n and the second end \n218\n.', 'The sealing surface \n222\n may be applied to the body \n214\n via laser cladding.', 'In other words, the sealing surface \n222\n is formed by laser cladding a sealing surface material to the body \n214\n.', 'Connecting the sealing surface \n222\n to the body \n214\n may provide a stronger connection between the sealing surface \n222\n and the body \n214\n, which may extend the life of the sealing surface and/or allow for different materials to be used for the sealing surface \n222\n.', 'The body \n214\n may be formed from a body material (e.g., a first material).', 'The sealing surface \n222\n may be formed from a sealing surface material (e.g., a second material).', 'In some embodiments, the body material may be different from the sealing surface material.', 'The body material may be different from the sealing surface material in one or more material properties.', 'For example, the body material may be different from the sealing surface material in at least one of chemical composition, particle size, particle hardness, particle density, particle shape, particle size ratio, binder material, any other material property, and combinations thereof.', 'In some embodiments, both the body material and the sealing surface material may include tungsten carbide particles.', 'However, the body material may be different from the sealing surface material because the body material may include a different binder, different particle size, different particle size distribution, additional non-tungsten carbide particles, or other material property differences.', 'In some embodiments, the sealing surface material may be different from the body material in any physical or chemical property.', 'In some embodiments, the body material may be any material, including infiltrated tungsten carbide, steel alloys, nickel alloys, any other material, or combinations thereof.', 'In some embodiments, the sealing surface material may be any material, including sintered tungsten carbide, nickel chromium alloys, hardened steel, or combinations thereof.', 'In some embodiments, the sealing surface material may be a TECHNOLASE® powder from TECHNOGENIA®.', 'For example, the sealing surface material may be TECHNOLASE® 40S, TECHNOLASE® 20S, TECHNOLASE® 30S, TECHNOLASE® 50S, TECHNOLASE® 60S, or any other powder or material from TECHNOGENIA®.', 'In some embodiments, the sealing surface material may be harder than the body material.', 'For example, the sealing surface material may have a hardness that is greater than 20 HRC, greater than 25 HRC, greater than 30 HRC, greater than 35 HRC, greater than 40 HRC, greater than 45 HRC, or greater than 50 HRC.', 'In some embodiments, it is critical that the sealing surface material has a hardness of greater than 40 HRC to prevent wear of the sealing surface during operation.', 'Conventionally, a layer of hardfacing may be connected to the body \n214\n via braze, weld, mechanical connector, other connection mechanism, or combinations thereof.', 'However, these connections may result in the hardfacing flaking, chipping, or otherwise removing from the body.', 'This may result in reduced performance of the piston and/or cause damage to the piston or other downhole components.', 'In contrast, in some embodiments, the sealing surface material may form a plurality of layers rather than a single layer of hardfacing via braze, weld, etc.', 'In some embodiments, laser cladding of the sealing surface \n222\n to the body \n214\n may provide a stronger bond between the sealing surface material and the body material than conventional connection mechanisms.', 'In some embodiments, laser cladding may occur at a higher temperature that conventional connection mechanisms.', 'This may result in the sealing surface material bonding to the hard particles of the body material and the binder, rather than only the binder.', 'Thus, in some embodiments, laser cladding of the sealing surface \n222\n to the body \n214\n may result in the sealing surface material bonding directly to tungsten carbide particles in the body \n214\n, which may result in a strong bond between the sealing surface \n222\n and the body \n214\n, thereby reducing the flaking and/or chipping of the sealing surface \n222\n from the body \n214\n, which may extend the operational life of the piston \n212\n.', 'In some embodiments, the sealing surface \n222\n may extend around the circumferential wall \n220\n such that the sealing surface \n222\n is perpendicular to the longitudinal axis \n224\n (e.g., the longest axis, the extension axis).', 'In this manner, the sealing surface \n222\n may be configured to engage the inner surface of a housing.', 'In some embodiments, the sealing surface \n222\n may be configured to form a tolerance seal between the inner surface of the housing and the sealing surface \n222\n (e.g., a seal based on a small gap between the inner surface of the housing and the sealing surface \n222\n).', 'By forming the sealing surface \n222\n from a hard material (e.g., with a hardness of greater than 40 HRC), the sealing surface \n222\n may experience reduced wear over repeated (e.g., over 100,000) cycles of extension and retraction in the housing.', 'This may increase the operational life and/or the efficiency of the piston \n212\n.', 'In some embodiments, the sealing surface \n222\n may be circumferentially continuous.', 'In other words, the sealing surface \n222\n may extend around an entirety of the circumferential wall \n220\n such that there are no gaps around the circumference of the sealing surface \n222\n.', 'This may help the sealing surface \n222\n to form a seal with a housing.', 'In some embodiments, the sealing surface \n222\n may be longitudinally offset from the first end \n216\n and/or the second end \n218\n.', 'For example, the sealing surface \n222\n includes an outer edge \n226\n and an inner edge \n228\n.', 'The piston \n212\n has a piston length \n230\n from the first end \n216\n to the second end.', 'In some embodiments, the outer edge \n226\n of the sealing surface \n222\n is located (e.g., longitudinally offset) an outer edge distance \n232\n from the first end \n216\n.', 'In some embodiments, the outer edge distance \n232\n may be zero.', 'In other words, the outer edge \n226\n may be located at the first end \n216\n.', 'Thus, the sealing surface \n222\n may extend to the first end \n216\n, or be flush with the first end \n216\n.', 'In some embodiments, the outer edge distance \n232\n may be an outer edge percentage of the piston length \n230\n (e.g., the outer edge distance \n232\n divided by the piston length \n230\n).', 'In some embodiments, the outer edge percentage may be in a range having a lower value, an upper value, or lower and upper values including any of 1%, 5%, 10%, 20%, 25%, 30%, 40%, 50%, 60%, 70%, 80%, 90%, or any value therebetween.', 'For example, the outer edge percentage may be greater than 1%.', 'In another example, the outer edge percentage may be less than 90%.', 'In yet other examples, the outer edge percentage may be any value in a range between 1% and 90%.', 'In some embodiments, it may be critical that the outer edge percentage is greater than 10% to allow the sealing surface \n222\n to engage the housing in the retracted position and thereby prevent waste.', 'In some embodiments, the inner edge \n228\n may be located (e.g., longitudinally offset) an inner edge distance \n234\n from the second end \n218\n.', 'In some embodiments, the inner edge distance \n234\n may be zero.', 'In other words, the inner edge \n228\n may be located at the second end \n218\n.', 'Thus, the sealing surface \n222\n may extend to the second end \n218\n, or be flush with the second end \n218\n.', 'In some embodiments, the inner edge distance \n234\n may be an inner edge percentage of the piston length \n230\n (e.g., the inner edge distance \n234\n divided by the piston length \n230\n).', 'In some embodiments, the inner edge percentage may be in a range having a lower value, an upper value, or lower and upper values including any of 1%, 5%, 10%, 20%, 25%, 30%, 40%, 50%, 60%, 70%, 80%, 90%, or any value therebetween.', 'For example, the inner edge percentage may be greater than 1%.', 'In another example, the inner edge percentage may be less than 90%.', 'In yet other examples, the inner edge percentage may be any value in a range between 1% and 90%.', 'In some embodiments, it may be critical that the inner edge percentage is less than 30% to support the body \n214\n of the piston \n212\n when the piston \n212\n is in the extended position.', 'The sealing surface \n222\n includes a sealing surface length \n236\n, which may be the distance between the outer edge \n226\n and the inner edge \n228\n.', 'The sealing surface length \n236\n may be a sealing percentage of the piston length \n230\n (e.g., the sealing surface length \n236\n divided by the piston length \n230\n).', 'In some embodiments, the sealing percentage may be in a range having a lower value, an upper value, or lower and upper values including any of 5%, 10%, 15%, 20%, 25%, 30%, 40%, 50%, 60%, 70%, 75%, 80%, 85%, 90%, 95%, or any value therebetween.', 'For example, the sealing percentage may be greater than 5%.', 'In another example, the sealing percentage may be less than 95%.', 'In yet other examples, the sealing percentage may be any value in a range between 5% and 95%.', 'In some embodiments, it may be critical that the sealing percentage is greater than 30% to provide a seal with the inner surface of the housing.', 'The body \n214\n of the piston \n212\n has a body diameter \n238\n.', 'The sealing surface \n222\n has a sealing surface diameter \n240\n.', 'In some embodiments, the sealing surface diameter \n240\n may be larger than the body diameter \n238\n.', 'In other words, the sealing surface \n222\n may be applied to an outside of the body \n214\n.', 'In some embodiments, the sealing surface \n222\n has a diameter percentage (e.g., the sealing surface diameter \n240\n divided by the body diameter \n238\n) that is greater than 100%.', 'In some embodiments, the diameter percentage may be in a range having a lower value, an upper value, or lower and upper values including any of 101%, 102%, 103%, 104%, 105%, 106%, 107%, 108%, 109%, 110%, or any value therebetween.', 'For example, the diameter percentage may be greater than 101%.', 'In another example, the diameter percentage may be less than 110%.', 'In yet other examples, the diameter percentage may be any value in a range between 101% and 110%.', 'In some embodiments, the sealing surface diameter \n240\n may be equal to the body diameter \n238\n.\n \nFIG.', '3\n-\n1\n is a representation of a piston \n312\n, according to at least one embodiment of the present disclosure.', 'In some embodiments, the sealing surface \n322\n may be applied to the body \n314\n with one or more layers \n342\n.', 'The circumferential wall \n320\n of the body \n314\n may be prepared prior to deposition of the layers \n342\n.', 'For example, the circumferential wall \n320\n of the body \n314\n may be machined (e.g., ground) to a preparation diameter.', 'A powder containing the sealing surface material may be directed to the circumferential wall and a laser may bind the powder to the body \n314\n as the sealing surface \n322\n.', 'The one or more layers \n342\n have a layer thickness \n343\n.', 'In some embodiments, the layer thickness \n343\n may be in a range having a lower value, an upper value, or lower and upper values including any of 1.0 mm, 1.5 mm, 2.0 mm, 2.5 mm, 3.0 mm, 3.5 mm, 4.0 mm, 4.5 mm, 5.0 mm, 6 mm, 7 mm, 8 mm, 9 mm, 10 mm, or any value therebetween.', 'For example, the layer thickness \n343\n may be greater than 1.0 mm.', 'In another example, the layer thickness \n343\n may be less than 10.0 mm.', 'In yet other examples, the layer thickness \n343\n may be any value in a range between 1.0 mm and 10.0 mm.', 'In the view shown in \nFIG.', '3\n-\n1\n, a single layer \n342\n of the sealing surface \n322\n has been applied to the body \n314\n.', 'In some embodiments, the single layer \n342\n may be the beginning of a plurality of layers \n342\n which may form the sealing surface \n322\n.', 'In some embodiments, the single layer \n342\n may form the entirety of the sealing surface \n322\n. \nFIG.', '3\n-\n2\n is a representation of the piston \n312\n of \nFIG.', '3\n-\n1\n that includes a sealing surface \n322\n that is formed from a plurality of layers (collectively \n342\n).', 'In some embodiments, each layer \n342\n of the plurality of layers \n342\n is formed from the same material.', 'In some embodiments, different layers \n342\n may be formed from different materials.', 'In some embodiments, the layers \n342\n may be formed longitudinally.', 'In other words, the layers \n342\n may each form a ring around the circumferential wall \n320\n.', 'Subsequent layers \n342\n may be formed longitudinally along the circumferential wall \n320\n.', 'For example, a first layer \n342\n-\n1\n may initially be deposited on the body \n314\n.', 'A second layer \n342\n-\n2\n may be deposited on the body \n314\n longitudinally offset from the first layer \n342\n-\n1\n such that the second layer \n342\n-\n2\n is longitudinally adjacent the first layer \n342\n-\n1\n on the side of the first end \n316\n.', 'A third layer \n342\n-\n3\n, fourth layer \n342\n-\n4\n, fifth layer \n342\n-\n5\n, and a plurality of other layers \n342\n may be deposited longitudinally adjacent the subsequent layers \n342\n.', 'In this manner, the sealing surface \n322\n may form a solid surface perpendicular to the longitudinal axis \n324\n.', 'It should be understood that subsequent adjacent layers \n342\n may be formed in the direction of the second end \n318\n.', 'In the embodiment shown in \nFIG.', '3\n-\n1\n and \nFIG.', '3\n-\n2\n, the layers \n342\n are shown as continuous, distinct, and individual rings around the circumferential wall of the body \n314\n.', 'However, it should be understood that the sealing surface \n322\n may be formed using any layer type geometry.', 'For example, the sealing surface \n322\n may be formed from a single continuous spiral (e.g., helical) that circles the body \n314\n one or more times to form the sealing surface \n322\n.', 'In some examples, the sealing surface \n322\n may be formed from a plurality of longitudinal layers that extend along the body \n314\n parallel to the longitudinal axis \n324\n, with each layer being arranged circumferentially adjacent to the other layers.', 'In this manner, the layers may resemble strips of the sealing surface material that extend between the first end \n316\n and the second end \n318\n.\n \nFIG.', '4\n is a representation of close-up view of a piston \n412\n that is having a sealing surface \n422\n deposited on the circumferential wall \n420\n of a body \n414\n, according to at least one embodiment of the present disclosure.', 'In the embodiment shown, a first layer \n442\n has been deposited, and a second layer is in the process of being deposited on the body \n414\n.', 'A nozzle \n444\n may be directed over the circumferential wall \n420\n.', 'The nozzle \n444\n may receive material powder \n446\n from a powder source (e.g., a powder feeder that directs powder to the nozzle).', 'The nozzle \n444\n may direct the material powder \n446\n at the circumferential wall \n420\n adjacent to the first layer \n442\n.', 'The nozzle may further direct a laser beam \n448\n (from a laser, such as a diode laser) at the material powder \n446\n.', 'The laser beam \n448\n may heat the material powder \n446\n and/or the body material of the body \n414\n at the circumferential wall \n420\n.', 'This may cause the material powder \n446\n to bond to the circumferential wall \n420\n.', 'For example, bonding of the material powder \n446\n may occur by partially or fully melting the material powder \n446\n and/or a portion of the body \n414\n at the circumferential wall \n420\n.', 'The materials of the partially or fully melted material powder \n446\n and body \n414\n may adhere (e.g., mix, sinter), and, when solidified, the material powder \n446\n may be bonded to the body \n414\n as a layer \n442\n of the sealing surface \n422\n.', 'In some embodiments, at least a portion of the material powder \n446\n may adhere to at least a portion of the first layer \n442\n.', 'In some embodiments, the body \n414\n of the piston \n412\n may be connected to a multi-axis controller, which may cause the body \n414\n to move relative to the nozzle \n444\n.', 'For example, the body \n414\n may be rotated about the longitudinal axis (e.g., longitudinal axis \n224\n of \nFIG.', '2\n) relative to the nozzle \n444\n.', 'In some embodiments, the body \n414\n may be moved longitudinally relative to the nozzle \n444\n (e.g., parallel to the longitudinal axis \n224\n toward the first end \n216\n or the second end \n218\n of \nFIG.', '2\n).', 'In some embodiments, the body \n414\n may be moved longitudinally and rotated relative to the nozzle \n444\n.', 'In some embodiments, the body \n414\n may be moved in any direction relative to the nozzle \n444\n, including perpendicular to the longitudinal axis, rotated transverse to the longitudinal axis, any other direction, and combinations thereof.', 'Thus, as the nozzle \n444\n continuously deposits material powder \n446\n and directs the laser beam \n448\n at the material powder \n446\n, a new layer may be formed adjacent to the first layer \n442\n.', 'In some embodiments, the nozzle \n444\n may move relative to the body \n414\n to deposit the layer.', 'For example, the nozzle \n444\n may be rotated, moved longitudinally, moved radially, otherwise moved or rotated, or combinations thereof, relative to the body \n414\n.\n \nFIG.', '5\n is a representation of a piston \n512\n including a plurality of sealing surfaces (collectively \n522\n), according to at least one embodiment of the present disclosure.', 'In the embodiment shown, the piston \n512\n includes a first sealing surface \n522\n-\n1\n and a second sealing surface \n522\n-\n2\n.', 'The first sealing surface \n522\n-\n1\n may be located on the body \n514\n closer to the first end \n516\n than the second sealing surface \n522\n-\n2\n.', 'Similarly, the second sealing surface \n522\n-\n2\n may be located on the body closer to the second end \n518\n than the first sealing surface \n522\n-\n1\n.', 'In the embodiment shown, the first sealing surface \n522\n-\n1\n is longitudinally offset from the second sealing surface \n522\n-\n2\n.', 'Accordingly, the first sealing surface \n522\n-\n1\n is separate and distinct from the second sealing surface \n522\n-\n2\n.', 'The first sealing surface \n522\n-\n1\n may be separated from the second sealing surface \n522\n-\n2\n by at least a portion of the circumferential wall \n520\n of the body \n514\n.', 'Two sealing surfaces \n522\n may increase the stability of the piston \n512\n during actuation.', 'This may help to prevent tilting or other lateral movement of the piston \n512\n relative to a housing during operation.', 'Preventing tilting and other lateral movement may help prevent binding (e.g., getting stuck) of the piston \n512\n in the housing.', 'This may improve the reliability of the piston \n512\n and/or extend the operating life of the piston \n512\n.', 'Furthermore, while the same stability benefit may be provided by a continuous sealing surface \n522\n (e.g., continuous between the first sealing surface \n522\n-\n1\n and the second sealing surface \n522\n-\n2\n), including two sealing surfaces may provide stability while reducing the amount of sealing surface material used, thereby reducing manufacturing costs.', 'In some embodiments, one or both of the sealing surfaces \n522\n may be circumferentially continuous.', 'A circumferentially continuous sealing surface \n522\n may not include any gaps around the circumference of the body \n514\n.', 'In some embodiments, the second sealing surface \n522\n-\n2\n may be circumferentially continuous, and the first sealing surface \n522\n-\n1\n may not be circumferentially continuous.', 'For example, the first sealing surface \n522\n-\n1\n may include gaps.', 'This may help to reduce the amount of sealing surface material used, which may help to reduce manufacturing costs.', 'In this manner, the second sealing surface \n522\n-\n2\n may provide a seal for the piston \n512\n, and the first sealing surface \n522\n-\n1\n may help to guide and support the piston \n512\n during actuation.', 'In some embodiments, the first sealing surface \n522\n-\n1\n may be circumferentially continuous and the second sealing surface \n522\n-\n2\n may not be circumferentially continuous.\n \nFIG.', '6\n is a representation of a piston \n612\n including a piston bore \n650\n.', 'The piston bore \n650\n may extend through the body \n614\n of the piston \n612\n.', 'The piston bore \n650\n may be configured to receive a pin from a housing.', 'The pin may extend into the piston bore \n650\n.', 'During retraction (e.g., in the retracted position), the pin (shown schematically in dashed lines at position \n653\n-\n1\n) may contact a bore first end \n652\n.', 'This may help to retain the piston \n612\n in the retracted position and prevent the piston \n612\n from over-retracting.', 'During extension (e.g., in the extended position), the pin (shown schematically in dashed lines at position \n653\n-\n2\n) may contact a bore second end \n654\n.', 'This may help to retain the piston \n612\n in the extended position and prevent the piston \n612\n from over-extending.', 'The piston \n612\n shown includes a first sealing surface \n622\n-\n1\n and a second sealing surface \n622\n-\n2\n.', 'The first sealing surface \n622\n-\n1\n may be located at or near the bore first end \n652\n.', 'The second sealing surface \n622\n-\n2\n may be located at or near the bore second end \n654\n.', 'In some embodiments, the first sealing surface \n622\n-\n1\n may longitudinally extend past the bore first end \n652\n.', 'In some embodiments, the first sealing surface \n622\n-\n1\n may be offset from the bore first end \n652\n.', 'In some embodiments, the second sealing surface \n622\n-\n2\n may longitudinally extend past the bore second end \n654\n.', 'In some embodiments, the second sealing surface \n622\n-\n2\n may be offset from the bore second end \n654\n.', 'As discussed above, one or both of the first sealing surface \n622\n-\n1\n and the second sealing surface \n622\n-\n2\n may be circumferentially continuous.', 'A circumferentially continuous second sealing surface \n622\n-\n2\n may help to seal the piston bore \n650\n from drilling and/or actuation fluid that acts on the second end \n618\n to extend the piston \n612\n.', 'This may help to reduce damage to the piston \n612\n at the piston bore \n650\n and/or reduce damage to the pin that extends into the piston bore.', 'In some embodiments, a circumferentially continuous first sealing surface \n622\n-\n1\n may help to seal the piston bore \n650\n from cuttings and/or drilling fluid that may travel into the piston bore \n650\n during drilling and/or steering operations.', 'This may help to reduce wear on the piston bore \n650\n and/or the pin extending into the piston bore \n650\n, thereby increasing the operational lifetime of the piston \n612\n.\n \nFIG.', '7\n is a representation of a piston \n712\n including wear surfaces \n756\n on the first end \n716\n, according to at least one embodiment of the present disclosure.', 'In some embodiments, the piston \n712\n may extend along the longitudinal axis \n724\n (e.g., the extension axis) such that the first end \n716\n moves out of a housing.', 'The first end \n716\n may engage a wellbore wall and impart a force against the wellbore wall to change a trajectory of the bit.', 'In some embodiments, the first end \n716\n may include one or more wear surfaces \n756\n.', 'The wear surfaces \n756\n may be formed from a wear and/or erosion resistant material to reduce wear when contacting the wellbore wall.', 'In some embodiments, the wear surfaces \n756\n may be formed by laser cladding, as discussed herein, especially with reference to \nFIG.', '3\n-\n1\n through \nFIG.', '4\n, and the associated description.', 'In this manner, the wear surfaces \n756\n may be formed with a hard material that has a high bonding strength to the body \n714\n.', 'In some embodiments, the first end \n716\n may be planar.', 'In some embodiments, the first end \n716\n may be contoured or otherwise have a shape that is not planar.', 'For example, the first end \n716\n may include a convex shape that is configured to match the profile of the wellbore wall.\n \nFIG.', '8\n-\n1\n is a representation of a piston assembly \n858\n in a retracted position, according to at least one embodiment of the present disclosure.', 'In the retracted position shown, the piston assembly \n858\n includes a piston \n812\n inserted into the bore \n860\n of a housing \n862\n.', 'The piston \n812\n may include one or more sealing surfaces (collectively \n822\n).', 'The sealing surfaces \n822\n engage an inner surface \n864\n of the bore \n860\n.', 'In some embodiments, at least one of the sealing surfaces \n822\n may form a tolerance seal with the inner surface \n864\n of the bore \n860\n.', 'The tolerance seal between the sealing surfaces \n822\n and the inner surface \n864\n may be formed via a gap \n866\n between the outer diameter of the sealing surface (e.g., the sealing surface diameter \n240\n of \nFIG.', '2\n) and the inner diameter of the bore \n860\n.', 'In some embodiments, the gap \n866\n may be small enough that debris and/or fluid may not pass between the sealing surface \n822\n and the inner surface \n864\n.', 'For example, the gap \n866\n may be less than 1 mm, less than 0.5 mm, less than 0.1 mm, less than 0.05 mm, less than 0.04 mm, less than 0.03 mm, or less than 0.02 mm.', 'In some embodiments, a seal formed by the gap \n866\n may not require any additional sealing element, such as an O-ring or other sealing element.', 'This may increase the simplicity of the piston assembly \n858\n.', 'The extend the piston \n812\n, a force, such as fluid pressure, may be applied to the second end \n818\n of the piston \n812\n.', 'This may cause the first end \n816\n of the piston \n812\n to extend out of the housing \n862\n to the extended position shown in \nFIG.', '8\n-\n2\n.', 'In the extended position of the piston assembly \n858\n shown in \nFIG.', '8\n-\n2\n, the first end \n816\n may be extended past an outer surface \n868\n of the housing \n862\n.', 'In some embodiments, in the extended position the first sealing surface \n822\n-\n1\n may remain in the bore \n860\n.', 'Thus, at least a portion of the first sealing surface \n822\n-\n1\n may remain in contact with the inner surface \n864\n in the extended position.', 'Accordingly, the inner edge \n828\n of the first sealing surface \n822\n-\n1\n may remain in the bore \n860\n (e.g., closer to a longitudinal axis of the downhole tool than the outer surface \n868\n of the housing \n862\n).', 'In some embodiments, the first sealing surface \n822\n-\n1\n may not engage the inner surface \n864\n in the extended position.', 'In some embodiments, the second sealing surface \n822\n-\n2\n may remain in the housing \n862\n in the extended position.', 'In this manner, the second sealing surface \n822\n-\n2\n may stabilize the piston \n812\n in the housing \n862\n.', 'This may help the piston \n812\n maintain its orientation, and prevent binding, catching, tilting, or other non-desirable movement from the piston \n812\n.', 'In some embodiments, in the extended position, both the first sealing surface \n822\n-\n1\n and the second sealing surface \n822\n-\n2\n may remain in the bore \n860\n of the housing \n862\n.', 'To retract the position from the extended position shown in \nFIG.', '8\n-\n2\n to the retracted position shown in \nFIG.', '8\n-\n1\n, the fluid pressure pushing against the piston \n812\n may be reduced, and the force from the wellbore wall pushing against the first end \n816\n of the piston \n812\n may push the piston \n812\n back into the housing.', 'A single extension and retraction of the piston \n812\n may be considered a cycle.', 'While cycling of the piston \n812\n, the sealing surface \n822\n may contact the inner surface \n864\n of the bore \n860\n.', 'Repeated cycling may cause one or both of the sealing surface \n822\n and the inner surface \n864\n to experience wear.', 'In some embodiments, the inner surface \n864\n may include a hard material, such as sintered tungsten carbide.', 'As discussed above, the sealing surface \n822\n may be formed from a hard material, deposited by laser cladding.', 'Because the sealing surface \n822\n and the inner surface \n864\n are both formed from hard materials, the piston assembly \n858\n may be wear resistant.', 'For example, the piston assembly \n858\n may be able to experience 100,000 cycles, 200,000 cycles, 300,000 cycles, 400,000 cycles, 500,000 cycles, 600,000 cycles, 700,000 cycles, 800,000 cycles, 900,000 cycles, 1,000,000 cycles, or more cycles, without experiencing a reduction in diameter (e.g., mass) of the sealing surface \n822\n and/or the inner surface \n864\n.', 'In some embodiments, at least a portion of the inner surface \n864\n may have laser cladding applied to it.', 'In this manner, the inner surface \n864\n and the sealing surface \n822\n may both be formed same process and may include the same material.', 'This may further help to reduce wear on the sealing surface \n822\n and/or the inner surface \n864\n.\n \nFIG.', '9\n is a representation of a method \n970\n for manufacturing a piston, according to at least one embodiment of the present disclosure.', 'The method \n970\n may include preparing a piston at \n972\n.', 'In some embodiments, preparing the piston may include forming the piston.', 'In some embodiments, the piston may be formed by placing matrix material (such as tungsten carbide powder).', 'A binder material (e.g., an infiltrant) may be melted and allowed to flow into the matrix material.', 'Preparing the piston may further include preparing the surface of the circumferential wall of the body of the piston.', 'For example, the circumferential wall may be machined or ground to a prepared diameter.', 'The method \n970\n may further include applying a sealing surface to the piston at \n974\n.', 'The sealing surface may be applied to the piston by laser cladding.', 'Laser cladding may include applying a sealing surface material to the circumferential wall of the body.', 'A laser may partially or fully melt the sealing surface material and/or the circumferential wall of the piston, and the particles may bond to each other and the circumferential wall.', 'The sealing surface material may be harder than the matrix material bound by the binder of the piston body.', 'In some embodiments, applying the sealing surface may include applying the sealing surface in a plurality of longitudinally adjacent layers.', 'The method \n970\n may further include finishing the sealing surface to a sealing surface diameter at \n976\n.', 'In some embodiments, finishing the sealing surface may include finishing the sealing surface to a sealing surface diameter tolerance of 0.02 mm.', 'In some embodiments, the sealing surface diameter tolerance may be in a range having a lower value, an upper value, or lower and upper values including any of 0.1 mm, 0.09 mm, 0.08 mm, 0.07 mm, 0.06 mm, 0.05 mm, 0.04 mm, 0.03 mm, 0.02 mm, 0.01 mm, or any value therebetween.', 'For example, the sealing surface diameter tolerance may be greater than 0.01 mm.', 'In another example, the sealing surface diameter tolerance may be less than 0.1 mm.', 'In yet other examples, the sealing surface diameter tolerance may be any value in a range between 0.1 mm and 0.01 mm.', 'In some embodiments, it may be critical that the sealing surface diameter tolerance is less than or equal to 0.02 mm to enable the sealing surface to seal against the inner surface of the housing.', 'In some embodiments, the method may include using laser cladding to apply other hard or wear surfaces.', 'For example, laser cladding may be used to apply a wear surface to a contact end of the piston.', 'This may help to extend the life of the piston.', 'The embodiments of the downhole piston have been primarily described with reference to wellbore drilling operations; the downhole pistons described herein may be used in applications other than the drilling of a wellbore.', 'In other embodiments, downhole pistons according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources.', 'For instance, downhole pistons of the present disclosure may be used in a borehole used for placement of utility lines.', 'Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.', 'One or more specific embodiments of the present disclosure are described herein.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that is within standard manufacturing or process tolerances, or which still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.']

['1.', 'A piston for use in a downhole tool, comprising:\na body formed of a first material, the body including a first end, a second end, and a circumferential wall;\na radially outwardly facing, circumferential sealing surface formed by laser cladding a second material to the body extending around the circumferential wall, the second material being harder than the first material, the circumferential sealing surface having a sealing surface diameter, the sealing surface diameter having a tolerance of less than or equal to 0.02 mm; and\na housing including a housing bore and an inner surface, the body being positioned at least partially in the housing bore and the circumferential sealing surface of the second material forming a tolerance seal between the inner surface and the circumferential sealing surface.', '2.', 'The piston of claim 1, wherein the first material comprises an infiltrated tungsten carbide matrix and the second material is different than the first material.', '3.', 'The piston of claim 2, wherein the infiltrated tungsten carbide matrix comprises a plurality of tungsten carbide particles and the second material is bonded to the plurality of tungsten carbide particles.', '4.', 'The piston of claim 2, wherein the second material is different from the first material in at least one of chemical composition, particle size, particle hardness, particle density, particle shape, or particle size ratio.', '5.', 'The piston of claim 1, wherein the second material is a tungsten carbide material having a hardness that is greater than 40 HRC.\n\n\n\n\n\n\n6.', 'The piston of claim 1, wherein the circumferential sealing surface includes a plurality of layers of the second material, the plurality of layers being longitudinally adjacent to and adhered to one another.\n\n\n\n\n\n\n7.', 'The piston of claim 1, wherein the body has a body diameter, and the sealing surface diameter is larger than the body diameter.', '8.', 'The piston of claim 1, wherein the first end includes a contact surface and the contact surface includes the second material.', '9.', 'A downhole piston assembly, comprising:\na piston, the piston including: a body including a first end, a second end, a circumferential wall, and an extension axis, the body having a first diameter and including a first material; and a sealing surface formed by laser cladding extending around the circumferential wall, the sealing surface being perpendicular to the extension axis, the sealing surface being a radially outwardly facing circumferential surface having a second diameter greater than the first diameter, the sealing surface having an outer edge at an outer edge distance relative to the first end of the body and having an inner edge distance relative to the second end of the body, the outer edge distance being between 10% and 50% of a length of the piston and the inner edge distance being less than 30% and greater than 0% of the length of the piston, the sealing surface including a second material, the second material being harder than the first material; and\na housing including a housing bore and an inner surface, the piston being longitudinally movable in the housing bore along the extension axis, the sealing surface forming a tolerance seal between the inner surface of the housing and the sealing surface of the second material.\n\n\n\n\n\n\n10.', 'The downhole piston assembly of claim 9, wherein the inner surface is formed from sintered tungsten carbide.', '11.', 'The downhole piston assembly of claim 9, wherein the sealing surface is a first sealing surface and further comprising a second sealing surface offset from the first sealing surface.', '12.', 'The downhole piston assembly of claim 11, the body including a piston bore transverse to the extension axis of the body, the second sealing surface being located between the piston bore and the second end.', '13.', 'The downhole piston assembly of claim 12, the housing including a pin extending at least partially into the piston bore.', '14.', 'The downhole piston assembly of claim 9, the sealing surface including at least first and second longitudinally offset sealing surfaces, with the first sealing surface being nearest the first end of the body and the second sealing surface nearest the second end of the body, the second end being radially inward relative to the first end along the extension axis, wherein the body further includes:\na piston bore transverse to the extension axis, the piston bore having a first end and a second end, the first end being longitudinally aligned with the first sealing surface, and the second end being offset from, and longitudinally outward relative to, the second sealing surface; and\na pin extending into the piston bore and which limits over extension of the piston.', '15.', 'A method for manufacturing a piston, comprising:\npreparing a piston, the piston including a first end, the piston having a body of a prepared diameter and being formed from a first material;\napplying a sealing surface to the piston using laser cladding, the sealing surface including a radially outwardly facing circumferential surface of a second material harder than the first material;\nfinishing the sealing surface to a sealing surface diameter greater than the prepared diameter, the sealing surface diameter having tolerances of less than or equal to 0.02 mm; and\nplacing the piston in a housing bore of a housing, the housing including an inner surface forming a tolerance seal with the second material of the radially outwardly facing circumferential surface.', '16.', 'The method of claim 15, further comprising applying a wear surface to the first end of the piston via laser cladding.\n\n\n\n\n\n\n17.', 'The method of claim 15, wherein preparing the piston includes forming the piston in a mold and grinding a circumferential wall of the piston to the prepared diameter.', '18.', 'The method of claim 15, wherein applying the sealing surface includes applying a plurality of layers of the second material to the piston, with the plurality of layers being adjacent and adhering to one another.']

['FIG.', '1 is a representation of a drilling system, according to at least one embodiment of the present disclosure;; FIG.', '1-1 is a representation of a bit and rotary steerable system, according to at least one embodiment of the present disclosure;; FIG.', '2 is a representation of a piston, according to at least one embodiment of the present disclosure;; FIG.', '3-1 and FIG.', '3-2 are representations of another piston, according to at least one embodiment of the present disclosure;; FIG.', '4 is a representation of a piston receiving laser cladding, according to at least one embodiment of the present disclosure;; FIG.', '5 is a representation of yet another piston, according to at least one embodiment of the present disclosure;; FIG.', '6 is a representation of still another piston, according to at least one embodiment of the present disclosure;; FIG. 7 is a representation of a further piston, according to at least one embodiment of the present disclosure;; FIG.', '8-1 is a representation of a piston assembly in the retracted position, according to at least one embodiment of the present disclosure;; FIG.', '8-2 is a representation of the piston assembly of FIG.', '8-1 in the extended position; and; FIG. 9 is a representation of a method for manufacturing a piston, according to at least one embodiment of the present disclosure.', '; FIG.', '1 shows one example of a drilling system 100 for drilling an earth formation 101 to form a wellbore 102.', 'The drilling system 100 includes a drill rig 103 used to turn a drilling tool assembly 104 which extends downward into the wellbore 102.', 'The drilling tool assembly 104 may include a drill string 105, a bottomhole assembly (“BHA”) 106, and a bit 110, attached to the downhole end of drill string 105.; FIG.', '1-1 is a perspective view of the downhole end of an embodiment of a bit 110 and connected RSS 111.', 'The bit 110 may include a bit body 113 from which a plurality of blades 115 may protrude.', 'At least one of the blades 115 may have a plurality of cutting elements 117 connected thereto.', 'In some embodiments, at least one of the cutting elements may be a planar cutting element, such as a shear cutting element.', 'In other embodiments, at least one of the cutting elements may be a non-planar cutting element, such as a conical cutting element or a ridged cutting element.', '; FIG.', '2 is a representation of a piston 212 for a downhole drilling system (such as the piston 112 shown in FIG.', '1-1)', ', according to at least one embodiment of the present disclosure.', 'The piston 212 may be any piston used in a downhole drilling system.', 'For example, the piston 212 may be the steering pad of a directional drilling system such as an RSS, or a steering pad of another tool.', 'In some examples, the piston 212 may be the piston in an expandable stabilizer or other expandable tool.; FIG.', '3-1 is a representation of a piston 312, according to at least one embodiment of the present disclosure.', 'In some embodiments, the sealing surface 322 may be applied to the body 314 with one or more layers 342.', 'The circumferential wall 320 of the body 314 may be prepared prior to deposition of the layers 342.', 'For example, the circumferential wall 320 of the body 314 may be machined (e.g., ground) to a preparation diameter.', 'A powder containing the sealing surface material may be directed to the circumferential wall and a laser may bind the powder to the body 314 as the sealing surface 322.; FIG.', '4 is a representation of close-up view of a piston 412 that is having a sealing surface 422 deposited on the circumferential wall 420 of a body 414, according to at least one embodiment of the present disclosure.', 'In the embodiment shown, a first layer 442 has been deposited, and a second layer is in the process of being deposited on the body 414.', 'A nozzle 444 may be directed over the circumferential wall 420.', 'The nozzle 444 may receive material powder 446 from a powder source (e.g., a powder feeder that directs powder to the nozzle).', 'The nozzle 444 may direct the material powder 446 at the circumferential wall 420 adjacent to the first layer 442.; FIG.', '5 is a representation of a piston 512 including a plurality of sealing surfaces (collectively 522), according to at least one embodiment of the present disclosure.', 'In the embodiment shown, the piston 512 includes a first sealing surface 522-1 and a second sealing surface 522-2.', 'The first sealing surface 522-1 may be located on the body 514 closer to the first end 516 than the second sealing surface 522-2.', 'Similarly, the second sealing surface 522-2 may be located on the body closer to the second end 518 than the first sealing surface 522-1.', 'In the embodiment shown, the first sealing surface 522-1 is longitudinally offset from the second sealing surface 522-2.', 'Accordingly, the first sealing surface 522-1 is separate and distinct from the second sealing surface 522-2.', 'The first sealing surface 522-1 may be separated from the second sealing surface 522-2 by at least a portion of the circumferential wall 520 of the body 514.; FIG.', '6 is a representation of a piston 612 including a piston bore 650.', 'The piston bore 650 may extend through the body 614 of the piston 612.', 'The piston bore 650 may be configured to receive a pin from a housing.', 'The pin may extend into the piston bore 650.', 'During retraction (e.g., in the retracted position), the pin (shown schematically in dashed lines at position 653-1) may contact a bore first end 652.', 'This may help to retain the piston 612 in the retracted position and prevent the piston 612 from over-retracting.', 'During extension (e.g., in the extended position), the pin (shown schematically in dashed lines at position 653-2) may contact a bore second end 654.', 'This may help to retain the piston 612 in the extended position and prevent the piston 612 from over-extending.; FIG.', '7 is a representation of a piston 712 including wear surfaces 756 on the first end 716, according to at least one embodiment of the present disclosure.', 'In some embodiments, the piston 712 may extend along the longitudinal axis 724 (e.g., the extension axis) such that the first end 716 moves out of a housing.', 'The first end 716 may engage a wellbore wall and impart a force against the wellbore wall to change a trajectory of the bit.', 'In some embodiments, the first end 716 may include one or more wear surfaces 756.', 'The wear surfaces 756 may be formed from a wear and/or erosion resistant material to reduce wear when contacting the wellbore wall.', 'In some embodiments, the wear surfaces 756 may be formed by laser cladding, as discussed herein, especially with reference to FIG.', '3-1 through FIG.', '4, and the associated description.', 'In this manner, the wear surfaces 756 may be formed with a hard material that has a high bonding strength to the body 714.', 'In some embodiments, the first end 716 may be planar.', 'In some embodiments, the first end 716 may be contoured or otherwise have a shape that is not planar.', 'For example, the first end 716 may include a convex shape that is configured to match the profile of the wellbore wall.; FIG.', '8-1 is a representation of a piston assembly 858 in a retracted position, according to at least one embodiment of the present disclosure.', 'In the retracted position shown, the piston assembly 858 includes a piston 812 inserted into the bore 860 of a housing 862.', 'The piston 812 may include one or more sealing surfaces (collectively 822).', 'The sealing surfaces 822 engage an inner surface 864 of the bore 860.', 'In some embodiments, at least one of the sealing surfaces 822 may form a tolerance seal with the inner surface 864 of the bore 860.', 'The tolerance seal between the sealing surfaces 822 and the inner surface 864 may be formed via a gap 866 between the outer diameter of the sealing surface (e.g., the sealing surface diameter 240 of FIG.', '2) and the inner diameter of the bore 860.', 'In some embodiments, the gap 866 may be small enough that debris and/or fluid may not pass between the sealing surface 822 and the inner surface 864.', 'For example, the gap 866 may be less than 1 mm, less than 0.5 mm, less than 0.1 mm, less than 0.05 mm, less than 0.04 mm, less than 0.03 mm, or less than 0.02 mm.', 'In some embodiments, a seal formed by the gap 866 may not require any additional sealing element, such as an O-ring or other sealing element.', 'This may increase the simplicity of the piston assembly 858.; FIG.', '9 is a representation of a method 970 for manufacturing a piston, according to at least one embodiment of the present disclosure.', 'The method 970 may include preparing a piston at 972.', 'In some embodiments, preparing the piston may include forming the piston.', 'In some embodiments, the piston may be formed by placing matrix material (such as tungsten carbide powder).', 'A binder material (e.g., an infiltrant) may be melted and allowed to flow into the matrix material.', 'Preparing the piston may further include preparing the surface of the circumferential wall of the body of the piston.', 'For example, the circumferential wall may be machined or ground to a prepared diameter.']

US11900658

Method for automated stratigraphy interpretation from borehole images

Mar 11, 2020

Marie LeFranc, Zikri Bayraktar, Morten Kristensen, Philippe Marza, Isabelle Le Nir, Michael Prange, Josselin Kherroubi

SCHLUMBERGER TECHNOLOGY CORPORATION

Office Action issued in Norwegian Patent Application No. 20211154 dated Aug. 22, 2022, 6 pages.; Abbreviated Exam Report Under Section 18(3) dated Aug. 31, 2022, 4 pages.; Alqahtani, N. et al., “Deep Learning Convolutional Neural Networks to Predict Porous Media Properties”, SPE-191906, Presented at the SPE Asia Pacific Oil and Gas Conference and Exhibition held in Brisbane, Australia, 2018, 10 pages.; Anxionnaz, H. et al., “Near-Wellbore 3D Reconstruction of Sedimentary Bodies from Borehole Electrical Images”, SPWLA 39th Annual Logging Symposium, Keystone, Colorado, USA, 1998, 14 pages.; Bahadidah, T. A. et al., “Integrating High-Resolution Multiwell Image Logs to Improve Geological Reservoir Characterization and Sequence Stratigraphy”, IPTC-18209-MS, International Petroleum Technology Conference, Kuala Lumpur, Malaysia, 2014.; Curray, J. 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W.J. et al., “The characterization of trough and planar cross-bedding from borehole image logs”, Journal of Applied Geophysics, 2007, 62, pp. 178-191.; He, K. et al., “Deep Residual Learning for Image Recognition”, http://arxiv.org/abs/1512.03385, 12 pages.; Krizhevsky, A. et al., “ImageNet Classification with Deep Convolutional Neural Networks”, Proceedings of the 25th International Conference on Neural Information Processing Systems, Lake Tahoe, Nevada, USA., 2012, pp. 1-9.; Luthi, S. M. et al., “Models to Interpret Bedform Geometries from Cross-Bed Data”, The Journal of Geology, 1990, 98(2), pp. 171-187.; Luthi, S. M., “Sedimentary structures of clastic rocks identified from electrical borehole images”, in Geological Applications of Wireline Logs Geological Society Special Publication, 1990, 48, pp. 3-10.; Redmon, J. et al., “You Only Look Once: Unified, Real-Time Object Detection”, 2016 IEEE Conference on Computer Vision and Pattern Recognition (CVPR), pp. 779-788.; Ren, S. et al., “Faster R-CNN: Towards Real-Time Object Detection with Region Proposal Networks”, Proceedings of the 28th International Conference on Neural Information Processing Systems—vol. 1, Montreal, Canada, 2015, 9 pages.; Scheidegger, A.E., “On the Statistics of the Orientation of Bedding Planes, Grain Axes, and Similar Sedimentological Data”, U.S. Geological Survey Professional. Paper 525-C, 1965, pp. C164-167.; Schmidhuber, J., “Deep Learning in Neural Networks: An Overview” Neural Networks, 2015, 61, pp. 85-117.; Shrivastva, C. et al., “Reconstructing Sedimentary Depositional Environment with Borehole Imaging and Core: A Case Study from Eastern Offshore India”, IPTC12253, presented at the International Petroleum Technology Conference, Kuala Lumpur, Malaysia, 2008, 12 pages.; Simonyan, K. et al., “Very Deep Convolutional Networks for Large-Scale Image Recognition”, ICLR 2015, 14 pages.; Szegedy, C. et. al., “Going deeper with convolutions”, Proceedings of the IEEE Conference on Computer vision and Pattern Recognition 2015, 12 pages.; Wilson, S. R. , “Controls on Sediment Distribution in the Late Permian Rangal Coal Measures of the Nebo Synclinorium”, Thesis submitted for the degree of Master of Philosophy at the University of Queensland, Australia, 2017, 201 pages.; Zhang, P. Y. et al., “Deep Learning Method for Lithology Identification from Borehole Images”, 79th EAGE Conference and Exhibition, Paris, France, 2017, 5 pages.; International Search Report and Written Opinion of PCT Application No. PCT/US2020/022131 dated Jun. 15, 2020, 8 pages.; International Preliminary Report on Patentability of PCT Application No. PCT/US2020/022131 dated Sep. 23, 2021, 8 pages.; Potter, P. E. et al., “Paleocurrents and Basin Analysis”, 2nd Edition, Springer-Verlag, New York, 1977, p. 256-257.; LeCun Y., Haffner P., Bottou L. and Bengio Y. 1999. Object Recognition with Gradient-based Learning, Shape, Contour and Grouping in Computer Vision, Springer-Verlag, p. 321-323.; Miall, A.D., “Principles of Sedimentary Basin Analysis”, Springer Verlag, New York, 1984, 490p, (pp. 29-34, 151-190, 209-247).; Rubin D.M. and Carter C.L. 2005. Appendix 2. Special features, Part A. Documentation of MATLAB code, Rubin D.M. and Carter C.L. Bedforms 4.0: Matlab code for simulating bedforms and cross-beddings. USGS open-file report 2005-1272. (13 pages).; Reineck, H.-E. et al., “Depositional Sedimentary Environments, With Reference to Terrigenous Clastics”, 1980, Second, revised and updated version. Springer-Verlag Berlin, Heidelberg, New York. 549p. (pp. 95-129, 229, 274, 277, 283, 285, 291, 297, 299, 318, 368, 394).; Taylor, T. D., 1986, Interpretation of large-scale cross-strata in a borehole-a computer simulation model: Unpub. M. Sc. Thesis, Pennsylvania State University, University Park, 171 pages.; David M. Rubin and Carissa L. Carter, 2006, Bedform Sedimentology Site: Bedforms and Cross-Bedding in Animation, link is https://cmgds.marine.usgs.gov/data/seds/bedforms/credits_long.html, downloaded on Mar. 17, 2022 (3 pages).

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['Embodiments of the present disclosure are directed towards systems and methods for automated stratigraphy interpretation from borehole images.', 'Embodiments may include constructing, using at least one processor, a training set of synthetic images corresponding to a borehole, wherein the training set includes one or more of synthetic images, real images, and modified images.', 'Embodiments may further include automatically classifying, using the at least one processor, the training set into one or more individual sedimentary geometries using one or machine learning techniques.', 'Embodiments may also include automatically classifying, using the at least one processor, the training set into one or more priors for depositional environments.']

['Description\n\n\n\n\n\n\nRELATED APPLICATIONS', 'This application claims the benefit of U.S. Provisional Application No. 62/816,466, filed on Mar. 11, 2019; the contents of which is incorporated herein by reference.', 'FILED OF THE INVENTION', 'The present disclosure relates to automatic stratigraphy interpretation from borehole images, more specifically, to a system and method for automatic stratigraphy interpretation from borehole images.', 'BACKGROUND\n \nWhen studying geological structures of sedimentary origin, outcrop exposures may be used to study and classify the geological structures.', 'The geological structures of sedimentary origin may include a sedimentary facies having a specific depositional environment, also referred to as a depositional facies.', 'The depositional facies may be interpreted qualitatively based on log shape.', 'However, this approach is often non-unique and requires supporting information from core description, regional geology, seismic attributes, and/or borehole images.', 'As a different approach, borehole images can provide additional information to better characterize depositional environments, such as the geometry of sedimentary bodies, grain size variation, and paleocurrent direction.', 'While image description approaches and manual approaches to studying the depositional facies exist, image description approaches appear to be more and more automated (i.e., dip picking, structural zonation, and structural dip removal), whereas manual approaches include sedimentological environment interpretation and sequence stratigraphy.', 'However, manual interpretation may be user biased, time consuming, and can become very challenging when dealing with highly deviated wells.', 'For example, the same sedimentary geometry observed on borehole images from wells with different well deviations and orientations can have a completely different signatures, from a regular, symmetrical sinusoid on vertical wells to very elongated patterns on horizontal wells.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Embodiments of the present disclosure are directed towards a method for automated stratigraphy interpretation from borehole images.', 'The method may include constructing, using at least one processor, a training set of synthetic images corresponding to a borehole, wherein the training set includes one or more of synthetic images, real images, and modified images.', 'The method may further include automatically classifying, using the at least one processor, the training set into one or more individual sedimentary geometries using one or more machine learning techniques.', 'The method may also include automatically classifying, using the at least one processor, the training set into one or more priors for depositional environments.', 'One or more of the following features may be included.', 'In some embodiments, constructing a training set may include a forward model to generate the synthetic images and/or an addition of noise to the synthetic images.', 'Automatically classifying one or more individual sedimentary geometries may include applying one or more machine learning techniques.', 'Automatically classifying into priors for depositional environments may include applying one or more machine learning techniques.', 'Automatically classifying into priors may include building one or more tables of sedimentary geometry successions that represent one or more depositional environments.', 'An addition of noise may include at least one of adding one or more masking stripes on the one or more synthetic images, adding one stripe on the one or more synthetic images, adding a one-pixel stripe to the one or more synthetic images, adding white noise to the one or more synthetic images, translating patterns on the one or more synthetic images, truncating the one or more synthetic images, or adding geometric noise.', 'The method may include utilizing one or more automated individual sedimentary geometry predictions to establish a depositional environment predictor.', 'The depositional environment predictor may include a decision tree-based machine-learning, fuzzy-logic based algorithms, or a probabilistic graphical model.', 'The method may include identifying a longer than standard borehole image and applying a sliding window as a spatial sampling technique.', 'In another embodiment of the present disclosure a system for automated stratigraphy interpretation from borehole images is provided.', 'The system may include a memory configured to store one or more borehole images and at least one processor configured to construct a training set of synthetic images corresponding to a borehole, wherein the training set includes one or more of synthetic images, real images, and modified images.', 'The at least one processor may be further configured to automatically classify the training set into one or more individual sedimentary geometries using one or more machine learning techniques.', 'The at least one processor may be further configured to automatically classify the training set into one or more priors for depositional environments.', 'One or more of the following features may be included.', 'In some embodiments, constructing a training set may include a forward model to generate the synthetic images and/or an addition of noise to the synthetic images.', 'Automatically classifying one or more individual sedimentary geometries may include applying one or more machine learning techniques.', 'Automatically classifying into priors for depositional environments may include applying one or more machine learning techniques.', 'Automatically classifying into priors may include building one or more tables of sedimentary geometry successions that represent one or more depositional environments.', 'An addition of noise may include at least one of adding one or more masking stripes on the one or more synthetic images, adding one stripe on the one or more synthetic images, adding a one-pixel stripe to the one or more synthetic images, adding white noise to the one or more synthetic images, translating patterns on the one or more synthetic images, truncating the one or more synthetic images, or adding geometric noise.', 'The system may include utilizing one or more automated individual sedimentary geometry predictions to establish a depositional environment predictor.', 'The depositional environment predictor may include a decision tree-based machine-learning, fuzzy-logic based algorithms, or a probabilistic graphical model.', 'The system may include identifying a longer than standard borehole image and applying a sliding window as a spatial sampling technique.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present invention is illustrated by way of example, and not limitation, in the figures of the accompanying drawings in which like references indicate similar elements and in which:\n \nFIG.', '1\n is a system in accordance with the automated interpretation process of the present disclosure;\n \nFIG.', '2\n is a diagram illustrating interpreted causes of steepening-upward and shallowing-upward dip trends in sedimentary strata;\n \nFIG.', '3\n is a diagram illustrating a determination of one or more paleoflow directions using down-hole scan images;\n \nFIG.', '4\n is a diagram illustrating bedform morphology and vertical sections, horizontal and vertical sections, and polar plots of cross beds and bounding-surface dip directions;\n \nFIG.', '5\n is a block diagram illustrating how different computer images are arranged according to classification parameters;\n \nFIG. \n6\n is a diagram depicting examples of various computer models with matching field examples;\n \nFIG.', '7\n is a diagram depicting an embodiment of a method of automated interpretation process in accordance with the present disclosure;\n \nFIG.', '8\n is a diagram depicting examples of sequences of sedimentary geometries defining depositional environments;\n \nFIG.', '9\n is a block diagram depicting an embodiment of a method of automated interpretation process in accordance with the present disclosure;\n \nFIG.', '10\n is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;\n \nFIG.', '11\n is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;\n \nFIG.', '12\n is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;\n \nFIG.', '13\n is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;\n \nFIG.', '14\n is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;\n \nFIG.', '15\n a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;\n \nFIG.', '16\n is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure; and\n \nFIG.', '17\n is a diagram depicting the LeNet-5 architecture.', 'DESCRIPTION', 'The discussion below is directed to certain implementations and/or embodiments.', 'It is to be understood that the discussion below may be used for the purpose of enabling a person with ordinary skill in the art to make and use any subject matter defined now or later by the patent “claims” found in any issued patent herein.', 'It is specifically intended that the claimed combinations of features not be limited to the implementations and illustrations contained herein, but include modified forms of those implementations including portions of the implementations and combinations of elements of different implementations as come within the scope of the following claims.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions may be made to achieve the developers' specific goals, such as compliance with system-related and business related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Nothing in this application is considered critical or essential to the claimed invention unless explicitly indicated as being “critical” or “essential.”', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms may be used to distinguish one element from another.', 'For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the disclosure.', 'The first object or step, and the second object or step, are both objects or steps, respectively, but they are not to be considered a same object or step.', 'Referring to \nFIG.', '1\n, there is shown a method for automated stratigraphy interpretation from borehole images, referred to hereinafter as “automated interpretation process \n10\n.”', 'For the following discussion, it is intended to be understood that automated interpretation process \n10\n may be implemented in a variety of ways.', 'For example, automated interpretation process \n10\n may be implemented as a server-side process, a client-side process, or a server-side/client-side process.', 'For example, automated interpretation process \n10\n may be implemented as a purely server-side process via automated interpretation process \n10\ns\n.', 'Alternatively, automated interpretation process \n10\n may be implemented as a purely client-side process via one or more of client-side application \n10\nc\n1\n, client-side application \n10\nc\n2\n, client-side application \n10\nc\n3\n, and client-side application \n10\nc\n4\n.', 'Alternatively still, automated interpretation process \n10\n may be implemented as a server-side/client-side process via server-side automated interpretation process \n10\ns \nin combination with one or more of client-side application \n10\nc\n1\n, client-side application \n10\nc\n2\n, client-side application \n10\nc\n3\n, client-side application \n10\nc\n4\n, and client-side application \n10\nc\n5\n.', 'In such an example, at least a portion of the functionality of automated interpretation process \n10\n may be performed by automated interpretation process \n10\ns \nand at least a portion of the functionality of automated interpretation process \n10\n may be performed by one or more of client-side application \n10\nc\n1\n, \n10\nc\n2\n, \n10\nc\n3\n, \n10\nc\n4\n, and \n10\nc\n5\n.', 'Accordingly, automated interpretation process \n10\n as used in this disclosure may include any combination of automated interpretation process \n10\ns\n, client-side application \n10\nc\n1\n, client-side application \n10\nc\n2\n, client-side application \n10\nc\n3\n, client-side application \n10\nc\n4\n, and client-side application \n10\nc\n5\n.\n \nAutomated interpretation process \n10\ns \nmay be a server application and may reside on and may be executed by computing device \n12\n, which may be connected to network \n14\n (e.g., the Internet or a local area network).', 'Examples of computing device \n12\n may include, but are not limited to: a personal computer, a server computer, a series of server computers, a mini computer, a mainframe computer, or a dedicated network device.', 'The instruction sets and subroutines of automated interpretation process \n10\ns\n, which may be stored on storage device \n16\n coupled to computing device \n12\n, may be executed by one or more processors (not shown) and one or more memory architectures (not shown) included within computing device \n12\n.', 'Examples of storage device \n16\n may include but are not limited to: a hard disk drive; a tape drive; an optical drive; a RAID device; an NAS device, a Storage Area Network, a random access memory (RAM); a read-only memory (ROM); and all forms of flash memory storage devices.', 'Network \n14\n may be connected to one or more secondary networks (e.g., network \n18\n), examples of which may include but are not limited to: a local area network; a wide area network; or an intranet, for example.', 'The instruction sets and subroutines of client-side application \n10\nc\n1\n, \n10\nc\n2\n, \n10\nc\n3\n, \n10\nc\n4\n, \n10\nc\n5\n which may be stored on storage devices \n20\n, \n22\n, \n24\n, \n26\n, \n28\n (respectively) coupled to client electronic devices \n30\n, \n32\n, \n34\n, \n36\n, \n38\n (respectively), may be executed by one or more processors (not shown) and one or more memory architectures (not shown) incorporated into client electronic devices \n30\n, \n32\n, \n34\n, \n36\n, \n38\n (respectively).', 'Examples of storage devices \n20\n, \n22\n, \n24\n, \n26\n, \n28\n may include but are not limited to: hard disk drives; tape drives; optical drives; RAID devices; random access memories (RAM); read-only memories (ROM), and all forms of flash memory storage devices.', 'Examples of client electronic devices \n30\n, \n32\n, \n34\n, \n36\n, \n38\n may include, but are not limited to, personal computer \n30\n, \n38\n, laptop computer \n32\n, mobile computing device \n34\n, notebook computer \n36\n, a netbook computer (not shown), a server computer (not shown), an Internet of Things (IoT) device (not shown), a gaming console (not shown), a data-enabled television console (not shown), and a dedicated network device (not shown).', 'Client electronic devices \n30\n, \n32\n, \n34\n, \n36\n, \n38\n may each execute an operating system.', 'Users \n40\n, \n42\n, \n44\n, \n46\n, \n48\n may access automated interpretation process \n10\n directly through network \n14\n or through secondary network \n18\n.', 'Further, automated interpretation process \n10\n may be accessed through secondary network \n18\n via link line \n50\n.', 'The various client electronic devices (e.g., client electronic devices \n30\n, \n32\n, \n34\n, \n36\n, \n38\n) may be directly or indirectly coupled to network \n14\n (or network \n18\n).', 'For example, personal computer \n30\n is shown directly coupled to network \n14\n.', 'Further, laptop computer \n32\n is shown wirelessly coupled to network \n14\n via wireless communication channels \n52\n established between laptop computer \n32\n and wireless access point (WAP) \n54\n.', 'Similarly, mobile computing device \n34\n is shown wirelessly coupled to network \n14\n via wireless communication channel \n56\n established between mobile computing device \n34\n and cellular network/bridge \n58\n, which is shown directly coupled to network \n14\n.', 'WAP \n54\n may be, for example, an IEEE 802.11a, 802.11b, 802.11g, 802.11n, Wi-Fi, and/or Bluetooth device that is capable of establishing wireless communication channel \n52\n between laptop computer \n32\n and WAP \n54\n.', 'Additionally, notebook computer \n36\n is shown directly coupled to network \n18\n via a hardwired network connection.', 'As generally discussed above, a portion and/or all of the functionality of automated interpretation process \n10\n may be provided by one or more of client side applications \n10\nc\n1\n-\n10\nc\n5\n.', 'For example, in some embodiments automated interpretation process \n10\n (and/or client-side functionality of automated interpretation process \n10\n) may be included within and/or interactive with client-side applications \n10\nc\n1\n-\n10\nc\n5\n, which may include client side electronic applications, web browsers, or another application.', 'Various additional/alternative configurations may be equally utilized.', 'Regarding specific terminology used herein, the term “bedform” refers to an overall bed geometry that exists at a given time in response to the flow (i.e., bed configuration) is composed of individual topographic elements (i.e., bed forms).', 'An ensemble of like bed configurations that can be produced by a given mean flow over a given sediment is denoted as a bed state.', 'The term bed phase may further be used to denote different kinds of bed configurations that are produced over a range of flow and sediment conditions and are closely related in geometry and dynamics.', 'The term bedform is indiscriminately used herein to denote all four aspects of the bed geometry.', 'While sedimentologists have given attention to bedforms mostly because of their role in the development of stratification in sedimentary deposits, bedforms are one of the most useful tools available for interpreting ancient sedimentary environments.', 'Further, the term ripples refers to the stronger the grain transport, the sooner the bed forms appear, and the faster they approach equilibrium.', 'These bedforms, classified as ripples, show generally triangular cross sections.', 'The region around the highest point on the ripple profile is the crest, and the region around the lowest point is the trough.', 'The upstream-facing surface of the ripple is the toss surface, the downstream-facing surface is the lee surface.', 'The average spacing of ripples is of the order of 10-20 cm, and the average height is a few centimeters.', "The term dunes refers to where at a flow velocity that's a middling fraction of a meter a second, ripples are replaced by larger bedforms called dunes.", 'Dunes are broadly similar to ripples in geometry and movement, but they are about an order of magnitude larger.', 'Additionally, cross-stratification is best defined as stratification that is locally inclined at some angle to the overall plane of stratification as a consequence of changes in the geometry of the depositional surface during deposition.', 'The best way to interpret those terms is to assume that cross-stratification is associated with the behavior of individual flow-molded geometrical elements on a transport surface within some broader flow.', 'Cross-stratification is formed by the erosion and deposition associated with a train of bed forms as the average bed elevation increases by net addition of sediment to some area of the bed.', 'They are arranged as sets of conformable laminae, planar or curving, that are separated from adjacent sets by erosional set boundaries or truncation surfaces.', 'Turning back to borehole images, sedimentary geometry on borehole images may typically be manually classified.', 'The classifications may include bed boundary, sedimentary dip, erosive surface, cross bedding, and/or deformed bed.', 'In contrast, bedform geometry interpretation from a cross-bed data appears to rarely be performed.', 'For example, when one or more bedform crests migrate in the direction of or obliquely to the sediment transport direction, the resulting sedimentary geometries on borehole images will vary considerably.', 'The geometry resulting from the change in flow direction generating different bedform shapes is also rarely interpreted.', 'Analysis of classified internal bedding dips can provide important information on sediment dispersal directions and sedimentary environments, as illustrated in \nFIG.', '2\n and \nFIG.', '3\n where \nFIG.', '2\n illustrates interpreted cause of steepening-upward and shallowing-upward dip trends in sedimentary strata and \nFIG.', '3\n illustrates determination of paleoflow directions using down-hole scan images.', 'Specifically, \nFIG.', '3\n illustrates trough cross stratification \n302\n, which includes 3D bar migration and may have low gamma ray response, blocky to fining upwards motif, sigmoidal cross beds, thin (i.e., 0.2-0.8 meter) bed sets with common basal scour, low to moderate angle dips (i.e., 10-15°) and variable dip direction (i.e., SW, S, SE).', 'Planar tabular cross stratification \n304\n may include straight crested transverse bar migration, which may include low gamma ray response, blocky to fining upwards motif, planner cross beds, high to moderate angle dip (i.e., 10-30°), 1-3 meter thick bed sets with common basal scour, and dip direction (i.e., SW).', 'Inclined heterolithic stratification (HS) \n306\n may include pointbar lateral accretion, which may include moderate gamma ray response, heterolithic and fining upwards motif, dip direction rotates counter clockwise upwards as point bar apex migrates downstream, bimodal dip (i.e., west for left bank, east for right bank) and 2-3 meter thick bed sets.', 'In some embodiments in accordance with the present disclosure, a borehole image on which one or more dips of sedimentary features (i.e., sinusoids or segments) may be required as a main input of data.', 'Further, an approach to automated dip picking on borehole images is known and is used on processed borehole images to provide necessary images to run the new automated classification.', 'A goal of the present disclosure is to include a catalog of 3D bedform geometries and to create, from the 3D models, one or more synthetic borehole images for wells with various diameters, orientations, and inclinations.', 'Regarding known methods, using cross-bed measurements to determine paleocurrent directions and depositional environments is known in the field as well as a relationship showing that cross-bedding and current ripples indicate a paleoslope.', 'These structures provide an unmistakable answer in alluvial-deltaic sandstones, as do oscillation and wave-formed ripples, which commonly strike parallel to shorelines of lakes, seas, and oceans.', 'In turbidites, ripple marks may indicate paleoslope.', 'Further, most studies of ancient marine shelf sandstones, both terrigenous and carbonate, often suggest an overall net transport down paleoslope.', 'In regards to construction of models used to interpret bedform geometries from cross-bed data, two computational approaches are known: a statistical random sampling technique over the area of the deposit and an analytical method based on topology and differential geometry.', 'For example, a computer model called RIPSYM exists that simulates the formation of cross-strata sets produced by the migration of three-dimensional large-scale ripple trains.', 'The model assumes uniform and steady sediment transport rates and the following independent variables: phase angle, crestline sinuosity, location and radius of the borehole, bedform migration velocity, length of time step, number of time steps, and number of ripple crests.', 'Further, an approach considering reconstruction of bedform geometry away from the wellbore is known, where the approach is constrained by the information available on the cylindrical borehole wall, and achieved by numerically solving an inverse problem.', 'In some embodiments according to the present disclosure, computer images may be used to build a forward model.', 'Table 1 below illustrates parameters specified for each experiment including the spacing, steepness, asymmetry, migration direction, migration speed, planform shape, and along-crest migration speed of planform sinuosities of each set of bedforms.', 'Further, table illustrates 2D and 3D dimensionality, variability, and orientation relative to transport parameters used in classifying bedforms.', 'TABLE 1\n \n \n \n \n \n \n \n \nTwo-dimensional\n \nInvariable\n \nTransverse, oblique, and\n \n \n \n2D bedforms are\n \nInvariable bedforms are those\n \nlongitudinal\n \n \n \nstraight and parallel\n \nthat do not change in\n \nTranvserse, oblique, and\n \n \n \nin plan form; the\n \nmorphology or path of climb.', 'longitudinal cross beddding are\n \n \n \nflanks of the\n \nCross-bedding deposited by\n \nnot distinguishable unless\n \n \n \nbedforms have the\n \ninvariable 2D bedforms has\n \nbedforms are at least slightly\n \n \n \nsame strike at all\n \nbounding surfaces that are\n \n3D.\n \n \n \nlocations.', '2D\n \nparallel planes', '; their poles\n \n \n \n \nbedforms produce\n \nplot as single point.', '2D cross-bedding:\n \nVariable\n \nTransverse, oblique, and\n \n \n \ncross-bedding in\n \nVariable bedforms are those\n \nlongitudinal\n \n \n \nwhich all forests and\n \nthat change in morphology or\n \nTransverse, oblique, and\n \n \n \nbounding surfaces\n \npath of climb.', 'Variability causes\n \nlongitudinal cross-bedding\n \n \n \nhave the same strike.\n \ndispersion in the inclination of\n \nare not distinguishable unless\n \n \n \nIn plots showing the\n \nbounding surfaces.', 'Cross-\n \nbedforms are at least slightly\n \n \n \ndirection and\n \nbedding deposited by variable\n \n3D.\n \n \n \ninclination of dips of\n \n2D bedforms are bounding\n \n \n \n \ncross-beds and\n \nsurfaces with a constant strike\n \n \n \n \nbounding surfaces,\n \nbut with varying inclination;\n \n \n \n \ndips of all planes,\n \ntheir poles plot as a straight line\n \n \n \n \nplot along a single\n \nthat parallels the line of cross-\n \n \n \n \nstraight line through\n \nbed dips.', 'the center of the\n \n \n \n \n \nplot.', 'Three-dimensional\n \nInvariable\n \nPerfectly transverse\n \n \n \n3D bedforms are\n \nCross-bedding deposited by\n \nPlots of cross-bed and\n \n \n \ncurved in plan flor\n \ninvariable 3D bedforms has\n \nbounding-surface dips have\n \n \n \nor have plan-form\n \nbounding surfaces that are\n \nbilateral symmetry; the axis\n \n \n \ncomplexities such as\n \ntrough-shaped; bounding\n \nof symmetry is the same for\n \n \n \nscour pits or\n \nsurface dips in a single trough\n \nboth plots; dips directions are\n \n \n \nsuperimposed\n \n(or in identical troughs) plot\n \ndistributed unimodally.', 'bedforms with a\n \nas a nearly straight line.', 'Obilique, imperfectly\n \n \n \ndifferent trend from\n \n \ntransverse, or imperfectly\n \n \n \nthe main bedform:\n \n \nlongitudinal\n \n \n \nthe strike of the\n \n \nPlots of cross-bed and\n \n \n \nflanks varies with\n \n \nbounding-surface dips have\n \n \n \nlocation.', '3D\n \n \nbilateral symmetry; the axis\n \n \n \nbedforms produce\n \n \nof symmetry is the same for\n \n \n \n3D cross-bedding in\n \n \nboth plots; dip directions are\n \n \n \nwhich foreset and\n \n \ndistributed unimodally.', 'bounding surface\n \n \nPerfectly longitudinal\n \n \n \nstrikes vary with\n \n \nPlots of cross-bed and\n \n \n \nlocation; dips of\n \n \nbounding-surface dips have\n \n \n \nforesets do not plot\n \n \nbilateral symmetry; dip\n \n \n \nalong a single\n \n \ndirections may be distributed\n \n \n \nstraight line through\n \n \nbimodally or be unimodal as a\n \n \n \nthe center of polar\n \n \nresult of migration of the nose\n \n \n \nplots.\n \n \nof the main bedform.', 'Perfect\n \n \n \n \n \nlongitudinallity is evidenced\n \n \n \n \n \nby vertical accretion of\n \n \n \n \n \nbedforms; cross-beds dip in\n \n \n \n \n \nopposing directions on\n \n \n \n \n \nopposite flanks.', 'Variable\n \nPerfectly transverse\n \n \n \n \nBounding surfaces have\n \nSame as perfectly transverse,\n \n \n \n \ncomplex shapes produced by\n \ninvariable, 3D cross-bedding\n \n \n \n \nsuch processes as zig-zagging\n \nOblique, imperfectly\n \n \n \n \nof scour pits; dips of bounding\n \ntransverse, or imperfectly\n \n \n \n \nsurfaces plot as scatter\n \nlongitudinal\n \n \n \n \ndiagrams.', 'Same as oblique or\n \n \n \n \n \nimperfectly aligned,\n \n \n \n \n \ninvariable, 3D cross-bedding\n \n \n \n \n \nPerfectly longitudinal\n \n \n \n \n \nSame as perfectly\n \n \n \n \n \nlongitudinal, invariable, 3D\n \n \n \n \n \ncross-bedding.', 'A computer model may account for variation of bedform morphology and behavior through time.', 'A total of 75 geometric parameters may control different geometries of the bedforms.', 'Three separate computer programs were used to produce the images shown in \nFIG.', '4\n.', 'FIG.', '4\n further illustrates bedform morphology and vertical sections, horizontal and vertical sections and polar plots of cross beds and bounding-surface dip directions.', 'By varying one or more input parameters, each computer program model may model different depositional situations, as illustrated in \nFIG.', '5\n.', 'FIG.', '5\n further illustrates how the above mentioned computer program models are arranged according to classification parameters.', 'For example, a first computer program may calculate a topography of a bed surfaces and display the surface in a 3D perspective.', 'The resulting image may include both bed morphology and internal structures.', 'A second computer program may produce perspective block diagrams with horizontal sections instead of bed morphology at the top of the block.', 'Further, a third computer program may plot vectors that represent a migration of bedforms and scour pits.', 'Specifically, the third computer program may plot a direction of sediment transport represented by bedform migration azimuth.', 'It may also plot inclination of cross-bed and bounding-surface planes.', 'In regards to detecting objects in images, traditional computer vision methods may entail multiple-steps where input data is sent through a feature extraction step and then a spatial sampling may be applied, which in turn is passed through a classifier and detection output is obtained.', 'Even within this traditional computer vision methodology, a machine learning classifier, such as support vector machine or decision tree methods, may be used.', 'In addition to traditional computer vision techniques, end-to-end machine learning algorithms and deep learning methods may be used.', 'As deep learning (DL) methods became easier to implement, DL algorithms demonstrated that they could create end-to-end workflows where 2D input image data is fed in and output detection comes out all at once.', 'Further, intermediate steps such as feature extraction, spatial sampling and classification are achieved within deep artificial neural network architectures and convolutional neural networks (CNN) are leading architectures in object detection in images.', 'When CNN has been combined with a gradient-based learning method called backpropagation, it has led to a new way for efficient image classification as demonstrated with LeNet architecture (CNN-based).', 'For example, classifying hand-written digits with CNNs is illustrated in \nFIG. \n6\n along with examples of the above mentioned compute models with matching field examples.', 'CNNs may be preferred, as they tend to be easier to train than fully-connected neural networks, and various improvements to CNNs proposed as well as larger, deeper architectures for applications in various fields.', 'Regarding \nFIG.', '6\n, sets of images are provided that include one or more images of a specific rock formation with an associated computer model rendering of the specific rock formation.', 'Arizona sample \n602\n shows a structure formed by reversing ripples with modern fluvial deposits from the Colorado River, Grand Canyon National Park, Arizona.', 'Utah sample \n604\n shows structures including a relatively complicated cross-bedding formed by irregular, 3D dunes from eolian deposits in the Temple Cap Sandstone (Jurassic), Zion National Park, Utah.', 'Further, Utah sample \n606\n shows structures formed with along-crest-migration superimposed dunes from Navajo Sandstone (Upper Triassic and Jurassic), Zion National Park, Utah.', 'Utah sample \n608\n shows a structure produced by sinuous, out-of-phase bedform from eolian deposits in the Navajo Sandstone (Upper Triassic and Jurassic) near Snow Canyon, Utah.', 'Additionally, Utah sample \n610\n includes a structure formed by a dune with a sinuous lee slope but without scour pots in the trough from Navajo Sandstone (Upper Triassic and Jurassic), Zio National Park, Utah.', 'Per an image classification task, various milestone architectures and methods exist.', 'For example, various improvements over LeNet architecture have been introduced, such as using a rectified linear unit (ReLU) for the nonlinearity function instead of sigmoid functions, implementing dropout layers for regularization, using augmentation techniques like translation and reflection, as well as utilizing stochastic gradient descent to train the architecture.', 'Deeper architectures such as VGGnet, GoogLeNet or ResNet achieved even better performance in classification.', 'In terms of object detection and localization, CNNs play a crucial role in advancing the field.', 'CNN based architectures, R-CNN, Fast R-CNN, and Faster R-CNN consist of a region proposal algorithm and CNNs working on the proposed regions for object detection.', 'However, the main drawback is the speed of execution, which has been improved with newer versions of the algorithm.', 'Further, another important work for real-time object detection is a YOLO algorithm, which is a fully convolutional neural networks-based method and provides very fast detection at the expense of small accuracy reduction.', 'Regarding applying CNNs to borehole images, known methods include classifying three lithology groups on a limited dataset and application to greyscale micro-CT images of three different sandstones species to predict porous media properties.', 'While CNNs are the preferred choice for seismic image processing, there are not many known applications of CNNs for use with borehole images.', 'This may be because labeled datasets on borehole images are extremely expensive to obtain.', 'In some embodiments according to the present disclosure, a method of automated interpretation process \n10\n is provided.', 'Automated interpretation process \n10\n may describe a method, using machine learning algorithms, to automatically interpret bedform geometries and depositional environments from cross-bed data and sedimentary features on borehole images.', 'Automated interpretation process \n10\n may initially require construction of one or more forward models to generate one or more labeled images for each sedimentary geometry.', 'Once a training set is built, one or more DL algorithms may be used to automatically classify one or more sedimentary structures (i.e., bedform geometries) and provide priors for depositional environments.', 'Specifically, automated interpretation process \n10\n may include constructing \n702\n, using at least one processor, a training set of synthetic images corresponding to a borehole, wherein the training set includes one or more of synthetic images, real images, and modified images, as illustrated in \nFIG. \n7\n.', 'The training set may include one or more of synthetic images, real images, and modified images similar to real borehole images.', 'Further, this may include using a forward model used to generate the synthetic images, and the addition of ‘noise’ to the synthetic images to better mimic real images.', 'Automated interpretation process \n10\n may further include automatically classifying \n704\n, using the at least one processor, the training set into one or more individual sedimentary geometries using one or machine learning techniques.', 'Automatically classifying one or more individual sedimentary geometries may include using one or more DL algorithm.', 'Specifically, one or more of development of specific machine learning techniques to classify the individual sedimentary structures may be included.', 'Further, automated interpretation process \n10\n may include automatically classifying \n706\n into priors for depositional environments.', 'This may include developing specific machine learning techniques to provide a prior for depositional environments.', 'Additionally, automatically classifying into priors for depositional environments may include building or more tables of sedimentary geometry successions that represent each depositional environment.', 'The tables may illustrate one or more different sequences of sedimentary geometries defining specific depositional environments.', 'Further, the creation of the tables may require extensive literature review by domain experts in order to generate a review data set.', 'The one or more tables may then be used to automatically obtain depositional environments from borehole images.', 'FIG.', '8\n illustrates sequences of sedimentary geometries defining depositional environments.', 'For example, floodplain \n802\n illustrates six layers of sedimentary geometries, including: (1) mud layer \n804\n, which may be finely laminated; (2) convolute bedding layer \n806\n, which may be comprised of finely laminated mud; (3) climbing ripple lamination layer \n808\n; (4) finely laminated mud layer \n810\n; (5) convolute bedding layer \n812\n, which may include a sandy layer; and (6) climbing ripple lamination layer \n814\n.', 'Further, point bar \n816\n may include: (1) mud layer \n818\n; (2) small ripple layer \n820\n, which may include cross-bedding; (3) climbing ripple lamination layer \n822\n; (4) horizontal lamination layer \n824\n; (5) lapse-scale cross-bedding layer \n826\n; and (6) channel last deposit layer \n828\n.', 'Additionally, levee \n830\n may include: (1) parallel bedded salty clay layer \n832\n, which may include burrows; (2) climbing ripple lamination layer \n834\n; (3) small ripple cross-bedding layer \n836\n; (4) horizontal bedding layer \n838\n; (5) large-scale cross-bedding layer \n840\n; and (6) salt and sand layer \n842\n, where the salt and sand may be poorly sorted with no internal structure and occasional ripples.', 'One or more borehole images may be required to be combined with one or more other types of measurements to more accurately define a depositional environment in an effort to provide priors for depositional environments.', 'Further, one or more automated individual sedimentary geometry predictions may be utilized to establish a depositional environment predictor.', 'The depositional environment predictor may include the following forms.', 'First, the depositional environment predictor may utilize a decision tree-based machine-learning algorithm that is trained on extensive literature review data set generated by the domain experts.', 'Once trained, decision-tree based algorithms may be very fast in inference and easy to interpret.', 'Second, one or more fuzzy-logic based algorithms may be utilized that can utilize one or more uncertainty measures created during the automated individual sedimentary prediction to construct one or more fuzzy-logic decision rules for depositional environments.', "Third, a probabilistic graphical model may be built on the domain expert's knowledge data set and utilized with one or more uncertainty estimations of the automated individual sedimentary prediction.", 'In some embodiments according to the present disclosure, automated interpretation process \n10\n may include allowing one or more borehole image interpretations to be integrated into 3D subsurface modeling.', 'Specifically, a depositional environment from dips interpreted on borehole images may be automatically estimated.', 'In some embodiments according to the present disclosure, automated interpretation process \n10\n may include automatically providing both classification of sedimentary geometries regardless of borehole deviation as well as priors for depositional environment interpretations, and their associated uncertainties using one or more machine learning techniques.', 'Regarding potential applications of automated interpretation process \n10\n, automated interpretation process \n10\n may be applied to interpretation of one or more borehole images, which may help a borehole geologist to interpret borehole images faster, to decrease user bias, and/or to add a level of interpretation to known borehole images analysis.', 'Automated interpretation process \n10\n may also be applied to 3D facies modeling where the outputs from automated interpretation process \n10\n may be used directly as input to build one or more 3D facies models.', 'Specifically, it is a crucial step to include borehole image interpretation in 3D subsurface models.', 'Further, automated interpretation process \n10\n may be used with exploration as the use of the depositional environment logs, combined with stratigraphic sequences from seismic will enhance exploration studies by facilitating identification of new drilling targets.', 'Regarding \nFIG.', '9\n, a method and system in accordance with the present disclosure is shown.', 'Forward model \n902\n may be used with training set \n904\n where individual sedimentary structures \n906\n may then be recognized.', 'Further, priors for depositional environments \n908\n may be acquired.', 'Referring back to \nFIG.', '5\n, a modification of existing computer models is provided.', 'In this example, 59 computer models may be used as a starting point.', 'These models may be selected due to the variety of the sedimentary geometries represented, and their link to real field examples, as illustrated in \nFIG.', '6\n.', 'One or more computer models may be used where the computer models include Matlab code, of which the results are illustrated in \nFIG.', '10\n and \nFIG.', '11\n.', 'FIG.', '10\n illustrates an example of automated interpretation process \n10\n with intermediate surfaces, computational of an intersection between surfaces and a vertical cylinder and creation of one or more resulting synthetic images with subsurface intersections denoted as \n1002\n and an azimuth in degrees denoted as \n1004\n.', 'FIG.', '11\n illustrates an example of automated interpretation process \n10\n with \nintermedia \nsurfaces, computation of an intersection between surfaces and a highly deviated cylinder, and creation of one or more resulting synthetic images where subsurface interactions are denoted as \n1102\n and \n1104\n and an azimuth in degrees is denoted as \n1106\n.', 'In general, the one or more computer models may include one or more of the following extract all intermediate surfaces, for each computer model, respecting rules of deposition, create a cylinder, representing a well drilled through the structures, compute intersections between the surfaces and the cylinder, and create a synthetic, oriented image representing the intersections between the surfaces and the cylinder/well.', 'In this example, a sinusoid may represent and intersection between a planar surface and a well.', 'The one or more synthetic images may represent results a borehole geologist would obtain after picking features on a real processed borehole image.', 'Referring to \nFIG.', '12\n,', 'an embodiment in accordance with the present disclosure is illustrated showing creation of one or more synthetic images with various well parameters.', 'Specifically, automated interpretation process \n10\n may be trained using one or more images generated from wells with multiple deviations in an attempt to automatically recognize one or more sedimentary geometries from one or more borehole images, regardless of the borehole deviation.', 'Further, \nFIG.', '12\n illustrates use of one or more different well parameters used to generate one or more synthetic images including one or more of well orientation, well deviation, well location, and well azimuth.', 'For example, \nFIG.', '12\n includes the following parameters: (1) two different well locations in the 3D model; (2) three different well diameters (i.e., representing diameters of 4″, 8.5″ and 12.25″; (3) multiple well deviations (i.e., every 10°, from 0° to 90°); and (4) multiple well orientations (i.e., every 10°, from 0° to 360°).', 'Referring to \nFIG.', '13\n and \nFIG.', '14\n, examples of synthetic images are presented.', 'FIG.', '13\n illustrates examples of synthetic images (i.e. \n1302\n, \n1304\n, \n1306\n, \n1308\n, \n1310\n, \n1312\n and \n1314\n), generated from vertical wells and their associated 3D models.', 'FIG.', '14\n illustrates examples of synthetic images created from vertical wells in different 3D models (i.e., \n1402\n, \n1404\n, \n1406\n, \n1408\n, \n1410\n, \n1412\n, \n1414\n, \n1416\n, \n1418\n, \n1420\n, \n1422\n, \n1424\n, \n1426\n, \n1428\n, \n1430\n, \n1432\n, \n1434\n, \n1436\n, \n1438\n and \n1440\n).', 'Referring to \nFIG.', '15\n, \nFIG.', '15\n illustrates examples of synthetic images generated from \n1412\n, with a vertical well and highly deviated wells with different orientations.', 'The cylinder in the demi-sphere illustrates the orientation of the well in the model.', 'Further, the intersections between the surfaces and the cylinder/well are also represented.', 'Additionally, \nFIG.', '16\n illustrates the addition of one or more noisy images to the training set and, specifically, adding noise to the synthetic images to be closer from real images, including stripes, ‘salt’, and truncations.', 'For example, sample \n1602\n illustrates no noise.', 'Sample \n1606\n illustrates an 8.5″ hole with 50% ‘white’ noise added.', 'Sample \n1606\n illustrates a 12.25″ hole with 60% coverage with stripes like formation micro-imager (FMI) FMI images along with 40% white noise added.', 'Sample \n1608\n illustrates an 8.5″ hole with 80% coverage and stripes like FMI images.', 'Sample \n1610\n illustrates an 8.5″ hole with one white stripe (i.e., one flap/pad not working).', 'Sample \n1612\n illustrates a 12.25″ hole with 50% ‘white’ noise added.', 'Further, sample \n1614\n illustrates an 8.5″ hole with 40% ‘white’ noise added.', 'Sample \n1616\n illustrates a 12.25″ hole with 60% coverage and stripes like FMI images.', 'Additionally, sample \n1618\n illustrates a 12.25″ hole with one white stripe (i.e., one flap/pad not working).', 'Sample \n1620\n illustrates an 8.5″ hole with 80% coverage, stripes like FMI images, and 40% ‘white’ noise added.', 'Sample \n1622\n illustrates a 12.25″ hole with a 40% ‘white’ noise added.', 'Further, sample \n1624\n illustrates a truncated image.', 'To train automated interpretation process \n10\n with one or more borehole images that are as realistic as possible, noise may be added to the one or more synthetic images.', 'Different levels of noise considered may include one or more of: (1) adding one or more masking stripes on the one or more synthetic images, thus reproducing limited coverage of certain types of pad-based imaging tools with, for example, 60% coverage in 12.25″ hole diameter, or 80% coverage in 8.5″ hole diameter; (2) adding one stripe on the one or more synthetic images, which may be equivalent to one pad or one flap not functioning; (3) adding a one-pixel stripe to one or more of the one or more synthetic images, which may be equivalent to a dead button; (4) adding ‘white’ noise to the one or more synthetic images to represent discontinuous interpretation obtained when the discontinuous (i.e., segment) extraction of sedimentary surfaces is used to automatically pick one or more features on the one or more synthetic images, or results when other patterns like breakouts and fractures are present also on the borehole images where different percentages of noise may be added to the one or more synthetic images (i.e., up to 50%); (5) translating patterns on the one or more synthetic images; (6) truncating the one or more synthetic images where only a limited part of the one or more synthetic images may be observed on a real image and one or more sections may be randomly selected on the images to train automated interpretation process \n10\n with truncated images; and (7) adding geometric noise where the borehole may not be perfectly circular (i.e., ellipse), and small depth error between pad may exist.', 'In some embodiments according to the present disclosure, multiple noise levels may be combined.', 'An initial comparison demonstrates that well known machine learning methods such as support vector machines, decision trees, random forest method, and fully-connected neural networks, do not perform as well as CNN based methods in classification of synthetically generated 2D image data.', 'On one hand, data may be converted into a very long input vector, thus spatial features may not be able to be captured.', 'However, a CNN may extract one or more spatial features from 2D input images directly, as illustrated in \nFIG.', '17\n which illustrates a LeNet-5 architecture.', 'Further, using a ResNet architecture, also referred to herein as “ResNet classification module” may be the most beneficial in classification in automated interpretation process \n10\n.', 'For example, automated interpretation process \n10\n may include using one or more ResNet classification modules with different settings and combined into an ensemble method where results of multiple models are voted on, and the most voted class may be selected as the prediction providing a confidence score among all votes.', 'Automated interpretation process \n10\n may train the one or more ResNet classification modules on an 2D input image that is 40 to 200 pixels tall and 140 pixels wide.', 'Such a small window of input may enable one or more small features to be captured and becomes crucial in the application of a sliding window.', 'A sliding window may be applied as a spatial sampling method where a long borehole image is provided.', 'Further, a sliding window may include defining a step of 5 to 10 pixel.', 'At each step, a 50-pixel window of a long borehole image may be cropped around the step point.', 'This cropped image may be fed into the one or more ResNet classification models and a classification prediction may be obtained.', 'Stepping through an entire borehole image, one or more classes of which the borehole image belongs to may be determined.', 'Additionally, a more advanced method of identification and localization may be performed using the YOLO (You-Only-Look-Once) algorithm.', 'In this approach, an entire borehole image may be fed into the automated interpretation process \n10\n and the YOLO algorithm may provide one or more coordinates of individual sedimentary geometries by placing boxes around each in addition to the class labels.', 'Since the YOLO algorithm is a fully-convolutional approach (i.e., it does not utilize sliding windows explicitly), it is may be significantly faster than above described method using one or more ResNet classification models.', 'The flowchart and block diagrams in the figures illustrate the architecture, functionality, and operation of possible implementations of systems and methods and according to various embodiments of the present disclosure.', 'In this regard, each block in the flowchart or block diagrams may represent a module, segment, or portion of code, which comprises one or more executable instructions for implementing the specified logical function(s).', 'It should also be noted that, in some alternative implementations, the functions noted in the block may occur out of the order noted in the figures.', 'For example, two blocks shown in succession may, in fact, be executed substantially concurrently, or the blocks may sometimes be executed in the reverse order, depending upon the functionality involved.', 'It will also be noted that each block of the block diagrams and/or flowchart illustration, and combinations of blocks in the block diagrams and/or flowchart illustration, can be implemented by special purpose hardware-based systems that perform the specified functions or acts, or combinations of special purpose hardware and computer instructions.', 'The terminology used herein is for the purpose of describing particular embodiments and is not intended to be limiting of the disclosure.', 'As used herein, the singular forms “a”, “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will be further understood that the terms “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'The corresponding structures, materials, acts, and equivalents of means or step plus function elements in the claims below are intended to include any structure, material, or act for performing the function in combination with other claimed elements as specifically claimed.', 'The description of the present disclosure has been presented for purposes of illustration and description, but is not intended to be exhaustive or limited to the disclosure in the form disclosed.', 'Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the disclosure.', 'The embodiment was chosen and described in order to best explain the principles of the disclosure and the practical application, and to enable others of ordinary skill in the art to understand the disclosure for various embodiments with various modifications as are suited to the particular use contemplated.', 'Although a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from the scope of the present disclosure, described herein.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.', 'Having thus described the disclosure of the present application in detail and by reference to embodiments thereof, it will be apparent that modifications and variations are possible without departing from the scope of the disclosure defined in the appended claims.']

['1.', 'A method for automated stratigraphy interpretation from borehole images comprising:\nconstructing, using at least one processor, a training set of images corresponding to a borehole, wherein the training set includes one or more of synthetic images, real images, and modified images;\nautomatically classifying, using the at least one processor, the training set into one or more individual sedimentary geometries using a machine learning model that has been trained based on images generated from wells with multiple deviations to automatically recognize one or more sedimentary geometries from one or more borehole images, regardless of borehole deviation, wherein the automatically classifying comprises: identifying a longer than standard borehole image in the training set of images; and applying a sliding window as a spatial sampling technique based on the identifying the longer than standard borehole image, wherein the spatial sampling technique includes providing a plurality of cropped images, corresponding to the sliding window, from the longer than standard borehole image as inputs to the machine learning model; and\nautomatically classifying, using the at least one processor, the training set into one or more priors for depositional environments, wherein the automatically classifying into the one or more priors includes: building one or more tables of sedimentary geometry successions that represent one or more depositional environments; and automatically obtaining, using the one or more tables, depositional environments from the training set of images.', '2.', 'The method of claim 1, wherein the automatically classifying into the one or more priors for the depositional environments includes applying one or more machine learning techniques.', '3.', 'The method of claim 1, wherein an addition of noise includes at least one of adding one or more masking stripes on one or more synthetic images of the synthetic images, adding one stripe on the one or more synthetic images, adding a one-pixel stripe to the one or more synthetic images, adding white noise to the one or more synthetic images, translating patterns on the one or more synthetic images, truncating the one or more synthetic images, or adding geometric noise.', '4.', 'The method of claim 1, further comprising:\nutilizing one or more automated individual sedimentary geometry predictions to establish a depositional environment predictor.', '5.', 'The method of claim 4, wherein the depositional environment predictor includes a decision tree-based machine-learning, fuzzy-logic based algorithms, or a probabilistic graphical model.', '6.', 'A system for automated stratigraphy interpretation from borehole images comprising:\na memory configured to store one or more borehole images;\nat least one processor configured to: construct a training set of images corresponding to a borehole, wherein the training set includes one or more of synthetic images, real images, and modified images; automatically classify the training set into one or more individual sedimentary geometries using a machine learning model that has been trained based on images generated from wells with multiple deviations to automatically recognize one or more sedimentary geometries from one or more borehole images, regardless of borehole deviation, wherein the automatically classifying comprises: identifying a longer than standard borehole image in the training set of images; and applying a sliding window as a spatial sampling technique based on the identifying the longer than standard borehole image, wherein the spatial sampling technique includes providing a plurality of cropped images, corresponding to the sliding window, from the longer than standard borehole image as inputs to the machine learning model; automatically classify the training set into one or more priors for depositional environments, wherein the automatically classifying into the one or more priors includes: building one or more tables of sedimentary geometry successions that represent one or more depositional environments; and automatically obtaining, using the one or more tables, depositional environments from the training set of images.', '7.', 'The system of claim 6, wherein constructing the training set includes a forward model to generate the synthetic images.', '8.', 'The method according to claim 1, wherein constructing the training set includes a forward model to generate the synthetic images.', '9.', 'The method according to claim 8 wherein constructing the training set further includes an addition of noise to the synthetic images.', '10.', 'The system of claim 7, wherein constructing the training set further includes an addition of noise to the synthetic images.', '11.', 'The system of claim 6, wherein the automatically classifying into the one or more priors for the depositional environments includes applying one or more machine learning techniques.\n\n\n\n\n\n\n12.', 'The system of claim 6, wherein an addition of noise includes at least one of adding one or more masking stripes on one or more synthetic images of the synthetic images, adding one stripe on the one or more synthetic images, adding a one-pixel stripe to the one or more synthetic images, adding white noise to the one or more synthetic images, translating patterns on the one or more synthetic images, truncating the one or more synthetic images, or adding geometric noise.', '13.', 'The system of claim 6, further comprising:\nutilizing one or more automated individual sedimentary geometry predictions to establish a depositional environment predictor.', '14.', 'The system of claim 13, wherein the depositional environment predictor includes a decision tree-based machine-learning, fuzzy-logic based algorithms, or a probabilistic graphical model.']

['FIG.', '1 is a system in accordance with the automated interpretation process of the present disclosure;; FIG.', '2 is a diagram illustrating interpreted causes of steepening-upward and shallowing-upward dip trends in sedimentary strata;; FIG.', '3 is a diagram illustrating a determination of one or more paleoflow directions using down-hole scan images;; FIG.', '4 is a diagram illustrating bedform morphology and vertical sections, horizontal and vertical sections, and polar plots of cross beds and bounding-surface dip directions;; FIG.', '5 is a block diagram illustrating how different computer images are arranged according to classification parameters;; FIG.', '6 is a diagram depicting examples of various computer models with matching field examples;; FIG. 7 is a diagram depicting an embodiment of a method of automated interpretation process in accordance with the present disclosure;; FIG. 8 is a diagram depicting examples of sequences of sedimentary geometries defining depositional environments;; FIG.', '9 is a block diagram depicting an embodiment of a method of automated interpretation process in accordance with the present disclosure;; FIG.', '10 is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;; FIG.', '11 is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;; FIG.', '12 is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;; FIG.', '13 is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;; FIG.', '14 is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;; FIG.', '15 a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure;; FIG.', '16 is a diagram depicting an embodiment of an automated interpretation process in accordance with the present disclosure; and; FIG.', '17 is a diagram depicting the LeNet-5 architecture.; FIG.', '5 further illustrates how the above mentioned computer program models are arranged according to classification parameters.', 'For example, a first computer program may calculate a topography of a bed surfaces and display the surface in a 3D perspective.', 'The resulting image may include both bed morphology and internal structures.', 'A second computer program may produce perspective block diagrams with horizontal sections instead of bed morphology at the top of the block.', 'Further, a third computer program may plot vectors that represent a migration of bedforms and scour pits.', 'Specifically, the third computer program may plot a direction of sediment transport represented by bedform migration azimuth.', 'It may also plot inclination of cross-bed and bounding-surface planes.']

US11820934

Microsphere compositions and methods for production in oil-based drilling fluids

Mar 10, 2020

Anders Grinrod

SCHLUMBERGER TECHNOLOGY CORPORATION

McClements, David Julian. “Advances in fabrication of emulsions with enhanced functionality using structural design principles.” Current Opinion in Colloid & Interface Science, vol. 17, issue 5 (2012), pp. 235-245. (Year: 2012).

6274174; August 14, 2001; Hom-ma; 7503404; March 17, 2009; McDaniel et al.; 10584272; March 10, 2020; Grinrod; 20090205824; August 20, 2009; Sullivan et al.; 20090205829; August 20, 2009; Sullivan et al.; 20100307744; December 9, 2010; Cochet

102626399; August 2012; CN; 0970705; January 2000; EP; 0187270; November 2001; WO

No images available

['A method includes admixing an aqueous polysaccharide solution into an oleaginous base fluid, and adding a divalent ion source to produce one or more polysaccharide microspheres.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE TO RELATED APPLICATIONS', 'This application is a divisional application of U.S. patent application Ser.', 'No. 15/371,394 filed Dec. 7, 2016, now U.S. Pat.', 'No. 10,584,272B2, which claims priority from U.S. Provisional Application No. 62/263,783 filed on Dec. 7, 2015.', 'The entire content of this application is explicitly incorporated herein by this reference.', 'BACKGROUND\n \nDuring the drilling of a wellbore, various fluids are used in the well for a variety of functions.', 'The fluids may be circulated through a drill pipe and drill bit into the wellbore, and then may subsequently flow upward through wellbore to the surface.', 'During this circulation, a drilling fluid may act to remove drill cuttings from the bottom of the hole to the surface, to suspend cuttings and weighting material when circulation is interrupted, to control subsurface pressures, to maintain the integrity of the wellbore until the well section is cased and cemented, to isolate the fluids from the formation by providing sufficient hydrostatic pressure to prevent the ingress of formation fluids into the wellbore, to cool and lubricate the drill string and bit, and/or to maximize penetration rate.', 'During drilling operations, variations in formation composition may lead to undesirable fluid loss events in which substantial amounts of wellbore fluid are lost to the formation through large or small fissures or fractures in the formation or through a highly porous rock matrix surrounding the borehole.', 'In response to various types of formation damage and fluid loss, wellbore fluids may also be circulated downhole to deliver agents to treat or mitigate such problems.', 'Treatment compositions may be water- or oil-based and may contain weighting agents, surfactants, proppants, viscosifiers, and fluid loss additives depending on the nature of the problem.', 'For example, treatments may include physical treatments that contain viscosifying agents or particulate solids that reduce the mobility of fluids into formation defects or form aggregates that obstruct fractures or pores downhole, or chemical treatments that include polymer- or gel-forming components and cements that harden or set up to produce seals downhole.', 'DETAILED DESCRIPTION', 'In one aspect, the present disclosure relates to the use of polysaccharide compositions to encapsulate various materials for delivery and controlled release of materials in various wellbore operations.', 'In one or more embodiments, polysaccharide microspheres may be prepared in an oleaginous base fluid and used directly or isolated and later recombined with a suitable base fluid.', 'In some embodiments, polysaccharide microspheres may be disrupted in response to an external stimulus or triggering event, releasing any stored materials.', 'Triggering events may include changes in temperature or pH; degradation of the polysaccharide encapsulant by enzymes, oxidants, or solvents; or physical disruption of the encapsulant, such as by shearing, grinding, pressure such as differential pressure, or crushing.', 'In one or more embodiments, polysaccharide microspheres may be produced using an emulsion-based assembly method that includes forming an internal phase containing a polysaccharide encapsulant in a water-in-oil or invert emulsion, followed by crosslinking the polysaccharide at the surface of microspheres.', 'In particular, when the aqueous polysaccharide solution is mixed with the oil, the solution phase may separate to produce spheres that may harden and crosslink when a divalent ion source, such as calcium, is added.', 'To this end, it is believed that adding the ion source creates ionic bonding at the surface of the water-in-oil droplets to create a hardened shell or crosslinkage.', 'Following formation of the microspheres in the emulsified wellbore fluid, the fluid may then be used in a selected wellbore operation such as drilling, drill-in operations, productions, spot treatments, etc.', 'In some embodiments, the polysaccharide microspheres may be isolated from an emulsion, and combined with a separate wellbore fluid or stored for future use.', 'In some embodiments, polysaccharide microspheres may be used as a carrier for an oil-soluble additive in an oil-based fluid.', 'For example, an aqueous solution of polysaccharide is mixed with the oil-soluble additive and crosslinked prior to or soon after mixing with the oil-based wellbore fluid in order to trap the oil-soluble additive in the forming microsphere.', 'In one embodiment, polysaccharide microspheres of the present disclosure may be present cross linked and/or in a discrete particulate state rather than dissolved in the bulk solution as may be found in standard polymer solutions.', 'The oil-soluble additive may then be released at a later time by disrupting the polysaccharide microsphere according to methods of the present disclosure at a designated time into the surrounding fluids.', 'In some embodiments, polysaccharide microspheres may be used as a carrier for time-release of chemical additives such as crosslinking agents for components present in a wellbore fluid, rheological modifiers, or polymer-forming species such as silicates or silylated polymers.', 'Polysaccharide microspheres in accordance with the present disclosure may be used for a variety of downhole applications including delivering fluid loss additives, film-formers, bridging agents, and creation of downhole structures.', 'Once formed, polysaccharide microspheres may be isolated and added to various treatment fluid compositions.', 'Treatment fluids may be aqueous or non-aqueous, and may be selected based on the treatment desired and on the specific polysaccharide used in formation of the microspheres.', 'Once crosslinked, polysaccharide microspheres may be filtered from the solution in some embodiments and dried using standard filter and drying equipment.', 'In some embodiments, a continuous mix process may be selected and equipment may be sized and scaled accordingly.', 'For example, in a lab scale embodiment, a polysaccharide is dissolved and hydrated in a blender.', 'The resulting viscous fluid is agitated continuously, and then introduced into an oleaginous base fluid.', 'The viscous polysaccharide solution may then separate into an internal phase of distinct domains or microspheres within the fluid.', 'The ongoing agitation prevents gravity-based settling or agglomeration until an added crosslinker reacts with the polysaccharide solution to produce hardened microspheres.', 'Polysaccharide microspheres in accordance with the present disclosure may be used to stabilize emulsions in some embodiments.', 'For example, a polysaccharide encapsulant may produce a hardened layer around an aqueous internal phase that capable of maintaining emulsion stability, particularly in applications where the surfactant becomes unstable or degrades prematurely.', 'In some embodiments, polysaccharide microspheres present in a circulating wellbore fluid may form a filter cake in the formation.', 'For example, polysaccharide microspheres may be deposited as the fluid accumulates on the walls of a wellbore as a filter cake in some embodiments.', 'After deposition into a filtercake, the polysaccharide microspheres may be degraded using the appropriate stimuli and release chemical agents to perform a number of functions depending on the particular wellbore operation, such as aiding filter cake degradation or strengthening the filter cake.', 'Polysaccharide Encapsulant', 'In one or more embodiments, polysaccharide microspheres may be produced from a number of polysaccharide encapsulants.', 'Polysaccharide encapsulants in some embodiments may be polysaccharides that are crosslinked through ionic or covalent bonding to a crosslinking agent.', 'In or more embodiments, polysaccharide encapsulants may include alginates, guars, guar derivatives such as hydropropyl guar (HPG), carboxymethyl guar (CMG), and carboxymethylhydroxypropyl guar (CMHPG).', 'Polysaccharide encapsulants may also include gums such as xanthan gum, diutan gum, and scleroglucan, cellulose derivatives such as hydroxyethylcellulose (HEC) or hydroxypropylcellulose (HPC), carboxymethylhydroxyethylcellulose (CMHEC), or the like.', 'Polysaccharide encapsulants may be combined with a crosslinker in some embodiments that facilitate intermolecular and intramolecular association of polysaccharide chains at the surface of a forming microsphere.', 'Suitable crosslinkers may include polyvalent ions such as borates, or metal cations such as calcium, magnesium, chromium, iron, aluminum, titanium, antimony, and zirconium, or mixtures of polyvalent ions.', 'In some embodiments, the crosslinker may be isolated from the polysaccharide encapsulant, depending on the application.', 'For example, adding crosslinkers to a fluid may augment the viscosity and it may be desirable in some instances to delay such a reaction in order to decrease the pumping pressure required for delivery.', 'In another embodiment, pH may be used to control the formation of ionic bonding between a polysaccharide encapsulant and a crosslinker.', 'In such an arrangement, an emulsion containing a polysaccharide encapsulant in the aqueous phase may be kept at a low pH in order to protonate functional groups responsible for interacting with the crosslinker.', 'When formation of the polysaccharide microspheres is desired, the pH may be then increased through the addition of a pH modifier such as a base or other buffering compound.', 'In particular embodiments, the polysaccharide microspheres may be designed such that an encapsulated reagent is released when exposed to shear forces, such as those that occur during injection of a wellbore fluid downhole.', 'For example, an encapsulated reagent may be injected into a wellbore and as the wellbore fluid containing the encapsulated reagent is exposed to shear forces that occur as the fluid exits an opening in a tubular, drill string, or drill bit, the shear forces may disrupt the encapsulating material and release the reagent into the surrounding fluid.', 'Thus, the release and delivery of an encapsulated reagent may be obtained by tuning the shear pressure of the fluid injection in the wellbore.', 'In one or more embodiments, the average particle size of the polysaccharide microspheres may range from a lower limit of 1 μm, 5 μm, and 10 μm, to an upper limit of 30 μm, 50 μm, and 100 μm, where the average particle size may range from any lower limit to any upper limit.', 'Average particle size may be determined using a number of methods including light scattering, laser diffraction, sieve analysis, and the like.', 'In one or more embodiments, a polysaccharide encapsulant may be used to prepare an aqueous solution prior to crosslinking that may be combined with various additives that become entrained in the solution and later within the formed microsphere after crosslinking.', 'Polysaccharide encapsulant solutions may be prepared at a concentration that ranges from 0.2 to 10.0 weight percent of aqueous solution in some embodiments, and from 1 to 8 weight percent in other embodiments.', 'In one or more embodiments, polysaccharide microspheres may be prepared to encapsulate additives and/or solvents, which are then delivered to a selected location downhole.', 'In some embodiments, materials encapsulated in the polysaccharide microspheres may be released when activated at the bit when shear or pressure drop disrupts the microspheres.', 'For example, an encapsulated component may be injected into a wellbore and shear forces that occur as the fluid exits an opening in a tubular, drill string, or drill bit, may disrupt the polysaccharide microspheres and release the encapsulated component.', 'Shear forces are closely related to the pressure drop experienced by a wellbore fluid passing through constrictions in various pumps, pipes, and drill-bits that may be present during a particular wellbore operation.', "This phenomenon is also known as the Venturi effect, which describes the physical process in which a fluid's velocity increases as it passes through a constriction to satisfy the principle of continuity, while its pressure decreases to satisfy the principle of conservation of mechanical energy.", 'The greater the pressure differential between two particular stages that a wellbore fluid passes through (e.g., a change in diameter of a length of pipe or tubing), the greater the proportional pressure drop and shear force the fluid experiences.', 'For example, shear forces may be highest when a fluid passes through narrow openings or nozzles on a drill bit or a port of completion string downhole.', 'Thus, targeted delivery of the encapsulated materials may be achieved in some embodiments by tuning the durability of polysaccharide microspheres through concentration or crosslinking chemistry, by adjusting the pumping pressure of the wellbore fluids, or the opening sizes of the tools through which fluids are injected.', 'In one or more embodiments, polysaccharide microspheres may be designed such that the coating ruptures when exposed to shear forces that may range from 10,000 to 30,000 s\n−1 \nin some embodiments, or from 12,000 to 25,000 s\n−1 \nin other embodiments.', 'Breaker Agents', 'In some embodiments, degradation of polysaccharide microspheres may be initiated or accelerated by contact with a breaking agent that disrupts the crosslinks within the polysaccharide layer forming the microspheres, or degrades the backbone chain of the polysaccharide encapsulant.', 'In one or more embodiments, a breaking agent may include acids such as organic acids such as acetic acid and formic acid, or mineral acids such as phosphoric acid, hydrochloric acid, nitric acid, hydrobromic acid, hydrofluoric acid, perchloric acid, and the like.', 'In some embodiments, polysaccharide microspheres may be injected with a delayed acid source that produces acid at a time period after combination, which may allow materials encapsulated in the microspheres to be delivered to greater depths in the wellbore and/or into the formation.', 'Delayed acid sources may hydrolyze to form acids in situ, for example, by hydrolysis of an ester or anhydride to produce an organic acid.', 'Illustrative examples of delayed acid sources in accordance with embodiments of the present disclosure include esters of carboxylic acids, anhydrides of carboxylic acids, esters of phosphonic acid, esters of sulfonic acid and other similar hydrolyzable compounds that are known to those skilled in the art.', 'In some embodiments, a delayed acid source may include an ester that hydrolyzes to produce the corresponding carboxylic acid.', 'Suitable esters may include formic or acetic acid ester of a C\n4\n-C\n30 \nalcohol, which may be mono- or polyhydric.', 'In one or more embodiments, a delayed acid source may include an aliphatic polyester such as polyglycolic acid, polylactic acid, polymers or co-polymers of esters that include, for example, substituted and unsubstituted polylactide, polyglycolide, polylactic acid, poly(lactic-co-glycolic acid), polyglycolic acid, poly(ε-caprolactone), and the like.', 'In some embodiments, internal breakers in accordance with the present disclosure may contain one or more selected from homo- or copolymers of lactic acid and glycolic acid as well as compounds containing hydroxy, phenoxy, carboxylic, hydroxycarboxylic or phenoxycarboxylic moieties.', 'In some embodiments, chelating agents may be introduced into a fluid containing polysaccharide microspheres in order to trigger degradation by sequestering ionic species crosslinking the polysaccharide chains on the surfaces of the microspheres.', 'Chelating agents suitable for use in the breaker fluids of the present disclosure may include polydentate chelating agents such as ethylenediaminetetraacetic acid, diethylenetriaminepentaacetic acid, nitrilotriacetic acid, ethylene glycol-bis(2-aminoethyl)-N,N,N′,N′-tetraacetic acid, 1,2-bis(o-aminophenoxy)ethane-N,N,N′,N′-tetraceticacid, cyclohexanediaminete-traacetic acid, triethylenetetraminehexaacetic acid, N-(2-Hydroxyethyl)ethylenediamine-N,N′,N′-triacetic acid, glutamic-N,N-diacetic acid, ethylene-diamine tetra-methylene sulfonic acid, diethylene-triamine penta-methylene sulfonic acid, amino tri-methylene sulfonic acid, ethylene-diamine tetra-methylene phosphonic acid, diethylene-triamine penta-methylene phosphonic acid, amino tri-methylene phosphonic acid, and mixtures thereof.', 'Such chelating agents may include potassium or sodium salts thereof in some embodiments.', 'However, this list is not intended to have any limitation on the chelating agents (or salt types) suitable for use in the embodiments disclosed herein.', 'In one or more embodiments, polysaccharide microspheres may also be degraded by adding an enzyme to degrade glycosidic linkages in the constituent polysaccharide.', 'Natural polymer degrading enzymes in accordance with the present disclosure may be selected from, for example, carbohydrases, amylases, pullulanases, and cellulases.', 'In some embodiments, the enzyme may be selected from endo-amylase, exo-amylase, isoamylase, glucosidase, amylo-glucosidase, malto-hydrolase, maltosidase, isomalto-hydrolase, malto-hexaosidase, or alginate lyase.', 'One skilled in the art would appreciate that selection of an enzyme may depend on various factors such as the type of polymeric additive used in the wellbore fluid being degraded, the temperature of the wellbore, and the pH of wellbore fluid.', 'Wellbore Fluids\n \nWellbore fluids may contain a base fluid that is entirely aqueous base or contains a full or partial oil-in-water or water-in-oil emulsion.', 'In some embodiments, the wellbore fluid may be any water-based fluid that is compatible with the accretion inhibiting compositions disclosed herein.', 'In some embodiments, the fluid may include at least one of fresh water, mixtures of water and water soluble organic compounds and mixtures thereof.', 'Wellbore fluids in accordance with the present disclosure may also include oleaginous base fluids such as natural or synthetic oils, including diesel oil, mineral oil, hydrogenated and unhydrogenated olefins including polyalpha olefins, linear and branch olefins and the like, polydiorganosiloxanes, siloxanes, or organosiloxanes, esters of fatty acids, specifically straight chain, branched and cyclical alkyl ethers of fatty acids, mixtures thereof, and similar compounds known to one of skill in the art.', 'In various embodiments, the wellbore fluid may contain a brine such as seawater, aqueous solutions wherein the salt concentration is less than that of sea water, or aqueous solutions wherein the salt concentration is greater than that of sea water.', 'Salts that may be found in seawater include, but are not limited to, sodium, calcium, aluminum, magnesium, potassium, strontium, lithium, and salts of chlorides, bromides, carbonates, iodides, chlorates, bromates, formates, nitrates, oxides, sulfates, phosphates, silicates and fluorides.', 'Salts that may be incorporated in a given brine include any one or more of those present in natural seawater or any other organic or inorganic dissolved salts.', 'Additionally, brines that may be used in the drilling fluids disclosed herein may be natural or synthetic, with synthetic brines tending to be much simpler in constitution.', 'One of ordinary skill would appreciate that the above salts may be present in the base fluid or may be added according to the method disclosed herein.', 'Further, the amount of the aqueous based continuous phase should be sufficient to form a water based drilling fluid.', 'This amount may range from nearly 100% of the wellbore fluid to less than 30% of the wellbore fluid by volume.', 'In some embodiments, the aqueous based continuous phase may constitute from about 95 to about 30% by volume or from about 90 to about 40% by volume of the wellbore fluid.', 'EXAMPLE', 'A method may be shown for producing polysaccharide microspheres in an invert emulsion in accordance with the present disclosure.', 'A 2% by weight solution of sodium alginate was prepared and mixed into a divalent cation-free brine.', 'The mixture was then emulsified into a mineral oil base fluid.', 'Next, the alginate in the dispersed aqueous phase was crosslinked by adding a dilute calcium chloride solution.', 'Upon addition of a the calcium chloride to the invert emulsion, the water droplets crosslinked almost instantaneously, and the internal aqueous phase droplets became encapsulated in a relatively mechanically strong microsphere.', 'Formation of microspheres was verified by optical microscopy.', 'Although the preceding description has been described herein with reference to particular means, materials, and embodiments, it is not intended to be limited to the particulars disclosed herein; rather, it extends to all functionally equivalent structures, methods and uses, such as are within the scope of the appended claims.']

['1.', 'A method comprising:\ndispersing an aqueous polysaccharide solution into an oleaginous base fluid; and\nadding a divalent ion source to produce one or more polysaccharide microspheres within the oleaginous base fluid, wherein the oleaginous base fluid is an oil-based mud; and wherein the polysaccharide microspheres contain an oil-soluble additive; wherein the oil-soluble additive comprises crosslinking agents, rheological modifiers, a polymer-forming species, or a combination thereof.', '2.', 'The method of claim 1, further comprising dispersing the oil-soluble additive within the aqueous polysaccharide solution prior to dispersing the aqueous polysaccharide solution into the oleaginous base fluid.', '3.', 'The method of claim 1, wherein the crosslinking agent is mixed with the aqueous polysaccharide solution prior to dispersing the aqueous polysaccharide solution into the oleaginous base fluid.', '4.', 'The method of claim 1, wherein the crosslinking agent is mixed with the aqueous polysaccharide solution after dispersing the aqueous polysaccharide solution into the oleaginous base fluid.', '5.', 'The method of claim 1, wherein the aqueous polysaccharide solution contains a polysaccharide at a concentration of 1 to 8 weight percent of the aqueous solution.', '6.', 'The method of claim 1, further comprising isolating the one or more polysaccharide microspheres and combining the isolated one or more polysaccharide microspheres with a wellbore fluid.', '7.', 'The method of claim 6, wherein the wellbore fluid is an aqueous fluid or an oil-in-water emulsion.', '8.', 'The method of claim 6, wherein the wellbore fluid is an oleaginous fluid or an invert emulsion.', '9.', 'The method of claim 1, wherein the polysaccharide is alginate.', '10.', 'The method of claim 1, wherein the adding the divalent ion source causes crosslinking of the polysaccharide in the aqueous polysaccharide solution.', '11.', 'The method of claim 1, wherein the polymer-forming species are selected from a group of silicates and silylated polymers.']

['No Captions Available']

US11931822

System and methodology for welding

Oct 19, 2020

Hongfa Huang

Schlumberger Technology Corporation

Extended European Search Report issued in European Patent Application No. 18888887.9 dated Nov. 9, 2021, 6 pages.; International Search Report and Written opionion issued in the related PCT application PCT/2015/056161, dated Dec. 21, 2015 (16 pages).; International Preliminary Report on Patentability issued in the related PCT application PCT/2015/056161, dated May 2, 2017 (12 pages).; Yehuda Meir and Eli Jerby, Underwater Microwave Ignition of Hydrophobic Thermite Powder Enabled by Magnetic Encapsulation, Conference: 14th International Conference on Microwave and High Frequency Heating, Nottingham, UK, Sep. 2013 (4 pages).; Extended Search Report issued in the related EP Application 17193207.2 dated May 18, 2018 (8 pages).; Extended Search Report issued in the related EP Application 15855623.3 dated Jun. 29, 2018 (7 pages).; Office Action issued in the related U.S. Appl. No. 15/275,948 dated Jul. 3, 2018 (20 Pages).; Exam Report issue in the related EP Application No. 17193207.2 dated Apr. 9, 2019, 6 pages.; Office Action issued in the related U.S. Appl. No. 15/520,853 dated Mar. 19, 2019, 32 pages.; International Search Report and Written Opinion of International Patent Application No. PCT/US2018/065590 dated Mar. 27, 2019, 13 pages.; Office Action issued in the related U.S. Appl. No. 15/275,948 dated Jun. 4, 2019, 18 pages.; Office Action issued in the related U.S. Appl. No. 15/988,098 dated Dec. 26, 2019, 40 pages.; Communication pursuant to Article 94(3) EPC issued in the related EP Application 15855623.3 dated Jan. 27, 2020, 6 pages.; Notice of Allowance issued in the related U.S. Appl. No. 15/988,098 dated May 20, 2020, 15 pages.; International Preliminary Report on Patentability issued in the related PCT application PCT/2018/065590 dated Jun. 25, 2020, 9 pages.; Notice of Allowance issued in the related U.S. Appl. No. 16/939,954 dated Apr. 14, 2021, 20 pages.

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2065750; July 1981; GB; 2013135583; September 2013; WO; 2014138444; September 2014; WO; 2016069305; May 2016; WO; 2016161283; October 2016; WO

['A technique facilitates a welding operation in a variety of difficult environments, including downhole environments, to enable formation of a dependable connection between components.', 'A tool may be constructed to contain a material mixture used in the welding operation.', 'The tool is conveyed to a position adjacent a weld region of components to be welded together.', 'The material mixture is of a type which may be ignited to initiate a reaction which forms a molten metal from at least one constituent in the material mixture.', 'Additionally, the tool comprises a nozzle oriented to direct the molten metal to the weld region so as to form a secure, welded connection between the components.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is a divisional of U.S. patent application Ser.', 'No. 15/275,948 filed 26 Sep. 2016, now U.S. Pat.', 'No. 10,807,189, which is herein incorporated by reference.', 'BACKGROUND', 'In a variety of well applications many types of components are joined in sealing engagement.', 'For example, plugs may be deployed downhole and actuated to form a sealing engagement with a surrounding tubing, e.g. casing.', 'The plugs often comprise an elastomeric element which may be expanded to form a seal with the interior surface of the surrounding tubing.', 'Other types of components also may be joined with tubing or with other downhole devices to form a permanent connection and/or seal.', 'However, the process for joining components in a downhole environment can be difficult, particularly if the region is flooded with well fluid.', 'Additionally, elastomeric elements may be susceptible to the adverse conditions often found in downhole environments.', 'SUMMARY', 'In general, a system and methodology facilitate welding in a variety of difficult environments, including downhole environments, to enable formation of a dependable connection between components.', 'According to an embodiment, a material mixture is employed in a tool, and the tool is conveyed to a position adjacent a weld region of components to be welded together.', 'The material mixture is of a type which may be ignited to initiate a reaction which causes formation of a molten metal from at least one constituent in the material mixture.', 'The tool also may comprise a nozzle oriented to direct the molten metal to the weld region so as to form a secure, welded connection between the components.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is a schematic illustration of an example of a well string carrying a welding tool down into a subsurface borehole, according to an embodiment of the disclosure;\n \nFIG.', '2\n is an illustration of an example of a welding tool deployed in a borehole and positioned for welding components together while downhole in the borehole, according to an embodiment of the disclosure;\n \nFIG.', '3\n is an illustration of another example of a welding tool deployed in a borehole and positioned for welding components together while downhole in the borehole, according to an embodiment of the disclosure;\n \nFIG.', '4\n is an illustration of another example of a welding tool deployed in a borehole and positioned for welding components together while downhole in the borehole, according to an embodiment of the disclosure;\n \nFIG.', '5\n is an illustration similar to that of \nFIG.', '2', 'but during a different stage of the welding operation, according to an embodiment of the disclosure;\n \nFIG.', '6\n is an illustration of an example of welded components after performance of the welding operation, according to an embodiment of the disclosure; and\n \nFIG.', '7\n illustrates a table listing examples of various constituents which may be mixed to form a reactive material mixture used in the welding tool, according to an embodiment of the disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'The present disclosure generally relates to a system and methodology which facilitate welding in a variety of difficult environments to enable formation of a dependable connection between components.', 'For example, the system and methodology facilitate welding in downhole environments and in submerged, e.g. underwater, environments.', 'The technique may be used for welding components within well tubing to form strong, sealed connections between, for example, tubing plugs and surrounding casing or other tubing.', 'The welding may be performed in subsea environments and in wellbore environments in which the wellbore is filled with mud, water, or other fluids.', 'However, the technique also may be used for surface applications to join components within tubing or in other difficult to reach locations.', 'According to an embodiment, a material mixture is installed in a tool, and the tool is conveyed to a position adjacent a weld region of components to be welded together.', 'The material mixture is of a type which may be ignited to initiate a reaction which forms a molten metal from at least one constituent in the material mixture.', 'By way of example, the material mixture may be a mixture of a metal powder fuel and a metal oxide which undergo an exothermic reaction.', 'Additionally, the tool may comprise a nozzle oriented to direct the molten metal to the weld region so as to form a secure, welded connection between the components.', 'Various additives may be combined with the material mixture to control aspects of the exothermic reaction, e.g. to control the reaction rate, to generate gas for clearing liquid from the weld region, to generate heat for preheating of the weld components, and/or to control other aspects of the reaction.', 'In various embodiments, the material mixture is in the form of thermite which is a pyrotechnic composition of the metal powder fuel and the metal oxide.', 'For example, thermite may comprise an iron oxide and an aluminum powder mixture which can be ignited to react and release a large amount of heat in a short time.', 'The material mixture also results in a molten elemental metal produced by the thermite reaction.', 'This molten metal may be used to weld components in many types of environments, e.g. to weld components in a downhole environment.', 'In a specific example, a downhole tool, e.g. a plug, may be welded to surrounding well casing by directing the molten metal to the desired weld region between those components.', 'The thermite also may be formed from other material mixtures that are able to undergo the exothermic reduction-oxidation reaction which generates substantial heat and results in the molten metal.', 'The material mixture of the thermite may be adjusted to achieve a desired heat output and temperature for producing the desired resultant components, such as a separated molten metal and slag.', 'For example, the size of the particles forming the material mixture may be selected so as to achieve a desired burn rate or reaction rate.', 'Additionally, alloying elements such as carbon and silicon may be added to the material mixture to cause formation of molten metal in the form of grey cast iron which expands when solidifying.', 'The expansion can be useful when, for example, welding parts along the interior of well casing so as to push the casing outwardly rather than pulling the casing inwardly.', 'Additives also may be added to the material mixture to provide desired mechanical and corrosion properties with respect to the resultant weld.', 'The material mixture also may comprise additives to help provide an initial blow of high temperature flame which may be directed to preheat the components to be welded at a weld region.', 'Additives also may be used to initially create gas during the thermite reaction so as to clear liquid from around the region to be welded, thus assisting in forming a dependable weld.', 'Once the liquid is cleared the molten metal, e.g. molten iron, may be directed through a nozzle and driven to a gap between the components being welded, e.g. to the gap between a plug and a surrounding well casing.', 'The generation of gas also may be used to help force the molten metal through the nozzle.', 'The ability to form a weld between the plug and the well casing creates a much stronger connection than provided by the friction force associated with conventional mechanical plugs or elastomeric elements.', 'Referring generally to \nFIG.', '1\n, an example of a system \n20\n for welding in a downhole subsurface environment, e.g. a subsea downhole environment, is illustrated.', 'In this embodiment, the system \n20\n comprises a welding tool \n22\n which may be deployed downhole into a borehole \n24\n, e.g. a wellbore.', 'The welding tool \n22\n may be conveyed downhole via a conveyance \n26\n which may be in the form of a well string comprising coiled tubing, other tubing, wireline, or other suitable conveyance.', 'The welding tool \n22\n is deployed into proximity with components \n28\n to be welded together.', 'In a specific example, the components \n28\n to be welded may comprise a plug \n30\n and a surrounding casing \n32\n.', 'The welding tool \n22\n is utilized in forming a weld between the plug \n30\n and casing \n32\n so as to plug and seal the borehole \n24\n.', 'In some applications, at least one of the components \n28\n, e.g. plug \n30\n, may be attached to welding tool \n22\n and conveyed downhole to a desired welding location, thus effectively placing welding tool \n22\n proximate the components \n28\n to be welded.', 'Additionally, the plug \n30\n may be constructed with particular structures selected according to parameters of specific applications.', 'The welding tool \n22\n may be operated in a variety of well related environments and other environments for joining many types of components \n28\n.', 'By way of example, the welding tool \n22\n may be deployed via conveyance \n26\n to a subsea well \n34\n at a seabed \n36\n.', 'The welding tool \n22\n may be deployed from a sea surface \n38\n, down through a riser \n40\n, and into wellbore \n24\n until positioned proximate the components \n28\n to be welded.', 'In various subsea applications and other well related or non-well related applications, the welding tool \n22\n may be submerged into a liquid \n42\n and the welding operation may be performed at the submerged location.', 'In well applications, the liquid \n42\n may comprise a variety of well fluids, e.g. water, mud, or hydrocarbon-based fluids.', 'Welding tool \n22\n may be constructed to facilitate formation of dependable welds and component couplings even when the welding tool \n22\n is submerged in liquid \n42\n.', 'Referring generally to \nFIG.', '2\n, an example of welding tool \n22\n is illustrated as deployed in a borehole \n24\n.', 'In this embodiment, the tool \n22\n has been conveyed downhole into borehole \n24\n until at a desired location which is proximate the components \n28\n, e.g. plug \n30\n and casing \n32\n, to be welded.', 'The welding tool \n22\n may comprise a housing \n44\n for containing a material mixture \n46\n of, for example, a metal powder fuel \n48\n and a metal oxide \n50\n.', 'By way of example, the material mixture \n46\n may comprise thermite and the metal powder fuel \n48\n and metal oxide \n50\n may comprise powder aluminum and iron oxide, respectively.', 'When the material mixture \n46\n is ignited an exothermic reaction is caused between the elemental aluminum \n48\n and iron oxide \n50\n and the resulting products are aluminum oxide, elemental iron, and a large amount of heat.', 'The elemental iron may be produced as a molten metal for welding, as described in greater detail below.', 'It should be noted that the reactants \n48\n, \n50\n may comprise various other materials, e.g. elemental aluminum and copper oxide, which may be ignited to cause the desired exothermic reaction.', 'Within housing \n44\n, the reactants \n48\n, \n50\n may be mixed in powdered form, combined with a binder which holds the material mixture \n46\n together, and compacted so as to avoid unwanted separation of constituents.', 'In the embodiment illustrated, the welding tool \n22\n further comprises at least one igniter \n52\n which may be selectively actuated to ignite the material mixture \n46\n and cause the exothermic reaction between the elemental metal fuel \n48\n and the metal oxide \n50\n.', 'By way of example, the igniter \n52\n may be positioned toward the top and/or bottom (see igniter in dashed lines) of the material mixture \n46\n.', 'The igniter \n52\n may be constructed in various forms able to ignite the material mixture \n46\n, but one example is an electrically actuated igniter.', 'In this latter example, the igniter \n52\n is coupled with an electrical power controller \n54\n by a suitable control line \n56\n which conveys electrical control signals from controller \n54\n to igniter \n52\n when ignition of material mixture \n46\n is desired.', 'By way of example, the electrical power controller \n54\n or other control system may be located at the surface.', 'The welding tool \n22\n also may comprise a nozzle \n58\n positioned to direct the molten metal resulting from the exothermic reaction to a desired weld region along components \n28\n.', 'The nozzle \n58\n comprises an inlet region \n60\n for receiving products, e.g. molten metal, resulting from the exothermic reaction of material mixture \n46\n.', 'After ignition of material mixture \n46\n, the resulting products are able to flow down through housing \n44\n and into nozzle \n58\n through inlet region \n60\n.', 'The nozzle \n58\n further comprises an outlet region \n62\n, e.g. a jet, constructed and positioned to direct the products of the exothermic reaction to a desired weld region \n64\n.', 'If, for example, plug \n30\n is to be welded to surrounding casing \n32\n, the outlet region/jet \n62\n may have an annular configuration to direct a reaction product, e.g. molten metal, to the annular space between plug \n30\n and casing \n32\n.', 'Because of the substantial heat of the products handled by nozzle \n58\n, the nozzle \n58\n may be constructed from graphite or another suitable, heat resistant material.', 'Referring generally to \nFIG.', '3\n, another embodiment of welding tool \n22\n is illustrated.', 'In this example, an additive feature \n66\n may be added to the material mixture \n46\n to control an aspect of the exothermic reaction when the material mixture \n46\n is ignited.', 'In some embodiments, as illustrated in \nFIG. \n3\n, the additive feature \n66\n may be in the form of physical features \n68\n formed in the bound powder material of reactants \n48\n, \n50\n.', 'The physical features \n68\n may comprise recesses, e.g. holes, passages, gaps, or other physical features \n68\n, e.g. variations in density, within material mixture \n46\n.', 'The physical features \n68\n may be arranged to control, for example, the burn rate or the amount of heat produced so as to achieve the desired application of molten metal during the welding process.', 'In some applications, it is useful to preheat the components \n28\n at weld region \n64\n so as to ensure a better weld and better seal between the components \n28\n.', 'The additive feature \n66\n, e.g. physical features \n68\n, may be used to create a reaction rate able to promote initial preheating of the components \n28\n prior to receiving the molten metal used to form the weld.', 'As illustrated in the embodiment of \nFIG.', '4\n, the additive feature \n66\n also may comprise material constituents \n70\n combined with material mixture \n46\n at specific regions \n72\n or throughout the material mixture \n46\n.', 'The constituent additive \n70\n may comprise materials used to produce a controlled initial flame for preliminary heating of components \n28\n at weld region \n64\n.', 'However, the constituent additive \n70\n also may comprise materials which cause an initial production of gas which is directed through nozzle \n58\n to the weld region \n64\n.', 'The initial production of gas can be used to create gas pressure which drives out liquid from the weld region \n64\n to ensure an improved weld quality.', 'Additionally, the additive \n70\n may be arranged so the generation of gas is created at an appropriate location within housing \n44\n to help drive out the molten metal into the weld region \n64\n.', 'It should be noted that a variety of other types of constituent additives \n70\n, e.g. alloying elements, may be combined with material mixture \n46\n to enhance various aspects of the welding operation according to the parameters of a given application.', 'In some embodiments, additional molten metal may be initially driven to or through the weld region \n64\n to preheat components \n28\n at weld region \n64\n.', 'The delivery of molten metal to preheat the weld region \n64\n also can be used to gasify liquid \n42\n collected in the weld region \n64\n, thus again driving the liquid \n42\n from weld region \n64\n to ensure a desired weld quality.', 'By way of example, various metal nitrates, e.g. strontium nitrate, may be mixed into the thermite material mixture \n46\n to enhance the generation of gas during the exothermic reaction.', 'This gas may then be directed through nozzle \n58\n to the weld region \n64\n or may be used to drive molten metal into or through weld region \n64\n.', 'According to an embodiment of a welding operation, the welding tool \n22\n is deployed to a desired position, e.g. a position proximate components \n28\n.', 'Once in the desired position, a control signal is sent by controller \n54\n through control line \n56\n to igniter \n52\n.', 'The igniter \n52\n is thus actuated, e.g. sparked, electrically arced, or otherwise suitably actuated, to ignite the material mixture \n46\n, e.g. thermite.', 'Ignition of material mixture \n46\n causes the desired exothermic reaction between the elemental metal \n48\n and the metal oxide \n50\n.', 'Depending on the additive or additives \n66\n, the rate of the reaction, the gas production, and/or other aspects of the exothermic reaction may be controlled to, for example, provide the desired preheating of components and/or clearing of liquid from the weld area \n64\n.', 'Regardless, the exothermic reaction creates a molten metal \n74\n which flows from housing \n44\n of welding tool \n22\n and into the desired weld region \n64\n, as illustrated in \nFIG.', '5\n.', 'In various applications, the molten metal \n74\n may comprise molten iron which forms a weld to create a strong, sealed connection between the components \n28\n.', 'In some applications, the liquid \n42\n, e.g. water, brine, oil, may be used to quench the initial flow of molten metal \n74\n and to thus form a barrier which prevents escape of subsequently delivered molten metal \n74\n.', 'Once a sufficient amount of molten metal \n74\n is delivered from housing \n44\n into the desired region \n64\n, the welding tool \n22\n (e.g. the remaining housing \n44\n and nozzle \n58\n) may be removed, as illustrated in \nFIG.', '6\n.', 'The molten metal \n74\n solidifies at weld region \n64\n to form a solid weld \n76\n.', 'In the plug example, the solid weld \n76\n is formed around the circumference of plug \n30\n between the plug \n30\n and the surrounding casing \n32\n.', 'Consequently, the plug \n30\n is held securely in place along casing \n32\n and sealed with respect to casing \n32\n so that fluid is no longer able to flow past plug \n30\n along the interior of the casing.', 'The welding tool \n22\n may be used in a wide variety of applications and environments.', 'For example, the welding tool \n22\n is amenable to use underwater or submerged in other liquids.', 'In such embodiments, the material mixture \n46\n may be packed into a desired shape with the appropriate additive or additives \n66\n to create an initial high temperature flame and gas production.', 'In this manner, the welding tool \n22\n may be used to create a transient gas environment at the weld region \n64\n to facilitate welding in the submerged environment.', 'The flame and initial hot gas also may be used to preheat the components \n28\n at weld region \n64\n to further facilitate successful welding.', 'In some applications, the gas atmosphere may be created by forcing out sufficient molten metal \n74\n, e.g. molten iron, to preheat components \n28\n at weld region \n64\n and to boil off the water or other liquid at weld region \n64\n.', 'Quenching of the initial flow of molten metal \n74\n also can be used to effectively establish a restriction which prevents escape of the subsequent flow of molten metal \n74\n.', 'It should be noted that if the gap between components \n28\n is relatively large, a filler stick or filler ring may be added to prevent escape of the molten metal \n74\n from weld region \n64\n.', 'By using thermite as the material mixture \n46\n, a pure metal element, e.g. iron or copper, may be provided in molten metal form to the desired weld region \n64\n.', 'However, the material mixture \n46\n may be adjusted to accommodate different welding operations and welding environments.', 'For example, many types of metal oxides \n50\n and metal fuels \n48\n may be used to obtain a desired molten metal \n74\n.', 'Additionally, various gas generating constituents, e.g. metal nitrates, may be added to material mixture \n46\n to provide a desired amount and rate of gas generation.', 'Many types of physical features or alloying elements also may be added to material mixture \n46\n to adjust the reaction rate, the heat produced, or other characteristics of the exothermic reaction.', 'As illustrated in the table of \nFIG.', '7\n, several types of metal oxides \n50\n and metal fuels \n48\n may be combined to obtain the desired molten metal \n74\n.', 'Additionally, many types of constituents \n70\n, e.g. gas generating constituents or alloying element constituents, may be combined into the material mixture \n46\n, as further illustrated in \nFIG.', '7\n.', 'The welding tool \n22\n may be used in many downhole operations for welding components within a wellbore.', 'Examples include welding a metal ring to a surrounding tubing to provide stronger support with a smaller packer package, welding a metal plug or disk to the surrounding tubing, or welding to form a simple, strong, and sealed connection between components downhole.', 'These are just a few examples of many well related and non-well related applications for welding tool \n22\n.', 'Depending on the parameters of a given application, welding tool \n22\n may be constructed in a variety of sizes and configurations.', 'For example, the size and shape of tool housing \n44\n may be adjusted according to the type of weld to be formed and to accommodate the desired amount of material mixture \n46\n.', 'In a variety of applications, the material mixture \n46\n may be formed from powdered constituents which are mixed and compacted into a disk or other desired form.', 'The igniter or igniters \n52\n may have a variety of structures and may be placed at various locations in contact with material mixture \n46\n.', 'Similarly, the nozzle \n58\n may have a variety of configurations and be made from graphite or other materials suitable for a given application.', 'In some applications the nozzle \n58\n may be constructed from or may comprise other materials, such as tungsten, tantalum, molybdenum, or other suitable heat resistant materials.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A system, comprising:\na welding tool having: a tool housing; a thermite mixture contained in the tool housing; a thermite igniter configured to selectively ignite the thermite mixture in the tool housing to form a molten metal; and a nozzle coupled to the tool housing and comprising an inlet region, an outlet region, a flow path from the inlet region to the outlet region, and an outer wall disposed about the flow path, wherein the outlet region has an annular opening defined by an inner surface of the outer wall and an opposing surface, wherein the annular opening of the outlet region is disposed at a distal end of the nozzle, wherein the inner surface has a first taper with an increasing width from the inlet region to the outlet region, wherein the first taper extends to the distal end of the nozzle around the annular opening, wherein the inlet region of the nozzle is configured to receive the molten metal from the tool housing and direct the molten metal from the annular opening of the nozzle to a desired annular-shaped region, and wherein the outer wall comprises an outer surface having a second taper from the inlet region to the outlet region.', '2.', 'The system of claim 1, further comprising a well string coupled to the welding tool to convey the welding tool downhole into a wellbore.\n\n\n\n\n\n\n3.', 'The system of claim 1, wherein the thermite mixture comprises aluminum powder and iron oxide.', '4.', 'The system of claim 1, wherein the thermite mixture comprises a gas generating metal nitrate.', '5.', 'The system of claim 1, wherein the thermite mixture is formed with recessed areas to provide a desired production of heat and the molten metal.\n\n\n\n\n\n\n6.', 'The system of claim 1, wherein the nozzle comprises a graphite material.', '7.', 'The system of claim 1, wherein the thermite mixture comprises a metal powder fuel and a metal oxide.', '8.', 'The system of claim 1, wherein the thermite mixture comprises an additive that includes a gas generating constituent.', '9.', 'The system of claim 1, wherein the thermite mixture comprises an additive configured to preheat one or more components to be welded at the desired annular-shaped region.', '10.', 'The system of claim 1, wherein the thermite mixture comprises one or more alloying elements.', '11.', 'The system of claim 10, wherein the one or more alloying elements comprises carbon or silicon.\n\n\n\n\n\n\n12.', 'The system of claim 1, wherein the thermite mixture comprises aluminum and copper oxide.', '13.', 'The system of claim 4, wherein the gas generating metal nitrate is strontium nitrate.', '14.', 'The system of claim 1, wherein the outer wall decreases in thickness in a direction from the inlet region toward the outlet region.', '15.', 'The system of claim 1, wherein the annular opening is defined by the first taper of the inner surface of the outer wall and an opposing taper of the opposing surface.', '16.', 'The system of claim 1, wherein the first taper and the annular opening of the nozzle is configured to direct the molten metal in an outwardly angled direction relative to a central axis from the outlet region of the nozzle to the desired annular-shaped region.', '17.', 'A system, comprising:\na welding tool having: a tool housing configured to receive a thermite mixture; a thermite igniter configured to selectively ignite the thermite mixture in the tool housing to form a molten metal; and a nozzle coupled to the tool housing and comprising an inlet region, an outlet region, a flow path from the inlet region to the outlet region, and an outer wall disposed about the flow path, wherein the outlet region has an annular opening, wherein an inner surface of the outer wall has a first taper and an outer surface of the outer wall has a second taper, wherein the first and second tapers increase in width in a downstream direction from the inlet region toward the outlet region, wherein the inlet region of the nozzle is configured to receive the molten metal from the tool housing and direct the molten metal from the annular opening of the nozzle to a desired annular-shaped region.', '18.', 'The system of claim 17, wherein the outer wall decreases in thickness between the first and second tapers in the downstream direction from the inlet region toward the outlet region.', '19.', 'The system of claim 17, wherein the first and second tapers extend to a distal end of the outer wall of the nozzle.']

['FIG.', '1 is a schematic illustration of an example of a well string carrying a welding tool down into a subsurface borehole, according to an embodiment of the disclosure;; FIG.', '2 is an illustration of an example of a welding tool deployed in a borehole and positioned for welding components together while downhole in the borehole, according to an embodiment of the disclosure;; FIG.', '3 is an illustration of another example of a welding tool deployed in a borehole and positioned for welding components together while downhole in the borehole, according to an embodiment of the disclosure;; FIG.', '4 is an illustration of another example of a welding tool deployed in a borehole and positioned for welding components together while downhole in the borehole, according to an embodiment of the disclosure;; FIG.', '5 is an illustration similar to that of FIG.', '2', 'but during a different stage of the welding operation, according to an embodiment of the disclosure;; FIG. 6 is an illustration of an example of welded components after performance of the welding operation, according to an embodiment of the disclosure; and; FIG.', '7 illustrates a table listing examples of various constituents which may be mixed to form a reactive material mixture used in the welding tool, according to an embodiment of the disclosure.']

US11899243

System and method for joining fiber optic cables

Apr 25, 2022

Zhanke Liu, Mark Oettli, Shrividya Sridharan

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent application PCT/US2023/019612 dated Aug. 24, 2023, 10 pages.

4580874; April 8, 1986; Winter; 4585287; April 29, 1986; Ramsey et al.; 6099170; August 8, 2000; Sarbell; 6338579; January 15, 2002; Winiarski; 6496625; December 17, 2002; Falkowich; 6499891; December 31, 2002; Stevenson; 6779931; August 24, 2004; Murata; 6931194; August 16, 2005; Dowd; 7403686; July 22, 2008; Zervas; 7410308; August 12, 2008; Qian; 7918612; April 5, 2011; Zhao; 8096712; January 17, 2012; Solomon; 8696221; April 15, 2014; Vastmans; 8737774; May 27, 2014; MacDougall; 9063286; June 23, 2015; Durrant; 11587698; February 21, 2023; Glasscock; 20070160332; July 12, 2007; Qian; 20070284117; December 13, 2007; Smithson; 20080056639; March 6, 2008; MacDougall et al.; 20160003669; January 7, 2016; Lee; 20190316425; October 17, 2019; Wisinger, Jr. et al.; 20200379176; December 3, 2020; Rossi

0926519; July 2005; EP

['A method for joining fiber optic cables includes sliding a sleeve over a first fiber optic cable, joining a first set of optical fibers of the first fiber optic cable to a second set of optical fibers of a second fiber optic cable, sliding the sleeve over the first and second fiber optic cables, and joining the sleeve to a first exterior casing of the first fiber optic cable and to a second exterior casing of the second fiber optic cable.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThe subject matter disclosed herein relates to systems and methods for joining two fiber optic cables, for example, for use with downhole tools.', 'Wellbore operations often employ fiber optic cables to connect surface-level equipment to downhole tooling.', 'The fiber optic cables include optical fibers surrounded by exterior casings to protect the optical fibers from downhole environmental factors.', 'In some circumstances, it may be desirable to join two lengths of fiber optic cable.', 'Unfortunately, joining exterior casings may interfere with joining optical fibers, and vice versa.', 'SUMMARY\n \nA summary of certain embodiments disclosed herein is set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.', 'In one embodiment, a method for joining fiber optic cables includes sliding a sleeve over a first fiber optic cable, joining a first set of optical fibers of the first fiber optic cable to a second set of optical fibers of a second fiber optic cable, sliding the sleeve over the first and second fiber optic cables, and joining the sleeve to a first exterior casing of the first fiber optic cable and to a second exterior casing of the second fiber optic cable.', 'In another embodiment, a method for joining a pair of fiber optic cables for use in a wellbore site operation includes sliding a sleeve over a first fiber optic cable, joining a first set of optical fibers of the first fiber optic cable to a second set of optical fibers of a second fiber optic cable, sliding the sleeve over the first and second fiber optic cables, and joining the sleeve to a first exterior casing of the first fiber optic cable and to a second exterior casing of the second fiber optic cable.', 'The method also includes utilizing the first fiber optic cable and the second fiber optic cable to communicate an optical signal to or from a downhole tool.', 'The method may further include retrieving the downhole tool from the wellbore, joining the fiber optic cables at a surface of the wellbore, disposing the downhole tool and joined fiber optic cables into the wellbore and performing a wellbore operation, including communicating an optical signal to or from a downhole tool while performing the wellbore operation.', 'In yet another embodiment, an assembly for a joined fiber optic cable includes a first fiber optic cable that includes a first plurality of optical fibers and a first exterior casing.', 'The assembly also includes a second fiber optic cable that includes a second plurality of optical fibers and a second exterior casing.', 'The first plurality of optical fibers is joined to the second plurality of optical fibers.', 'The assembly also includes a sleeve that partially overlaps the first exterior casing and the second exterior casing, and the sleeve is joined to the first exterior casing and the second exterior casing.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings in which:\n \nFIG.', '1\n is a schematic diagram of a wellbore site employing fiber optic-connected tools, in accordance with the present disclosure;\n \nFIG.', '2\n is a perspective view of a pair of separated fiber optic cables, in accordance with the present disclosure;\n \nFIG.', '3\n is a perspective view of two joined fiber optic cables, in accordance with the present disclosure;\n \nFIG.', '4\n is a flow diagram of a process for joining a pair of fiber optic cables, in accordance with the present disclosure;\n \nFIG.', '5\n is a flow diagram of another process for joining a pair of fiber optic cables, in accordance with the present disclosure; and\n \nFIG.', '6\n is a flow diagram of a process for testing a pair of joined fiber optic cables, in accordance with the present disclosure.', 'DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS\n \nOne or more specific embodiments will be described below.', 'In an effort to provide a concise description of these embodiments, not all features of an actual implementation are described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'As used herein, the terms “connect,” “connection,” “connected,” “in connection with,” and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element.”', 'Further, the terms “couple,” “coupling,” “coupled,” “coupled together,” and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements.”', 'As used herein, the terms “up” and “down,” “uphole” and “downhole”, “upper” and “lower,” “top” and “bottom,” and other like terms indicating relative positions to a given point or element are utilized to more clearly describe some elements.', 'Commonly, these terms relate to a reference point as the surface from which drilling operations are initiated as being the top (e.g., uphole or upper) point and the total depth along the drilling axis being the lowest (e.g., downhole or lower) point, whether the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.', 'In addition, as used herein, the terms “automatic” and “automated” are intended to describe operations that are caused to be performed, for example, by an automation control system (i.e., solely by the automation control system, without human intervention).', 'As generally discussed above, wellbore operations often employ fiber optic cables to quickly communicate between surface-level equipment (e.g., a controller) and downhole tooling.', 'In some cases, it may be desirable to join two pieces of fiber optic cable together.', 'For example, during a downhole or wellbore operation, many hazards such as high temperatures, pressure, tension caused by a downhole tool, and so forth, may damage the fiber optic cables, resulting in snapping or casing damage.', 'In another example, a portion of fiber optic cable may experience relatively high temperatures and pressures downhole.', 'An operator may employ a length of high-temperature (e.g., capable of operating in temperatures above 200° C., for example) fiber optic cable in high temperature downhole areas.', 'However, in an effort to decrease cost, the operator may desire to join the high-temperature fiber optic cable to a length of low-temperature (e.g., capable of operating in temperatures up to 120° C.) fiber optic cable that will not be exposed to high temperature downhole areas.', 'However, methods for joining inner components of fiber optic cable and methods for joining exterior components of fiber optic cable may conflict.', 'For example, joining optical fibers of two lengths of fiber optic cable may require removal of an exterior casing.', 'In another example, joining exterior casing of two lengths of fiber optic casing may employ a joining method (e.g., welding, brazing, soldering, and so forth) that may potentially damage the optical fibers.', 'Accordingly, a method for joining two lengths of fiber optic cable that does not risk damaging the optical fibers is desirable.', 'The present disclosure is directed to techniques for joining separate pieces of fiber optic cable.', 'Generally, a method may include sliding a sleeve over a first fiber optic cable.', 'The method may then include joining optical fibers of the first fiber optic cable to optical fibers of a second fiber optic cable.', 'An operator may then slide the sleeve over the joined optical fibers and join the sleeve to exterior casings of the first fiber optic cable and the second fiber optic cable.', 'Techniques may also include testing the joined fiber optic cables.', 'The testing may include attenuation loss testing, mechanical testing, and pressure testing, among other types of testing.', 'With this in mind, \nFIG.', '1\n is a schematic diagram of a wellbore site \n10\n employing fiber optic-connected tools.', 'The wellbore site \n10\n may include a plurality of devices (e.g., surface-level electronic equipment, downhole wellbore tools, etc.) to perform an operation (e.g., drilling operation, an intervention operation such as a coiled tubing operation or the like, an analysis operation, and so forth) in the wellbore \n12\n.', 'The wellbore \n12\n may include a wellbore shaft \n14\n and a wellbore mouth \n16\n at an upper end of the wellbore shaft \n14\n at a surface \n18\n.', 'At the wellbore mouth \n16\n, a spooling device \n20\n may lower a downhole tool \n22\n into the wellbore \n12\n via a fiber optic cable \n24\n.', 'The downhole tool \n22\n may include sensors, an open end of optical fiber, and so forth.', 'The downhole tool \n22\n may be coupled to the fiber optic cable \n24\n.', 'The fiber optic cable \n24\n may include a plurality of optical fibers configured to transmit optical data between a first end and a second end of the fiber optic cable \n24\n.', 'In certain embodiments, the plurality of optical fibers may be surrounded by an exterior casing configured to protect the plurality optical fibers (e.g., from structural damage, from extreme temperatures and/or pressures in a downhole environment, and so forth).', 'The fiber optic cable \n24\n may communicably couple the downhole tool \n22\n to equipment at the surface \n18\n of the wellbore site \n10\n.', 'The wellbore site \n10\n may include various pieces of equipment for controlling and communicating with the downhole tool \n22\n.', 'To this end, in certain embodiments, the wellbore site \n10\n may include an electromagnetic source \n30\n.', 'The electromagnetic source \n30\n may generate an electromagnetic signal (e.g., a light signal) and send the electromagnetic signal to the downhole tool \n22\n via the fiber optic cable \n24\n.', 'Likewise, the downhole tool \n22\n may send electromagnetic signals via the fiber optic cable \n24\n.', 'In certain embodiments, a beam splitter \n32\n may direct a portion of the electromagnetic signal (e.g., backscatter) toward an optical detector \n34\n.', 'The optical detector \n34\n may receive the electromagnetic signal and transmit data of the electromagnetic signal to a processor \n36\n.', 'The processor \n36\n may be any type of computer processor or microprocessor capable of executing computer-executable code.', 'The processor \n36\n may also include multiple processors that may perform a plurality of operations (e.g., sending and receiving data).', 'As mentioned above, it may be advantageous to employ a method for joining a pair of separate fiber optic cables.', 'Accordingly, \nFIG.', '2\n is a perspective view of a pair of separated fiber optic cables.', 'As illustrated, a first fiber optic cable \n50\n and a second fiber optic cable \n52\n may be separate fiber optic cables, or portions of a single fiber optic cable that has been severed.', 'For example, the first fiber optic cable \n50\n and the second fiber optic cable \n52\n may both be portions of a fiber optic cable that has been severed during an operation at a wellbore site \n10\n (e.g., the fiber optic cable \n24\n was snapped by the weight of the downhole tool \n22\n, etc.).', 'In another example, the first fiber optic cable \n50\n may be configured to withstand relatively high temperatures, and the second fiber optic cable \n52\n may not be configured to withstand relatively high temperatures.', 'In this example, an operator may wish to save money by minimizing an amount of high-cost, high-temperature fiber optic cable by coupling the high-temperature fiber optic cable to a length of low-cost, low-temperature fiber optic cable that is not lowered into a depth of the wellbore \n12\n that experiences relatively high temperatures.', 'As illustrated in \nFIG.', '2\n, the first fiber optic cable \n50\n may include a first plurality of optical fibers \n54\n (e.g., a first set of optical fibers \n54\n), a first tubular body \n56\n, and a first exterior casing \n58\n, and the second fiber optic cable \n52\n may include a second plurality of optical fibers \n60\n (e.g., a second set of optical fibers \n60\n), a second tubular body \n62\n, and a second exterior casing \n64\n.', 'In certain embodiments, the plurality of optical fibers \n54\n, \n60\n may be formed of glass (e.g., silica), plastic, or another suitable material.', 'The plurality of optical fibers \n54\n, \n60\n may have a narrow circular geometry, and may be configured to carry an optical signal from a first axial end of each optical fiber \n54\n, \n60\n to a second axial end of each optical fiber \n54\n, \n60\n.', 'In certain embodiments, the tubular bodies \n56\n, \n62\n may be formed of glass, plastic, or another suitable material, and may extend about the respective plurality of optical fibers \n54\n, \n60\n.', 'The tubular bodies \n56\n, \n62\n may have a suitable refractive index (e.g., a refractive index lower than a refractive index of the plurality of optical fibers \n54\n) to discourage attenuation.', 'In certain embodiments, the exterior casings \n58\n, \n64\n may extend about the plurality of optical fibers \n54\n, \n60\n and the tubular bodies \n56\n, \n62\n.', 'The exterior casings \n58\n, \n64\n may be formed of a polymer, metal (e.g., Inconel®), or another suitable material.', 'Additionally, the exterior casings \n58\n, \n64\n may be configured to bear an axial load (e.g., tension or compression) and maintain an internal pressure to prevent damage to the plurality of optical fibers \n54\n, \n60\n and the tubular bodies \n56\n, \n62\n during operation.', 'In certain embodiments, portions of the exterior casings \n58\n, \n64\n and the tubular bodies \n56\n, \n62\n may be stripped from an axial end of the first fiber optic cable \n50\n and an axial end of the second fiber optic cable \n52\n to expose portions of the plurality of optical fibers \n54\n, \n60\n for a joining process.', 'As illustrated in \nFIG.', '2\n, each axial end of an optical fiber \n54\n, \n60\n of the plurality of optical fibers \n54\n, \n60\n may be staggered lengthwise from other axial ends.', 'In the illustrated embodiment, the first fiber optic cable \n50\n and the second fiber optic cable \n52\n are prepared for a joining operation.', 'FIG.', '3\n is a cross-sectional view of two joined fiber optic cables.', 'In particular, \nFIG. \n3\n illustrates the first fiber optic cable \n50\n and the second fiber optic cable \n52\n, including the plurality of optical fibers \n54\n, \n60\n, the tubular bodies \n56\n, \n62\n, and the exterior casings \n58\n, \n64\n of \nFIG.', '2\n in a joined state.', 'Multiple components of the first fiber optic cable \n50\n and the second fiber optic cable \n52\n may be joined to achieve optical and structural continuity.', 'First, the plurality of optical fibers \n54\n, \n60\n may be joined to enable transmission of optical signals from the first fiber optic cable \n50\n to the second fiber optic cable \n52\n, and vice versa.', 'In particular, in certain embodiments, the first plurality of optical fibers \n54\n of the first fiber optic cable \n50\n may be joined to the second plurality of optical fibers \n60\n of the second fiber optic cable \n52\n via a fusion splicing process, via installation of a patch cord, via application of an adhesive (e.g., glue), or another suitable process.', 'In certain embodiments, a fusion splicing process may include heating respective axial ends of the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n until the respective axial ends are melted and fused to each other.', 'In such, embodiments, the fusion splicing process may be performed using an electric arc, a laser, or another suitable method for heating the optical fibers \n54\n, \n60\n.', 'In other embodiments, a patch cord installation process may include mechanically attaching a patch cord to respective axial ends of the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n.', 'In other embodiments, application of an adhesive may include applying an adhesive to respective axial ends of the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n.', 'In such embodiments, the adhesive may have a similar refractive index to the material of the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n.', 'In each of the above-mentioned joining techniques, a plurality of joints \n70\n are created between respective axial ends of the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n.', 'As illustrated, in certain embodiments, a longitudinal (e.g., axial) location of each joint \n70\n may be staggered along the length of the first plurality of optical fibers \n54\n of the first fiber optic cable \n50\n and the second plurality of optical fibers \n60\n of the second fiber optic cable \n52\n.', 'Second, the first exterior casing \n58\n of the first fiber optic cable \n50\n and the second exterior casing \n64\n of the second fiber optic cable \n52\n may be joined to increase structural integrity and enable maintenance of a pressure within the joined fiber optic cables \n50\n, \n52\n.', 'In particular, in certain embodiments, a sleeve \n72\n may couple to the first exterior casing \n58\n and the second exterior casing \n64\n and extend radially around all of the joints \n70\n.', 'The sleeve \n72\n may have a tubular geometry, and may have an inner diameter greater than an outer diameter of the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In certain embodiments, the sleeve \n72\n may be formed of a polymer, metal (e.g., Inconel®), or another suitable material.', 'In addition, in certain embodiments, the sleeve \n72\n may be formed of the same material as the first exterior casing \n58\n and/or the second exterior casing \n64\n.', 'In addition, in certain embodiments, an interior surface of the sleeve \n72\n may include materials similar to the first tubular body \n56\n and/or the second tubular body \n62\n.', 'In certain embodiments, the sleeve \n72\n may be coupled to the first exterior casing \n58\n and the second exterior casing \n64\n via a plurality of coupling features \n74\n.', 'In particular, in certain embodiments, the plurality of coupling features \n74\n may be adhesives (e.g., glues or other substances that chemically react with the sleeve \n72\n, the first exterior casing \n58\n, and/or the second exterior casing \n64\n), swaging or crimping locations, adhesives in addition to swaging or crimping location, metallurgical joining points, sealants, and so forth.', 'In certain embodiments, the plurality of coupling features \n74\n may be located anywhere that the inner surface of the sleeve \n72\n and an exterior surfaces of the first exterior casing \n58\n or the second exterior casing \n64\n overlap.', 'In certain embodiments, the plurality of coupling features \n74\n may include adhesives that set over time.', 'In other embodiments, the plurality of coupling features \n74\n may include crimping locations, and the crimping force required to crimp the material of the sleeve \n72\n may be below a threshold that would damage optical fibers \n54\n, \n60\n of the respective fiber optic cable \n50\n, \n52\n.', 'The coupling features \n74\n may be designed to protect the optical fibers \n54\n, \n60\n of the first fiber optic cable \n50\n and the second fiber optic cable \n52\n.', 'In addition, in certain embodiments, the sleeve \n72\n, the first exterior casing \n58\n, and the second exterior casing \n64\n may be sealed via a plurality of o-rings \n76\n (e.g., sealing elements).', 'Each o-ring \n76\n of the plurality of o-rings \n76\n may be formed of rubber, plastic, metal, or another suitable material.', 'In certain embodiments, the plurality of o-rings \n76\n may be located anywhere that the inner surface of the sleeve \n72\n and an exterior surfaces of the first exterior casing \n58\n or the second exterior casing \n64\n overlap.', 'The plurality of o-rings \n76\n enable the first fiber optic cable \n50\n, the sleeve \n72\n, and the second fiber optic cable \n52\n to maintain an internal pressure.', 'An inner diameter of the o-rings \n76\n may be smaller than the outer diameters of the first exterior casing \n58\n and the second exterior casing \n64\n.', 'Accordingly, the o-rings \n76\n may elastically deform to fit over the first exterior casing \n58\n and the second exterior casing \n64\n to enhance the seal.', 'The thickness of the o-rings \n76\n may be equal to or greater than a radial distance between the sleeve \n72\n and the first exterior casing \n58\n and the second exterior casing \n64\n in an installed configuration.', 'As discussed below, the processes for joining optical fibers \n54\n, \n60\n and exterior casings \n58\n, \n64\n may be employed to join two fiber optic cables \n50\n, \n52\n without risking damage to components of the optical fibers \n54\n, \n60\n.', 'FIG.', '4\n is a flow diagram of a method \n100\n for joining a pair of fiber optic cables \n50\n, \n52\n.', 'Although the following description of the method \n100\n is described in a particular order, it should be noted that the method \n100\n is not limited to the depicted order and, instead, the method \n100\n may be performed in any suitable order.', 'This method \n100\n (or algorithm) may be performed manually by an operator, automatically by industrial machinery, or the like, in accordance with present embodiments.', 'In particular, while described below as being performed manually by an operator, in other embodiments, the steps of the method \n100\n may each be performed automatically by industrial machinery.', 'At block \n102\n, the operator may slide the sleeve \n72\n over the first fiber optic cable \n50\n.', 'In other embodiments, the operator may slide the sleeve \n72\n over the second fiber optic cable \n52\n.', 'In certain embodiments, the operator may slide the sleeve \n72\n up a length of the first fiber optic cable \n50\n to enable the sleeve \n72\n to cover the joints \n70\n and couple to the exterior casings \n58\n, \n64\n after the plurality of optical fibers \n54\n, \n60\n are joined.', 'In certain embodiments, when slid onto the first fiber optic cable \n50\n, the interior surface of the sleeve \n72\n may be covered by a protective cover configured to protect the interior surface of the sleeve \n72\n.', 'At block \n104\n, the operator may join the first plurality of optical fibers \n54\n to the second plurality of optical fibers \n60\n.', 'As mentioned above, the operator may join the optical fibers \n54\n, \n60\n via fusion splicing, a patch cord, an adhesive, or the like.', 'These methods are expanded upon below.', 'Joining the first plurality of optical fibers \n54\n to the second plurality of optical fibers \n60\n may allow optical signals to be communicated from the first plurality of optical fibers \n54\n to the second plurality of optical fibers \n60\n, and vice versa, with minimal attenuation loss.', 'The joining process may create the joints \n70\n, which may have a greater diameter than the plurality of optical fibers \n54\n, \n60\n, in certain embodiments.', 'Accordingly, in certain embodiments, the operator may stagger longitudinal locations of the joints \n70\n of the first set of optical fibers \n54\n of the first fiber optic cable \n50\n with respect to the second set of optical fibers \n60\n of the second fiber optic cable \n52\n, so as to prevent a significant increase in fiber optic cable diameter near the joints \n70\n.', 'In other embodiments, two or more of the joints \n70\n may be longitudinally aligned.', 'At block \n106\n, the operator may slide the sleeve \n72\n over the joined optical fibers \n54\n, \n60\n.', 'The operator may position the sleeve \n72\n to equally overlap the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In certain embodiments in which the interior surface of the sleeve \n72\n is covered by a protective cover, the operator may remove the protective cover.', 'At block \n108\n, the operator may join the sleeve \n72\n to the first exterior casing \n58\n and the second exterior casing \n64\n.', 'As mentioned above, the operator may employ adhesives (e.g., chemical techniques), mechanical techniques, metallurgical techniques, or the like, to join the sleeve \n72\n to the first exterior casing \n58\n and the second exterior casing \n64\n.', 'These methods are expanded upon below.', 'The method \n100\n may join the first fiber optic cable \n50\n to the second fiber optic cable \n52\n.', 'The following figure describes a more detailed embodiment of the method \n100\n.\n \nFIG.', '5\n is a flow diagram of a method \n200\n for joining a pair of fiber optic cables \n50\n, \n52\n.', 'Although the following description of the method \n200\n is described in a particular order, it should be noted that the method \n200\n is not limited to the depicted order and, instead, the method \n200\n may be performed in any suitable order.', 'This method \n200\n (or algorithm) may be performed manually by an operator, automatically by industrial machinery, or the like, in accordance with present embodiments.', 'In particular, while described below as being performed manually by an operator, in other embodiments, the steps of the method \n200\n may each be performed automatically by industrial machinery.', 'At block \n202\n, the operator may slide the sleeve \n72\n over the first fiber optic cable \n50\n.', 'In other embodiments, the operator may slide the sleeve \n72\n over the second fiber optic cable \n52\n.', 'In certain embodiments, the operator may slide the sleeve \n72\n up a length of the first fiber optic cable \n50\n to enable the sleeve \n72\n to cover the joints \n70\n and couple to the exterior casings \n58\n, \n64\n after the plurality of optical fibers \n54\n, \n60\n are joined.', 'At block \n204\n, the operator may prepare the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n to be joined.', 'For example, the operator may clean the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n in preparation for a joining operation.', 'The operator may align each axial end of the first plurality of optical fibers \n54\n with respective axial ends of the second plurality of optical fibers \n60\n.', 'In certain embodiments, the operator may cut axial ends of the optical fibers \n54\n, \n60\n to be longitudinally staggered.', 'For example, the operator may stagger each optical fiber \n54\n of the first plurality of optical fibers \n54\n to correspond to an optical fiber \n60\n of the second plurality of optical fibers \n60\n so that each pair of corresponding optical fibers \n54\n, \n60\n may contact one another in a pre-joined configuration.', 'In certain embodiments, the operator may cut the optical fibers \n54\n, \n60\n using scissors, a blade, a heat implement, or the like.', 'In an embodiment including fusion splicing techniques, the operator may orient each axial end of the first plurality of optical fibers \n54\n to contact a respective axial end of the second plurality of optical fibers \n60\n.', 'In an embodiment including a patch cord, the operator may orient each axial end of the first plurality of optical fibers \n54\n to be spaced from a respective axial end of the second plurality of optical fibers \n60\n by a certain span.', 'In an embodiment including adhesives (e.g., chemical techniques), the operator may apply an adhesive to each axial end of the first plurality of optical fibers \n54\n and connect each axial end to a respective axial end of the second plurality of optical fibers \n60\n.', 'At block \n206\n, the operator may join the first plurality of optical fibers \n54\n to the second plurality of optical fibers \n60\n.', 'In an embodiment including fusion splicing techniques, the operator may utilize a heating device (e.g., an electric arc device, a laser, etc.) to melt and attach each axial end of the first plurality of optical fibers \n54\n to the respective axial ends of the second plurality of optical fibers \n60\n.', 'The fusion splicing technique results in the plurality of joints \n70\n connecting the first plurality of optical fibers \n54\n to the second plurality of optical fibers \n60\n.', 'In an embodiment including a patch cord, the operator may mechanically connect the first plurality of optical fibers \n54\n to a first axial end of the patch cord and connect the second plurality of optical fibers \n60\n to a second axial end of the patch cord.', 'In certain embodiments, the patch cord may include a plurality of optical fibers having the same refractive index as the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n.', 'In certain embodiments, the patch cord may also include a first connector at the first axial end and a second connector at the second axial end.', 'In such embodiments, the first connector and second connector may be configured to mechanically connect the plurality of optical fibers of the patch cord to the first plurality of optical fibers \n54\n and the second plurality of optical fibers \n60\n, respectively.', 'In an embodiment including adhesives, the operator may set the adhesives.', 'The adhesives may be set using heat (e.g., via a heat gun), a catalyst compound (e.g., chemically), or by allowing the adhesive to set over a period of time.', 'At block \n208\n, the operator may prepare the sleeve \n72\n, the first exterior casing \n58\n, and the second exterior casing \n64\n for joining.', 'For example, the operator may clean the interior surface of the sleeve \n72\n, as well as the exterior surfaces of the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In embodiments including adhesives (e.g., chemically joining), the operator may apply adhesives to the interior surface of the sleeve \n72\n and/or to the exterior surfaces of the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In embodiments including metallurgical techniques (e.g., metallurgical joining), the operator may remove oxidation or imperfections from the interior surface of the sleeve \n72\n, as well as the exterior surfaces of the first exterior casing \n58\n and the second exterior casing \n64\n, before metallurgically joining the sleeve \n72\n, the first exterior casing \n58\n, and the second exterior casing \n64\n.', 'At block \n210\n, the operator may place o-rings \n76\n on the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In certain embodiments, the operator may elastically deform the o-rings \n76\n to fit on the first exterior casing \n58\n and the second exterior casing \n64\n.', 'The o-rings \n76\n may be placed at any longitudinal locations on the first exterior casing \n58\n and the second exterior casing \n64\n that longitudinally overlap with the sleeve \n72\n in an installed configuration.', 'Additionally, the operator may place any number (e.g., 1, 2, 3, 4, etc.) of o-rings \n76\n on the first exterior casing \n58\n and the second exterior casing \n64\n.', 'At block \n212\n, the operator may slide the sleeve \n72\n over the joined optical fibers \n54\n, \n60\n.', 'In certain embodiments, the operator may position the sleeve \n72\n to equally overlap the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In embodiments including adhesives, the operator may position the sleeve \n72\n to overlap portions of the interior surface of the sleeve \n72\n covered in the adhesive with portions of the first exterior casing \n58\n and the second exterior casing \n64\n covered in adhesive.', 'At block \n214\n, the operator may join the sleeve \n72\n to the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In embodiments including chemical joining (e.g., adhesives), the operator may cause the adhesives applied to the sleeve \n72\n, the first exterior casing \n58\n, and the second exterior casing \n64\n to set.', 'In certain embodiments, the operator may set the adhesives using heat (e.g., via a heat gun), a catalyst compound (e.g., chemically), or by allowing the adhesive to set over a period of time.', 'In certain embodiments, the adhesive applied to the sleeve \n72\n is a first part of an epoxy, and the adhesive applied to the first exterior casing \n58\n and the second exterior casing \n64\n is a second part of the epoxy.', 'In such embodiments, once the first part of the epoxy contacts the second part of the epoxy, the epoxy sets, joining the sleeve \n72\n to the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In embodiments including mechanical joining, the operator may use a swaging or crimping device to swage or crimp areas of the sleeve \n72\n to the first exterior casing \n58\n and the second exterior casing \n64\n.', 'In embodiments including metallurgical joining, the operator may join the sleeve \n72\n to the first exterior casing \n58\n and the second exterior casing \n64\n via a welding process, a brazing process, a soldering process, a friction seizure, or the like.', 'In certain embodiments, the operator chooses a particular joining technique(s) to ensure that the optical fibers \n54\n, \n60\n of the first fiber optic cable \n50\n and the second fiber optic cable \n52\n are not damaged during the joining process.', 'Once the method \n200\n is complete, the operator may choose to perform one or more testing operations, as detailed below.\n \nFIG.', '6\n is a flow diagram of a method \n300\n for testing a pair of joined fiber optic cables.', 'Although the following description of the method \n300\n is described in a particular order, it should be noted that the method \n300\n is not limited to the depicted order; and, instead, the method \n300\n may be performed in any suitable order.', 'This method \n300\n (or algorithm) may be performed manually by an operator, automatically by industrial machinery, or the like, in accordance with present embodiments.', 'In particular, while described below as being performed manually by an operator, in other embodiments, the steps of the method \n300\n may each be performed automatically by industrial machinery.', 'At block \n302\n, the operator may receive the joined pair of the first fiber optic cable \n50\n and the second fiber optic cable \n52\n.', 'The pair of fiber optic cables \n50\n, \n52\n may be joined via any of the methods described above with reference to \nFIGS.', '4\n and \n5\n, or via another suitable method.', 'At block \n304\n, the operator may test the joined fiber optic cables \n50\n, \n52\n for attenuation loss.', 'In certain embodiments, the operator may utilize a testing apparatus (e.g., the electromagnetic source \n30\n and the optical detector \n34\n, an optical testing apparatus, etc.) to determine an amount of attenuation loss experienced by an optical signal transmitted through the joined fiber optic cables \n50\n, \n52\n.', 'In one embodiment, the operator may connect a first axial end of the joined fiber optic cables \n50\n, \n52\n to the electromagnetic source \n30\n, and may connect a second axial end of the joined fiber optic cables \n50\n, \n52\n to the optical detector \n34\n.', 'Then, the electromagnetic source \n30\n may send an optical signal to the optical detector \n34\n via the joined fiber optic cables \n50\n, \n52\n.', 'Then, a processor \n36\n coupled to the electromagnetic source \n30\n and the optical detector \n34\n may then determine an amount of attenuation loss.', 'At block \n306\n, the operator may determine whether the amount of attenuation loss experienced by the joined fiber optic cables \n50\n, \n52\n is greater than a threshold amount of attenuation loss.', 'If the amount of attenuation loss experienced by the joined fiber optic cables \n50\n, \n52\n is greater than a threshold amount of attenuation loss, the method \n300\n continues to block \n318\n.', 'If the amount of attenuation loss experienced by the joined fiber optic cables \n50\n, \n52\n is less than a threshold amount of attenuation loss, the method \n300\n continues to block \n308\n.', 'At block \n308\n, the operator may test the joined fiber optic cables \n50\n, \n52\n to determine whether the joined fiber optic cables \n50\n, \n52\n can maintain an internal pressure.', 'In certain embodiments, the operator utilize a testing apparatus (e.g., a pressure testing apparatus) to determine whether the joined fiber optic cables \n50\n, \n52\n can maintain a threshold internal pressure.', 'For example, the operator may connect each axial end of the joined fiber optic cables \n50\n, \n52\n to an apparatus that may pump compressed air or nitrogen into the joined fiber optic cables \n50\n, \n52\n and measure the internal pressure over a period of time.', 'A decrease in pressure over the period of time may indicate a defective seal.', 'At block \n310\n, the operator may determine whether the joined fiber optic cables \n50\n, \n52\n can maintain an internal pressure.', 'If the joined fiber optic cables \n50\n, \n52\n cannot maintain an internal pressure, the method \n300\n continues to block \n318\n.', 'If the joined fiber optic cables \n50\n, \n52\n can maintain an internal pressure, the method \n300\n continues to block \n312\n.', 'At block \n312\n, the operator may test the joined fiber optic cables \n50\n, \n52\n to determine whether the joined fiber optic cables \n50\n, \n52\n can withstand a threshold axial load.', 'In certain embodiments, the operator may utilize a testing apparatus (e.g., a tensile testing apparatus) to determine whether the joined fiber optic cables \n50\n, \n52\n can withstand a threshold compressive load or a threshold tensile load.', 'For example, the operator may connect each axial end of the joined fiber optic cables \n50\n, \n52\n to a tensile testing apparatus and impose tensile and compressive loads on the joined fiber optic cables \n50\n, \n52\n.', 'At block \n314\n, the operator may determine whether the joined fiber optic cables \n50\n, \n52\n can withstand the threshold compressive and tensile loads.', 'If the joined fiber optic cables \n50\n, \n52\n cannot withstand the threshold compressive and tensile loads, the method \n300\n continues to block \n318\n.', 'If the joined fiber optic cables \n50\n, \n52\n can withstand the threshold compressive and tensile loads, the method \n300\n continues to block \n316\n.', 'At block \n316\n, the operator confirms that the joined fiber optic cables \n50\n, \n52\n are of sufficient quality, at which point the operator may approve the joined fiber optic cables \n50\n, \n52\n for use at a wellbore site \n10\n, and may indicate in an inventory that the joined fiber optic cables \n50\n, \n52\n passed attenuation loss tests, pressure tests, and axial strength tests.', 'At block \n318\n, the operator may repeat the joining process.', 'In particular, the operator may determine, based on a failed attenuation loss test, a failed pressure test, a failed axial strength test, or a combination thereof that the joined fiber optic cables \n50\n, \n52\n are not of sufficient quality.', 'In response, the operator may remove the joined portion of the fiber optic cables \n50\n, \n52\n and repeat the joining process.', 'It should be understood that the above methods of joining optical fibers \n54\n, \n60\n and the methods of joining exterior casings \n58\n, \n64\n can be used in any combination.', 'For example, in certain embodiments, the operator may join the optical fibers \n54\n, \n60\n via fusion splicing, and the operator may join the exterior casings \n58\n, \n64\n chemically (e.g., via an adhesive).', 'In another example, the operator may join the optical fibers \n54\n, \n60\n via fusion splicing, and the operator may join the exterior casings \n58\n, \n64\n mechanically.', 'In another example, the operator may join the optical fibers \n54\n, \n60\n via fusion splicing, and the operator may join the exterior casings \n58\n, \n64\n metallurgically.', 'In yet another example, the operator may join the optical fibers \n54\n, \n60\n via a patch cord, and the operator may join the exterior casings \n58\n, \n64\n chemically (e.g., via an adhesive).', 'In another example, the operator may join the optical fibers \n54\n, \n60\n via a patch cord, and the operator may join the exterior casings \n58\n, \n64\n mechanically.', 'In another example, the operator may join the optical fibers \n54\n, \n60\n via a patch cord, and the operator may join the exterior casings \n58\n, \n64\n metallurgically.', 'In yet another example, the operator may join the optical fibers \n54\n, \n60\n chemically (e.g., via an adhesive), and the operator may join the exterior casings \n58\n, \n64\n chemically (e.g., via an adhesive).', 'In another example, the operator may join the optical fibers \n54\n, \n60\n chemically (e.g., via an adhesive), and the operator may join the exterior casings mechanically.', 'In another example, the operator may join the optical fibers \n54\n, \n60\n chemically (e.g., via an adhesive), and the operator may join the exterior casings \n58\n, \n64\n metallurgically.', 'In these examples, it should be noted that the plurality of optical fibers \n54\n, \n60\n may be staggered or aligned longitudinally.', 'Additionally, the exterior casings \n58\n, \n64\n may be joined to the sleeve \n72\n metal-to-metal, or o-rings (e.g., sealing elements) may be disposed between the sleeve \n72\n and the exterior casings \n58\n, \n64\n.', 'Furthermore, the optical fibers \n54\n, \n60\n of the first fiber optic cable \n50\n may be the same type of optical fibers \n54\n, \n60\n that are used in the second fiber optic cable \n52\n, or the optical fibers \n54\n, \n60\n may be different types of optical fibers \n54\n, \n60\n.', 'For example, the first set of optical fibers \n54\n may be high-temperature optical fibers (e.g., capable of operating in temperatures above 200° C., for example), and the second set of optical fibers \n60\n may be low-temperature optical fibers (e.g., capable of operating in temperatures up to 120° C.).', 'The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical.', 'Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ”', 'or “step for [perform]ing [a function] . . .', '”, it is intended that such elements are to be interpreted under 35 U.S.C. § 112(f).', 'However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. § 112(f).']

['1.', 'A method for joining fiber optic cables, comprising:\nsliding a sleeve over a first fiber optic cable, wherein the sleeve has an inner diameter greater than an outer diameter of a first exterior casing of the first fiber optic cable that extends about a first set of optical fibers over a length of a first tubular body of the first fiber optic cable, wherein the first set of optical fibers is disposed within the first tubular body;\njoining the first set of optical fibers of the first fiber optic cable to a second set of optical fibers disposed within a second tubular body of a second fiber optic cable;\nsliding the sleeve over the first and second fiber optic cables, wherein the sleeve has an inner diameter greater than an outer diameter of a second exterior casing of the second fiber optic cable that extends about the second set of optical fibers over a length of the second tubular body; and\njoining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable, wherein the sleeve comprises a same material as the first exterior casing and the second exterior casing, and wherein joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable comprises metallurgically joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable by: utilizing welds between at least one of: the sleeve, the first exterior casing, or the second exterior casing; utilizing friction seizures between at least one of: the sleeve, the first exterior casing, or the second exterior casing; or a combination thereof.', '2.', 'The method of claim 1, wherein joining the first set of optical fibers of the first fiber optic cable to the second set of optical fibers of the second fiber optic cable comprises fusion splicing the first set of optical fibers of the first fiber optic cable to the second set of optical fibers of the second fiber optic cable.', '3.', 'The method of claim 1, wherein joining the first set of optical fibers of the first fiber optic cable to the second set of optical fibers of the second fiber optic cable comprises using a patch cord to join the first set of optical fibers of the first fiber optic cable to the second set of optical fibers of the second fiber optic cable.', '4.', 'The method of claim 1, further comprising staggering longitudinal locations of joints of the first set of optical fibers of the first fiber optic cable to the second set of optical fibers of the second fiber optic cable.', '5.', 'The method of claim 1, wherein joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable further comprises mechanically joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable.', '6.', 'The method of claim 5, wherein mechanically joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable comprises:\nutilizing threads or threaded devices on at least one of: the sleeve, the first exterior casing, or the second exterior casing;\nutilizing swaging or crimping on at least one of: the sleeve, the first exterior casing, or the second exterior casing; or\na combination thereof.', '7.', 'The method of claim 1, wherein joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable further comprises chemically joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable.', '8.', 'The method of claim 7, wherein chemically joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable comprises:\nutilizing glues, utilizing adhesives, utilizing substances that chemically react with at least one of: the sleeve, the first exterior casing, or the second exterior casing; or a combination thereof.', '9.', 'The method of claim 1, further comprising installing a first set of sealing elements between the sleeve and the first exterior casing and installing a second set of sealing elements between the sleeve and the second exterior casing.', '10.', 'The method of claim 1, wherein the first set of optical fibers of the first fiber optic cable and the second set of optical fibers of the second fiber optic cable are different types of optical fibers.', '11.', 'The method of claim 1, further comprising:\nattaching the first fiber optic cable and the second fiber optic cable to an optical testing apparatus; and\ndetermining, via the optical testing apparatus, that an attenuation loss of the first fiber optic cable and the second fiber optic cable is less than a threshold attenuation loss value.\n\n\n\n\n\n\n12.', 'The method of claim 1, further comprising:\nattaching the first fiber optic cable and the second fiber optic cable to a pressure testing apparatus; and\ndetermining, via the pressure testing apparatus, that the first fiber optic cable and the second fiber optic cable can maintain a threshold pressure.', '13.', 'The method of claim 1, further comprising:\nattaching the first fiber optic cable and the second fiber optic cable to a tensile testing apparatus; and\ndetermining, via the tensile testing apparatus, that a tensile strength of the first fiber optic cable and the second fiber optic cable is greater than a threshold tensile strength value.\n\n\n\n\n\n\n14.', 'The method of claim 9, wherein the first set of sealing elements comprises a first set of o-rings and the second set of sealing elements comprises a second set of o-rings.', '15.', 'A method for joining a pair of fiber optic cables for use in a wellbore site operation, comprising:\nsliding a sleeve over a first fiber optic cable, wherein the sleeve has an inner diameter greater than an outer diameter of a first exterior casing of the first fiber optic cable that extends about a first set of optical fibers over a length of a first tubular body of the first fiber optic cable, wherein the first set of optical fibers is disposed within the first tubular body;\njoining the first set of optical fibers of the first fiber optic cable to a second set of optical fibers disposed within a second tubular body of a second fiber optic cable;\nsliding the sleeve over the first and second fiber optic cables, wherein the sleeve has an inner diameter greater than an outer diameter of a second exterior casing of the second fiber optic cable that extends about the second set of optical fibers over a length of the second tubular body; and\njoining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable, wherein the sleeve comprises a same material as the first exterior casing and the second exterior casing, and wherein joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable comprises metallurgically joining the sleeve to the first exterior casing of the first fiber optic cable and to the second exterior casing of the second fiber optic cable by: utilizing welds between at least one of: the sleeve, the first exterior casing, or the second exterior casing; utilizing friction seizures between at least one of: the sleeve, the first exterior casing, or the second exterior casing; or a combination thereof; and\nutilizing the first fiber optic cable and the second fiber optic cable to communicate an optical signal to or from a downhole tool.', '16.', 'The method of claim 15, wherein joining the first set of optical fibers of the first fiber optic cable to the second set of optical fibers of the second fiber optic cable comprises fusion splicing the first set of optical fibers of the first fiber optic cable to the second set of optical fibers of the second fiber optic cable.', '17.', 'The method of claim 15, further comprising:\nattaching the first fiber optic cable and the second fiber optic cable to an optical testing apparatus; and\ndetermining, via the optical testing apparatus, that an attenuation loss of the first fiber optic cable and the second fiber optic cable is less than a threshold attenuation loss value.']

['FIG.', '1 is a schematic diagram of a wellbore site employing fiber optic-connected tools, in accordance with the present disclosure;; FIG.', '2 is a perspective view of a pair of separated fiber optic cables, in accordance with the present disclosure;; FIG.', '3 is a perspective view of two joined fiber optic cables, in accordance with the present disclosure;; FIG.', '4 is a flow diagram of a process for joining a pair of fiber optic cables, in accordance with the present disclosure;; FIG.', '5 is a flow diagram of another process for joining a pair of fiber optic cables, in accordance with the present disclosure; and; FIG.', '6 is a flow diagram of a process for testing a pair of joined fiber optic cables, in accordance with the present disclosure.; FIG.', '3 is a cross-sectional view of two joined fiber optic cables.', 'In particular, FIG.', '3 illustrates the first fiber optic cable 50 and the second fiber optic cable 52, including the plurality of optical fibers 54, 60, the tubular bodies 56, 62, and the exterior casings 58, 64 of FIG.', '2 in a joined state.', 'Multiple components of the first fiber optic cable 50 and the second fiber optic cable 52 may be joined to achieve optical and structural continuity.; FIG. 4 is a flow diagram of a method 100 for joining a pair of fiber optic cables 50, 52.', 'Although the following description of the method 100 is described in a particular order, it should be noted that the method 100 is not limited to the depicted order and, instead, the method 100 may be performed in any suitable order.', 'This method 100 (or algorithm) may be performed manually by an operator, automatically by industrial machinery, or the like, in accordance with present embodiments.', 'In particular, while described below as being performed manually by an operator, in other embodiments, the steps of the method 100 may each be performed automatically by industrial machinery.; FIG.', '5 is a flow diagram of a method 200 for joining a pair of fiber optic cables 50, 52.', 'Although the following description of the method 200 is described in a particular order, it should be noted that the method 200 is not limited to the depicted order and, instead, the method 200 may be performed in any suitable order.', 'This method 200 (or algorithm) may be performed manually by an operator, automatically by industrial machinery, or the like, in accordance with present embodiments.', 'In particular, while described below as being performed manually by an operator, in other embodiments, the steps of the method 200 may each be performed automatically by industrial machinery.; FIG.', '6 is a flow diagram of a method 300 for testing a pair of joined fiber optic cables.', 'Although the following description of the method 300 is described in a particular order, it should be noted that the method 300 is not limited to the depicted order; and, instead, the method 300 may be performed in any suitable order.', 'This method 300 (or algorithm) may be performed manually by an operator, automatically by industrial machinery, or the like, in accordance with present embodiments.', 'In particular, while described below as being performed manually by an operator, in other embodiments, the steps of the method 300 may each be performed automatically by industrial machinery.']

US11697986

Power management at a wellsite

Sep 4, 2020

Shunfeng Zheng

Schlumberger Technology Corporation

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['Apparatus and methods for managing power at a wellsite.', 'An example apparatus may include a well construction equipment operable to construct a well at the wellsite, a power supply system operable to output electrical power to the well construction equipment to facilitate operation of the well construction equipment, and a control system for controlling the well construction system.', 'The control system may be operable to store a digital drilling program and cause the well construction equipment to perform planned well construction operations based on the digital drilling program.', 'The digital drilling program may include an equipment operational plan indicative of the planned well construction operations to be performed by the well construction equipment to construct the well, and an electrical power plan indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations.']

['Description\n\n\n\n\n\n\nBACKGROUND OF THE DISCLOSURE\n \nWells are generally drilled into the ground or ocean bed to recover natural deposits of oil, gas, and other materials that are trapped in subterranean rock formations.', 'Well construction (e.g., drilling) operations may be performed at a wellsite by a well construction system (i.e., a drilling rig) having various surface and subterranean well construction equipment operating in a coordinated manner.', 'For example, a drive mechanism, such as a top drive located at a wellsite surface, can be utilized to rotate and advance a drill string into a subterranean rock formation to drill a wellbore.', 'The drill string may include a plurality of drill pipes coupled together and terminating with a drill bit.', 'Length of the drill string may be increased by adding additional drill pipes while depth of the wellbore increases.', 'Drilling fluid may be pumped from the wellsite surface down through the drill string to the drill bit.', 'The drilling fluid lubricates and cools the drill bit, and carries drill cuttings from the wellbore back to the wellsite surface.', 'The drilling fluid returning to the surface may then be cleaned and again pumped through the drill string.', 'The well construction equipment of the well construction system may be grouped into various subsystems, wherein each subsystem performs a different operation.', 'Combustion engine electric generator units are typically utilized to output electrical power to operate the well construction equipment.', 'Fuel efficiency of such generator units increases when load on the engine increases.', 'Efficiency of the generator units (e.g., diesel fuel generating units) may be optimal at engine loads ranging between, for example, about 50% and about 100%.', 'Efficiency of the generator units is also relatively low during engine warm up periods, which may take several minutes.', 'During well construction operations, electrical power demand changes frequently and substantially during different stages of the well construction operations.', 'During such well construction operations, the generator units collectively output electrical power to match electrical power demand of the well construction equipment, regardless of efficiency.', 'Thus, during stages of well construction operations requiring relatively low levels of electrical power, the generator units operate at low efficiencies and discharge gas and particulate emissions at higher rates.', 'During stages of well construction operations requiring relatively high levels of electrical power, one or more additional generator units may be turned on to provide additional electrical power.', 'However, the additional generator units are typically brought online very quickly, without permitting the additional generator units to properly warm up, resulting in the generator units operating at low efficiencies and discharging gas and particulate emissions at higher rates.', 'SUMMARY OF THE DISCLOSURE', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure introduces an apparatus including a well construction system having well construction equipment operable to construct a well at a wellsite, a power supply system operable to output electrical power to the well construction equipment to facilitate operation of the well construction equipment, and a control system for controlling the well construction system.', 'The control system includes a processor and a memory storing a computer program code.', 'The control system is operable to store a digital drilling program that includes an equipment operational plan and an electrical power plan.', 'The equipment operational plan is indicative of planned well construction operations to be performed by the well construction equipment to construct the well.', 'The electrical power plan is indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The control system is also operable to cause the well construction equipment to perform the planned well construction operations indicated in the equipment operational plan.', 'The present disclosure also introduces an apparatus including a well construction system that includes well construction equipment operable to construct a well at a wellsite, a power supply system operable to output electrical power to the well construction equipment to facilitate operation of the well construction equipment, and a control system for controlling the well construction system.', 'The control system includes a processor and a memory storing a computer program code.', 'The control system is operable to store a digital drilling program that includes an equipment operational plan and an electrical power plan.', 'The equipment operational plan is indicative of planned well construction operations to be performed by the well construction equipment to construct the well.', 'The electrical power plan is indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The control system is also operable to cause the well construction equipment to perform the planned well construction operations indicated in the equipment operational plan.', 'The control system is also operable to cause the power supply system to output the electrical power to the well construction equipment based on the electrical power plan.', 'The electrical power output by the power supply system meets the planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The control system is also operable to: determine an electrical power output capacity indicative of electrical power that the power supply system can output to the well construction equipment to perform the planned well construction operations; compare the electrical power output capacity to the planned electrical power demand; and, based on the comparison, adjust the planned well construction operations to adjust the planned electrical power demand.', 'The present disclosure also introduces a method that includes commencing operation of a control system of a well construction system.', 'The well construction system is located at a wellsite and includes well construction equipment and a power supply system.', 'The operating control system stores a digital drilling program that includes an equipment operational plan and an electrical power plan.', 'The equipment operational plan is indicative of planned well construction operations to be performed by the well construction equipment to construct a well at the wellsite.', 'The electrical power plan is indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The operating control system also causes the well construction equipment to perform the planned well construction operations indicated in the equipment operational plan.', 'The operating control system also causes the power supply system to output the electrical power to the well construction equipment based on the electrical power plan.', 'The electrical power output by the power supply system meets the planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the material herein and/or practicing the principles described herein.', 'At least some aspects of the present disclosure may be achieved via means recited in the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is best understood from the following detailed description when read with the accompanying figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '2\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '3\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '4\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', 'FIGS.', '5\n and \n6\n are example implementations of screens displayed by the apparatus shown in one or more of \nFIGS.', '1\n and \n2\n according to one or more aspects of the present disclosure.', 'DETAILED DESCRIPTION', 'It is to be understood that the following disclosure describes many example implementations for different aspects introduced herein.', 'Specific examples of components and arrangements are described below to simplify the present disclosure.', 'These are merely examples, and are not intended to be limiting.', 'In addition, the present disclosure may repeat reference numerals and/or letters in the various examples.', 'This repetition is for simplicity and clarity, and does not in itself dictate a relationship between the various implementations described herein.', 'Moreover, the formation of a first feature over or on a second feature in the description that follows may include implementations in which the first and second features are formed in direct contact, and may also include implementations in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.\n \nSystems and methods (e.g., steps, processes, operations, etc.)', 'according to one or more aspects of the present disclosure may be utilized or otherwise implemented in association with an automated well construction system (i.e., a well construction rig) at an oil and gas wellsite, such as for constructing a wellbore for extracting hydrocarbons (e.g., oil and/or gas) from a subterranean formation.', 'However, one or more aspects of the present disclosure may be utilized or otherwise implemented in association with other automated systems in the oil and gas industry and other industries.', 'For example, one or more aspects of the present disclosure may be implemented in association with wellsite systems for performing fracturing, cementing, acidizing, chemical injecting, and/or water jet cutting operations, among other examples.', 'One or more aspects of the present disclosure may also be implemented in association with mining sites, building construction sites, and/or other work sites where automated machines or equipment are utilized.', 'FIG.', '1\n is a schematic view of at least a portion of an example implementation of a well construction system \n100\n according to one or more aspects of the present disclosure.', 'The well construction system \n100\n represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'The well construction system \n100\n may be or comprise a well construction rig (e.g., a well drilling rig).', 'Although the well construction system \n100\n is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', 'The well construction system \n100\n is depicted in relation to a wellbore \n102\n formed by rotary and/or directional drilling from a wellsite surface \n104\n and extending into a subterranean formation \n106\n.', 'The well construction system \n100\n comprises various well construction equipment (i.e., wellsite equipment), including surface equipment \n110\n located at the wellsite surface \n104\n and a drill string \n120\n suspended within the wellbore \n102\n.', 'The surface equipment \n110\n may include a mast, a derrick, and/or another support structure \n112\n disposed over a rig floor \n114\n.', 'The drill string \n120\n may be suspended within the wellbore \n102\n from the support structure \n112\n.', 'The support structure \n112\n and the rig floor \n114\n are collectively supported over the wellbore \n102\n by legs and/or other support structures (not shown).', 'The drill string \n120\n may comprise a bottom-hole assembly (BHA) \n124\n and means \n122\n for conveying the BHA \n124\n within the wellbore \n102\n.', 'The conveyance means \n122\n may comprise a plurality of interconnected tubulars, such as drill pipe, heavy-weight drill pipe (HWDP), wired drill pipe (WDP), tough logging condition (TLC) pipe, and drill collars, among other examples.', 'The conveyance means \n122\n may instead comprise coiled tubing for conveying the BHA \n124\n within the wellbore \n102\n.', 'A downhole end of the BHA \n124\n may include or be coupled to a drill bit \n126\n.', 'Rotation of the drill bit \n126\n and the weight of the drill string \n120\n collectively operate to form the wellbore \n102\n.', 'The drill bit \n126\n may be rotated from the wellsite surface \n104\n and/or via a downhole mud motor \n184\n connected with the drill bit \n126\n.', 'The BHA \n124\n may also include various downhole devices and/or tools \n180\n, \n182\n.', 'The support structure \n112\n may support a driver, such as a top drive \n116\n, operable to connect (perhaps indirectly) with an upper end of the drill string \n120\n, and to impart rotary motion \n117\n and vertical motion \n135\n to the drill string \n120\n, including the drill bit \n126\n.', 'However, another driver, such as a kelly and rotary table (neither shown), may be utilized instead of or in addition to the top drive \n116\n to impart the rotary motion \n117\n to the drill string \n120\n.', 'The top drive \n116\n and the connected drill string \n120\n may be suspended from the support structure \n112\n via a hoisting system or equipment, which may include a traveling block \n113\n, a crown block \n115\n, and a drawworks \n118\n storing a support cable or line \n123\n.', 'The crown block \n115\n may be connected to or otherwise supported by the support structure \n112\n, and the traveling block \n113\n may be coupled with the top drive \n116\n.', 'The drawworks \n118\n may be mounted on or otherwise supported by the rig floor \n114\n.', 'The crown block \n115\n and traveling block \n113\n comprise pulleys or sheaves around which the support line \n123\n is reeved to operatively connect the crown block \n115\n, the traveling block \n113\n, and the drawworks \n118\n (and perhaps an anchor).', 'The drawworks \n118\n may thus selectively impart tension to the support line \n123\n to lift and lower the top drive \n116\n, resulting in the vertical motion \n135\n.', 'The drawworks \n118\n may comprise a drum, a base, and a prime mover (e.g., an electric motor) (not shown) operable to drive the drum to rotate and reel in the support line \n123\n, causing the traveling block \n113\n and the top drive \n116\n to move upward.', 'The drawworks \n118\n may be operable to reel out the support line \n123\n via a controlled rotation of the drum, causing the traveling block \n113\n and the top drive \n116\n to move downward.', 'The top drive \n116\n may comprise a grabber, a swivel (neither shown), elevator links \n127\n terminating with an elevator \n129\n, and a drive shaft \n125\n operatively connected with a prime mover (e.g., an electric motor) (not shown).', 'The drive shaft \n125\n may be selectively coupled with the upper end of the drill string \n120\n and the prime mover may be selectively operated to rotate the drive shaft \n125\n and the drill string \n120\n coupled with the drive shaft \n125\n.', 'Hence, during drilling operations, the top drive \n116\n, in conjunction with operation of the drawworks \n118\n, may advance the drill string \n120\n into the formation \n106\n to form the wellbore \n102\n.', 'The elevator links \n127\n and the elevator \n129\n of the top drive \n116\n may handle tubulars (e.g., drill pipes, drill collars, casing joints, etc.) that are not mechanically coupled to the drive shaft \n125\n.', 'For example, when the drill string \n120\n is being tripped into or out of the wellbore \n102\n, the elevator \n129\n may grasp the tubulars of the drill string \n120\n such that the tubulars may be raised and/or lowered via the hoisting equipment mechanically coupled to the top drive \n116\n.', 'The grabber may include a clamp that clamps onto a tubular when making up and/or breaking out a connection of a tubular with the drive shaft \n125\n.', 'The top drive \n116\n may have a guide system (not shown), such as rollers that track up and down a guide rail on the support structure \n112\n.', 'The guide system may aid in keeping the top drive \n116\n aligned with the wellbore \n102\n, and in preventing the top drive \n116\n from rotating during drilling by transferring reactive torque to the support structure \n112\n.', 'The drill string \n120\n may be conveyed within the wellbore \n102\n through various fluid control devices disposed at the wellsite surface \n104\n on top of the wellbore \n102\n and perhaps below the rig floor \n114\n.', 'The fluid control devices may be operable to control fluid within the wellbore \n102\n.', 'The fluid control devices may include a blowout preventer (BOP) stack \n130\n for maintaining well pressure control comprising a series of pressure barriers (e.g., rams) between the wellbore \n102\n and an annular preventer \n132\n.', 'The fluid control devices may also include a rotating control device (RCD) \n138\n mounted above the annular preventer \n132\n.', 'The fluid control devices \n130\n, \n132\n, \n138\n may be mounted on top of a wellhead \n134\n.', 'A power unit \n137\n (i.e., a BOP control or closing unit) may be operatively connected with one or more of the fluid control devices \n130\n, \n132\n, \n138\n and operable to actuate, drive, operate, or otherwise control one or more of the fluid control devices \n130\n, \n132\n, \n138\n.', 'The power unit \n137\n may be or comprise a hydraulic fluid power unit fluidly connected with the fluid control devices \n130\n, \n132\n, \n138\n and selectively operable to hydraulically drive various portions (e.g., rams, valves, seals, etc.) of the fluid control devices \n130\n, \n132\n, \n138\n.', 'The power unit \n137\n may comprise one or more hydraulic pumps actuated by electric motors and operable to pressurize hydraulic fluid for operating the fluid control devices \n130\n, \n132\n, \n138\n, as described herein.', 'The well construction system \n100\n may further include a drilling fluid circulation system or equipment operable to circulate fluids between the surface equipment \n110\n and the drill bit \n126\n during drilling and other operations.', 'For example, the drilling fluid circulation system may be operable to inject a drilling fluid from the wellsite surface \n104\n into the wellbore \n102\n via an internal fluid passage \n121\n extending longitudinally through the drill string \n120\n.', 'The drilling fluid circulation system may comprise a pit, a tank, and/or other fluid container \n142\n holding the drilling fluid \n140\n (i.e., drilling mud), and one or more mud pump units \n144\n (i.e., drilling fluid pumps) operable to move the drilling fluid \n140\n from the container \n142\n into the fluid passage \n121\n of the drill string \n120\n via a fluid conduit \n146\n extending from the pump units \n144\n to the top drive \n116\n and an internal passage extending through the top drive \n116\n.', 'Each pump unit \n144\n may comprise a fluid pump (not shown) operable to pump the drilling fluid \n140\n and a prime mover (e.g., an electric motor) (not shown) operable to drive the corresponding fluid pump.', 'The fluid conduit \n146\n may comprise one or more of a pump discharge line, a stand pipe, a rotary hose, and a gooseneck connected with a fluid inlet of the top drive \n116\n.', 'The pumps \n144\n and the container \n142\n may be fluidly connected by a fluid conduit \n148\n, such as a suction line.', 'During drilling operations, the drilling fluid may continue to flow downhole through the internal passage \n121\n of the drill string \n120\n, as indicated by directional arrow \n131\n.', 'The drilling fluid may exit the BHA \n124\n via ports \n128\n in the drill bit \n126\n and then circulate uphole through an annular space \n108\n of the wellbore \n102\n defined between an exterior of the drill string \n120\n and the wall of the wellbore \n102\n, such flow being indicated by directional arrows \n133\n.', 'In this manner, the drilling fluid lubricates the drill bit \n126\n and carries formation cuttings uphole to the wellsite surface \n104\n.', 'The returning drilling fluid may exit the annular space \n108\n via different fluid control devices during different stages or scenarios of well drilling operations.', 'For example, the drilling fluid may exit the annular space \n108\n via a bell nipple \n139\n, the RCD \n138\n, or a ported adapter \n136\n (e.g., a spool, cross adapter, a wing valve, etc.) located above one or more rams of the BOP stack \n130\n.', 'During normal drilling operations, the drilling fluid may exit the annular space \n108\n via the bell nipple \n139\n and then be directed toward drilling fluid reconditioning equipment \n170\n via a fluid conduit \n158\n (e.g., a gravity return line) to be cleaned and/or reconditioned, as described below, before being returned to the container \n142\n for recirculation.', 'During managed pressure drilling operations, the drilling fluid may exit the annular space \n108\n via the RCD \n138\n and then be directed into a choke manifold \n152\n (e.g., a managed pressure drilling choke manifold) via a fluid conduit \n150\n (e.g., a drilling pressure control line).', 'The choke manifold \n152\n may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow through and out of the choke manifold \n152\n.', 'Backpressure may be applied to the annular space \n108\n by variably restricting flow of the drilling fluid or other fluids flowing through the choke manifold \n152\n.', 'The greater the restriction to flow through the choke manifold \n152\n, the greater the backpressure applied to the annular space \n108\n.', 'The drilling fluid exiting the choke manifold \n152\n may then pass through the drilling fluid reconditioning equipment \n170\n before being returned to the container \n142\n for recirculation.', 'During well pressure control operations, such as when one or more rams of the BOP stack \n130\n is closed, the drilling fluid may exit the annular space \n108\n via the ported adapter \n136\n and be directed into a choke manifold \n156\n (e.g., a rig choke manifold or a well control choke manifold) via a fluid conduit \n154\n (e.g., a rig choke line).', 'The choke manifold \n156\n may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow of the drilling fluid through the choke manifold \n156\n.', 'Backpressure may be applied to the annular space \n108\n by variably restricting flow of the drilling fluid (and other fluids) flowing through the choke manifold \n156\n.', 'The drilling fluid exiting the choke manifold \n156\n may then pass through the drilling fluid reconditioning equipment \n170\n before being returned to the container \n142\n for recirculation.', 'Before being returned to the container \n142\n, the drilling fluid returning to the wellsite surface \n104\n may be cleaned and/or reconditioned via the drilling fluid reconditioning equipment \n170\n, which may include one or more of liquid gas (i.e., mud gas) separators \n171\n, shale shakers \n172\n, and other drilling fluid cleaning and reconditioning equipment \n173\n.', 'The liquid gas separators \n171\n may remove formation gases entrained in the drilling fluid discharged from the wellbore \n102\n and the shale shakers \n172\n may separate and remove solid particles \n141\n (e.g., drill cuttings) from the drilling fluid.', 'The drilling fluid reconditioning equipment \n170\n may further comprise other equipment \n173\n operable to remove additional gas and finer formation cuttings from the drilling fluid and/or modify chemical and/or physical properties or characteristics (e.g., rheology, density, etc.) of the drilling fluid.', 'For example, the drilling fluid reconditioning equipment \n170\n may include a degasser, a desander, a desilter, a centrifuge, a mud cleaner, and/or a decanter, among other examples.', 'The drilling fluid reconditioning equipment \n170\n may further include chemical containers and mixing equipment collectively operable to mix or otherwise add selected chemicals to the drilling fluid returning from the wellbore \n102\n to modify chemical and/or physical properties or characteristics of the drilling fluid being pumped back into the wellbore \n102\n.', 'Intermediate tanks/containers (not shown) may be utilized to hold the drilling fluid while the drilling fluid progresses through the various stages or portions \n171\n, \n172\n, \n173\n of the drilling fluid reconditioning equipment \n170\n.', 'The cleaned and reconditioned drilling fluid may be transferred to the fluid container \n142\n, the solid particles \n141\n removed from the drilling fluid may be transferred to a solids container \n143\n (e.g., a reserve pit), and/or the removed gas may be transferred to a flare stack \n174\n via a conduit \n175\n (e.g., a flare line) to be burned or to a container (not shown) for storage and removal from the wellsite.', 'The surface equipment \n110\n may include a tubular handling system or equipment operable to store, move, connect, and disconnect tubulars (e.g., drill pipes) to assemble and disassemble the conveyance means \n122\n of the drill string \n120\n during drilling operations.', 'For example, a catwalk \n161\n may be utilized to convey tubulars from a ground level, such as along the wellsite surface \n104\n, to the rig floor \n114\n, permitting the elevator \n129\n to grab and lift the tubulars above the wellbore \n102\n for connection with previously deployed tubulars.', 'The catwalk \n161\n may have a horizontal portion and an inclined portion that extends between the horizontal portion and the rig floor \n114\n.', 'The catwalk \n161\n may comprise a skate \n163\n movable along a groove (not shown) extending longitudinally along the horizontal and inclined portions of the catwalk \n161\n.', 'The skate \n163\n may be operable to convey (e.g., push) the tubulars along the catwalk \n161\n to the rig floor \n114\n.', 'The skate \n163\n may be driven along the groove by a drive system (not shown), such as a pulley system or a hydraulic system.', 'Additionally, one or more racks (not shown) may adjoin the horizontal portion of the catwalk \n161\n.', 'The racks may have a spinner unit for transferring tubulars to the groove of the catwalk \n161\n.', 'The tubular handling system may comprise a plurality of actuators collectively operable to move various portions of the tubular handling equipment to perform the methods and operations described herein.', 'The actuators may be or comprise electric motors and/or hydraulic cylinders and rotary actuators.', 'The hydraulic cylinders and rotary actuators may be powered by hydraulic power packs comprising hydraulic pumps actuated by electric motors to pressurize hydraulic fluid.', 'An iron roughneck \n165\n may be positioned on the rig floor \n114\n.', 'The iron roughneck \n165\n may comprise a torqueing portion \n167\n, such as may include a spinner and a torque wrench comprising a lower tong and an upper tong.', 'The torqueing portion \n167\n of the iron roughneck \n165\n may be moveable toward and at least partially around the drill string \n120\n, such as may permit the iron roughneck \n165\n to make up and break out connections of the drill string \n120\n.', 'The torqueing portion \n167\n may also be moveable away from the drill string \n120\n, such as may permit the iron roughneck \n165\n to move clear of the drill string \n120\n during drilling operations.', 'The spinner of the iron roughneck \n165\n may be utilized to apply low torque to make up and break out threaded connections between tubulars of the drill string \n120\n, and the torque wrench may be utilized to apply a higher torque to tighten and loosen the threaded connections.', 'The iron roughneck may comprise a plurality of actuators collectively operable to move various portions of the iron roughneck to perform the methods and operations described herein.', 'The actuators may be or comprise electric motors.', 'A set of slips \n119\n may be located on the rig floor \n114\n, such as may accommodate therethrough the drill string \n120\n during tubular make up and break out operations and during the drilling operations.', 'The slips \n119\n may be in an open position during drilling operations to permit advancement of the drill string \n120\n, and in a closed position to clamp the upper end (e.g., the uppermost tubular) of the drill string \n120\n to thereby suspend and prevent advancement of the drill string \n120\n within the wellbore \n102\n, such as during the make up and break out operations.', 'During drilling operations, the various well construction equipment of the well construction system \n100\n may progress through a plurality of coordinated well construction operations (i.e., operational sequences) to drill or otherwise construct the wellbore \n102\n.', 'The well construction operations may change based on a digital drilling program, status of the well, status of the subterranean formation, stage of drilling operations (e.g., tripping, drilling, tubular handling, etc.), and type downhole tubulars (e.g., drill pipe) utilized, among other examples.', 'During drilling operations, the hoisting system lowers the drill string \n120\n while the top drive \n116\n rotates the drill string \n120\n to advance the drill string \n120\n downward within the wellbore \n102\n and into the formation \n106\n.', 'During the advancement of the drill string \n120\n, the slips \n119\n are in an open position, and the iron roughneck \n165\n is moved away or is otherwise clear of the drill string \n120\n.', 'When the upper end of the drill string \n120\n (i.e., upper end of the uppermost tubular of the drill string \n120\n) connected to the drive shaft \n125\n is near the slips \n119\n and/or the rig floor \n114\n, the top drive \n116\n ceases rotating and the slips \n119\n close to clamp the upper end of the drill string \n120\n.', 'The grabber of the top drive \n116\n then clamps the uppermost tubular connected to the drive shaft \n125\n, and the drive shaft \n125\n rotates in a direction reverse from the drilling rotation to break out the connection between the drive shaft \n125\n and the uppermost tubular.', 'The grabber of the top drive \n116\n may then release the uppermost tubular.', 'Multiple tubulars may be loaded on the rack of the catwalk \n161\n and individual tubulars may be transferred from the rack to the groove in the catwalk \n161\n, such as by the spinner unit.', 'The tubular positioned in the groove may be conveyed along the groove by the skate \n163\n until the box end of the tubular projects above the rig floor \n114\n.', 'The elevator \n129\n of the top drive \n116\n then grasps the protruding box end, and the drawworks \n118\n may be operated to lift the top drive \n116\n, the elevator \n129\n, and the new tubular.', 'The hoisting system then raises the top drive \n116\n, the elevator \n129\n, and the new tubular until the tubular is aligned with the upper portion of the drill string \n120\n clamped by the slips \n119\n.', 'The iron roughneck \n165\n is moved toward the drill string \n120\n, and the lower tong of the torqueing portion \n167\n clamps onto the upper end of the drill string \n120\n.', 'The spinning system threadedly connects the lower end (i.e., pin end) of the new tubular with the upper end (i.e., box end) of the drill string \n120\n.', 'The upper tong then clamps onto the new tubular and rotates with high torque to complete making up the connection with the drill string \n120\n.', 'In this manner, the new tubular becomes part of the drill string \n120\n.', 'The iron roughneck \n165\n then releases and moves clear of the drill string \n120\n.', 'The grabber of the top drive \n116\n may then clamp onto the drill string \n120\n.', 'The drive shaft \n125\n is brought into contact with the upper end of the drill string \n120\n (e.g., the box end of the uppermost tubular) and rotated to make up a connection between the drill string \n120\n and the drive shaft \n125\n.', 'The grabber then releases the drill string \n120\n, and the slips \n119\n are moved to the open position.', 'The drilling operations may then resume.', 'The tubular handling equipment may further include a tubular handling manipulator (THM) \n160\n disposed in association with a vertical pipe rack \n162\n for storing tubulars \n111\n (e.g., drill pipes, drill collars, drill pipe stands, casing joints, etc.).', 'The vertical pipe rack \n162\n may comprise or support a fingerboard \n164\n defining a plurality of slots configured to support or otherwise hold the tubulars \n111\n within or above a setback \n166\n (e.g., a platform or another area) located adjacent to, along, or below the rig floor \n114\n.', 'The fingerboard \n164\n may comprise a plurality of fingers (not shown), each associated with a corresponding slot and operable to close around and/or otherwise interpose individual tubulars \n111\n to maintain the tubulars \n111\n within corresponding slots of the fingerboard \n164\n.', 'The vertical pipe rack \n162\n may be connected with and supported by the support structure \n112\n or another portion of the wellsite system \n100\n.', 'The fingerboard \n164\n/setback \n166\n provide storage (e.g., a temporary storage) of tubulars \n111\n during various operations, such as during and between tripping out and tripping of the drill string \n120\n.', 'The THM \n160\n may comprise a plurality of actuators collectively operable to move various portions of the THM \n160\n to perform the methods and operations described herein.', 'The actuators may be or comprise electric motors.', 'The THM \n160\n may be operable to transfer the tubulars \n111\n between the fingerboard \n164\n/setback \n166\n and the drill string \n120\n (i.e., space above the suspended drill string \n120\n).', 'For example, the THM \n160\n may include arms \n168\n terminating with clamps \n169\n, such as may be operable to grasp and/or clamp onto one of the tubulars \n111\n.', 'The arms \n168\n of the THM \n160\n may extend and retract, and/or at least a portion of the THM \n160\n may be rotatable and/or movable toward and away from the drill string \n120\n, such as may permit the THM \n160\n to transfer the tubular \n111\n between the fingerboard \n164\n/setback \n166\n and the drill string \n120\n.', 'To trip out the drill string \n120\n, the top drive \n116\n is raised, the slips \n119\n are closed around the drill string \n120\n, and the elevator \n129\n is closed around the drill string \n120\n.', 'The grabber of the top drive \n116\n clamps the upper end of a tubular of the drill string \n120\n coupled to the drive shaft \n125\n.', 'The drive shaft \n125\n then rotates in a direction reverse from the drilling rotation to break out the connection between the drive shaft \n125\n and the drill string \n120\n.', 'The grabber of the top drive \n116\n then releases the tubular of the drill string \n120\n, and the drill string \n120\n is suspended by (at least in part) the elevator \n129\n.', 'The iron roughneck \n165\n is moved toward the drill string \n120\n.', 'The lower tong clamps onto a lower tubular below a connection of the drill string \n120\n, and the upper tong clamps onto an upper tubular above that connection.', 'The upper tong then rotates the upper tubular to provide a high torque to break out the connection between the upper and lower tubulars.', 'The spinning system then rotates the upper tubular to separate the upper and lower tubulars, such that the upper tubular is suspended above the rig floor \n114\n by the elevator \n129\n.', 'The iron roughneck \n165\n then releases the drill string \n120\n and moves clear of the drill string \n120\n.', 'The THM \n160\n may then move toward the drill string \n120\n to grasp the tubular suspended from the elevator \n129\n.', 'The elevator \n129\n then opens to release the tubular.', 'The THM \n160\n then moves away from the drill string \n120\n while grasping the tubular with the clamps \n169\n, places the tubular in the fingerboard \n164\n/setback \n166\n, and releases the tubular for storage.', 'This process is repeated until the intended length of drill string \n120\n is removed from the wellbore \n102\n.', 'The well construction system \n100\n may further comprise a power supply system \n178\n configured to supply electrical and mechanical (e.g., fluid) power for actuating or otherwise powering the surface equipment \n110\n.', 'The power supply system \n178\n may include one or more electric generators, electrical energy storage devices (e.g., batteries, capacitors, etc.), and fuel storage devices, among other examples.', 'The power supply system \n178\n may also include various means (not shown) for transferring and/or distributing electrical power, mechanical power, and fuel to the well construction equipment and between various pieces of equipment of the power supply system \n178\n, including electrical power conductors, electrical connectors, electrical relays, fluid conductors, fluid connectors, and fluid valves, among other examples.', 'The surface equipment \n110\n of the well construction system \n100\n may also comprise a control center \n190\n from which various portions of the well construction system \n100\n, such as the top drive \n116\n, the hoisting system, the tubular handling system, the drilling fluid circulation system, the well control system, the BHA \n124\n, among other examples, may be monitored and controlled.', 'The control center \n190\n may be located on the rig floor \n114\n or another location of the well construction system \n100\n.', 'The control center \n190\n may comprise a facility \n191\n (e.g., a room, a cabin, a trailer, etc.) containing a control workstation \n197\n, which may be operated by rig personnel \n195\n (e.g., a driller or another human rig operator) to monitor and control various well construction equipment or portions of the well construction system \n100\n.', 'The control workstation \n197\n may comprise or be communicatively connected with a central controller \n192\n (e.g., a processing device, a computer, etc.), such as may be operable to receive, process, and output information to monitor operations of and provide control to one or more portions of the well construction system \n100\n.', 'For example, the central controller \n192\n may be communicatively connected with the various surface and downhole equipment described herein, and may be operable to receive signals from and transmit signals to such equipment to perform various operations described herein.', 'The central controller \n192\n may store executable computer program code, instructions, and/or operational parameters or set-points, including for implementing one or more aspects of methods and operations described herein.', 'The central controller \n192\n may be located within and/or outside of the facility \n191\n.', 'Although it is possible that the entirety of the central controller \n192\n is implemented within one device, it is also contemplated that one or more components or functions of the central controller \n192\n may be implemented across multiple devices, some or an entirety of which may be implemented as part of the control center \n190\n and/or located within the facility \n191\n.', 'The control workstation \n197\n may be operable for entering or otherwise communicating control data (e.g., commands, signals, information, etc.) to the central controller \n192\n and other equipment controller by the rig personnel \n195\n, and for displaying or otherwise communicating information from the central controller \n192\n to the rig personnel \n195\n.', 'The control workstation \n197\n may comprise a plurality of human-machine interface (HMI) devices, including one or more input devices \n194\n (e.g., a keyboard, a mouse, a joystick, a touchscreen, etc.) and one or more output devices \n196\n (e.g., a video monitor, a touchscreen, a printer, audio speakers, etc.).', 'Communication between the central controller \n192\n, the input and output devices \n194\n, \n196\n, and the various well construction equipment may be via wired and/or wireless communication means.', 'However, for clarity and ease of understanding, such communication means are not depicted, and a person having ordinary skill in the art will appreciate that such communication means are within the scope of the present disclosure.', 'Well construction systems within the scope of the present disclosure may include more or fewer components than as described above and depicted in \nFIG.', '1\n.', 'Additionally, various equipment and/or subsystems of the well construction system \n100\n shown in \nFIG.', '1\n may include more or fewer components than as described above and depicted in \nFIG. \n1\n.', 'For example, various engines, electric motors, hydraulics, actuators, valves, and/or other components not explicitly described herein may be included in the well construction system \n100\n, and are within the scope of the present disclosure.', 'The present disclosure further provides various implementations of systems and/or methods for controlling one or more portions of the well construction system \n100\n. \nFIG.', '2\n is a schematic view of at least a portion of an example implementation of a drilling rig control system \n200\n (referred to hereinafter as a “rig control system”) for monitoring and controlling various well construction equipment of the well construction system \n100\n shown in \nFIG.', '1\n.', 'The rig control system \n200\n may comprise one or more features of the well construction system \n100\n, including where indicated by the same reference numerals.', 'Accordingly, the following description refers to \nFIGS.', '1\n and \n2\n, collectively.', 'The various pieces of well construction equipment described above and shown in \nFIGS.', '1\n and \n2\n may each comprise one or more (e.g., combustion, hydraulic, electrical, etc.)', 'actuators, which when operated, may cause the corresponding well construction equipment to perform intended actions (e.g., work, tasks, movements, operations, etc.).', 'Each piece of well construction equipment may further carry or comprise one or more sensors disposed in association with a corresponding actuator or another portion of the piece of equipment.', 'Each sensor may be communicatively connected with a corresponding equipment controller and operable to generate sensor data (e.g., electrical sensor signals or measurements, feedback signals, feedback loop, etc.)', 'indicative of an operational (e.g., mechanical, physical, etc.) status of the corresponding piece of well construction equipment or actuator of that piece of equipment, thereby permitting the operational status of the piece of equipment to be monitored by the equipment controller.', 'The sensor data may be utilized by the equipment controller as feedback data, permitting operational control of the piece of well construction equipment and coordination with other well construction equipment.', 'The rig control system \n200\n may be in real-time communication with and utilized to monitor and/or control various portions, components, and equipment of the well construction system \n100\n described herein.', 'The equipment of the well construction system \n100\n may be grouped into several subsystems, each operable to perform a corresponding operation and/or a portion of the well construction operations described herein.', 'The subsystems may include a tubular handling (TH) system \n211\n, a fluid processing (FP) system \n212\n, a managed pressure drilling (MPD) system \n213\n, a drilling fluid circulation (DFC) system \n214\n, a drill string rotation system (DSR) system \n215\n, a choke pressure control (CPC) system \n216\n, a well pressure control (WC) system \n217\n, and a power supply (PS) system \n218\n.', 'The TH system \n211\n may include the support structure \n112\n, a tubular hoisting system (e.g., the drawworks \n118\n, the elevator links \n127\n, the elevator \n129\n, and/or the slips \n119\n), a tubular handling system or equipment (e.g., the catwalk \n161\n, the THM \n160\n, the setback \n166\n, and/or the iron roughneck \n165\n), and/or other tubular handling equipment.', 'Accordingly, the TH system \n211\n may perform tubular handling and hoisting operations.', 'The TH system \n211\n may also serve as a support platform for tubular rotation equipment and staging ground for rig operations, such as connection make up and break out operations described above.', 'The FP system \n212\n may include the drilling fluid reconditioning equipment \n170\n, the flare stack \n174\n, the containers \n142\n, \n143\n, and/or other equipment.', 'Accordingly, the FP system \n212\n may perform fluid cleaning, reconditioning, and mixing operations.', 'The MPD system \n213\n may include the RCD \n138\n, the power unit \n137\n, the choke manifold \n152\n, and/or other equipment.', 'The DFC system \n214\n may comprise the pumps \n144\n, the drilling fluid container \n142\n, the bell nipple \n139\n, and/or other equipment collectively operable to pump and circulate the drilling fluid at the wellsite surface and downhole.', 'The DSR system \n215\n may include the top drive \n116\n and/or the rotary table and kelly.', 'The CPC system \n216\n may comprise the choke manifold \n156\n, the ported adapter \n136\n, and/or other equipment, and the WC system \n217\n may comprise the BOP stack \n130\n, the power unit \n137\n, and a BOP control station for controlling the power unit \n137\n.', 'The PS system \n218\n may comprise various sources of electrical power operable to power the well construction equipment of the well construction system \n100\n, including the well construction equipment of the well construction subsystems \n211\n-\n217\n.', 'The PS system \n218\n may also include various means for transferring and/or distributing electrical power and fuel to the well construction equipment and between various pieces of equipment of the PS system \n218\n, including electrical power conductors, electrical connectors, electrical relays, fluid conductors, fluid connectors, and fluid valves, among other examples.', 'The sources of electrical power may include electric generators, electrical energy storage devices (e.g., batteries, capacitors, etc.), fuel storage devices, and a remote electrical power grid, among other examples.', 'Each of the well construction subsystems \n211\n-\n218\n may further comprise various communication equipment (e.g., modems, network interface cards, etc.) and communication conductors (e.g., cables), communicatively connecting the equipment (e.g., sensors and/or actuators) of each subsystem \n211\n-\n218\n with a central controller \n192\n and a control workstation \n197\n.', 'Although the well construction equipment listed above and shown in \nFIG.', '1\n is associated with certain wellsite subsystems \n211\n-\n218\n, such associations are merely examples that are not intended to limit or prevent such well construction equipment from being associated with two or more wellsite subsystems \n211\n-\n218\n and/or different wellsite subsystems \n211\n-\n218\n.', 'The rig control system \n200\n may include various local controllers \n221\n-\n228\n, each operable to control various well construction equipment of a corresponding subsystem \n211\n-\n218\n and/or an individual piece of well construction equipment of a corresponding subsystem \n211\n-\n218\n.', 'As described above, each well construction subsystem \n211\n-\n218\n includes various well construction equipment comprising corresponding actuators \n241\n-\n248\n for performing operations of the well construction system \n100\n.', 'Each subsystem \n211\n-\n218\n may include various sensors \n231\n-\n238\n operable to generate sensor data (e.g., signals, information, measurements, etc.)', 'indicative of operational status of the well construction equipment of each subsystem \n211\n-\n218\n.', 'Each local controller \n221\n-\n228\n may output control data (e.g., commands, signals, information, etc.) to one or more actuators \n241\n-\n248\n to perform corresponding actions of a piece of equipment or subsystem \n211\n-\n218\n.', 'Each local controller \n221\n-\n228\n may receive sensor data generated by one or more sensors \n231\n-\n238\n indicative of operational status of an actuator or another portion of a piece of equipment or subsystem \n211\n-\n218\n.', 'Although the local controllers \n221\n-\n228\n, the sensors \n231\n-\n238\n, and the actuators \n241\n-\n248\n are each shown as a single block, it is to be understood that each local controller \n221\n-\n228\n, sensor \n231\n-\n238\n, and actuator \n241\n-\n248\n may be or comprise a plurality of local controllers, sensors, and actuators.', 'The sensors \n231\n-\n238\n may include sensors utilized for operation of the various subsystems \n211\n-\n218\n of the well construction system \n100\n.', 'For example, the sensors \n231\n-\n238\n may include cameras, position sensors, speed sensors, acceleration sensors, pressure sensors, force sensors, temperature sensors, flow rate sensors, vibration sensors, electrical current sensors, electrical voltage sensors, resistance sensors, gesture detection sensors or devices, voice actuated or recognition devices or sensors, chemical sensors, exhaust sensors, and/or other examples.', 'The sensor data may include signals, information, and/or measurements indicative of equipment operational status (e.g., on or off, percent load, up or down, set or released, etc.), drilling parameters (e.g., depth, hook load, torque, etc.), auxiliary parameters (e.g., vibration data of a pump), flow rate, temperature, operational speed, position, and pressure, among other examples.', 'The acquired sensor data may include or be associated with a timestamp (e.g., date and/or time) indicative of when the sensor data was acquired.', 'The sensor data may also or instead be aligned with a depth or other drilling parameter.', 'The local controllers \n221\n-\n228\n, the sensors \n231\n-\n238\n, and the actuators \n241\n-\n248\n may be communicatively connected with the central controller \n192\n.', 'For example, the local controllers \n221\n-\n228\n may be in communication with the sensors \n231\n-\n238\n and actuators \n241\n-\n248\n of the corresponding subsystems \n211\n-\n218\n via local communication networks (e.g., field buses) (not shown) and the central controller \n192\n may be in communication with the subsystems \n211\n-\n218\n via a central communication network \n209\n (e.g., a data bus, a field bus, a wide-area-network (WAN), a local-area-network (LAN), etc.).', 'The sensor data generated by the sensors \n231\n-\n238\n of the subsystems \n211\n-\n218\n may be made available for use by the central controller \n192\n and/or the local controllers \n221\n-\n228\n.', 'Similarly, control data output by the central controller \n192\n and/or the local controllers \n221\n-\n228\n may be automatically communicated to the various actuators \n241\n-\n248\n of the subsystems \n211\n-\n218\n, perhaps pursuant to predetermined programming, such as to facilitate well construction operations and/or other operations described herein.', 'Although the central controller \n192\n is shown as a single device (i.e., a discrete hardware component), it is to be understood that the central controller \n192\n may be or comprise a plurality of equipment controllers and/or other electronic devices collectively operable to monitor and control operations (i.e., computational processes or methods) of the well construction system.', 'The central controller \n192\n may be located within or form a portion of a control center \n190\n, however a portion of the central controller \n192\n may instead be external to the control center \n190\n.', 'The sensors \n231\n-\n238\n and actuators \n241\n-\n248\n may be monitored and/or controlled by corresponding local controllers \n221\n-\n228\n and/or the central controller \n192\n.', 'For example, the central controller \n192\n may be operable to receive sensor data from the sensors \n231\n-\n238\n of the wellsite subsystems \n211\n-\n218\n in real-time, and to output real-time control data directly to the actuators \n241\n-\n248\n of the subsystems \n211\n-\n218\n based on the received sensor data.', 'However, certain operations of the actuators \n241\n-\n248\n of each subsystem \n211\n-\n218\n may be controlled by a corresponding local controller \n221\n-\n228\n, which may control the actuators \n241\n-\n248\n based on sensor data received from the sensors \n231\n-\n238\n of the corresponding subsystem \n211\n-\n218\n and/or based on control data received from the central controller \n192\n.', 'The rig control system \n200\n may be a tiered control system, wherein control of the subsystems \n211\n-\n218\n of the well construction system \n100\n may be provided via a first tier of the local controllers \n221\n-\n228\n and a second tier of the central controller \n192\n.', 'The central controller \n192\n may facilitate control of one or more of the subsystems \n211\n-\n218\n at the level of each individual subsystem \n211\n-\n218\n.', 'For example, in the FP system \n212\n, sensor data may be fed into the local controller \n242\n, which may respond to control the actuators \n232\n.', 'However, for control operations that involve multiple subsystems \n211\n-\n218\n, the control may be coordinated through the central controller \n192\n operable to coordinate control of well construction equipment of two, three, four, or more (each) of the subsystems \n211\n-\n218\n.', 'For example, coordinated control operations may include the control of downhole pressure during tripping.', 'The downhole pressure may be affected by the DFC system \n214\n (e.g., pump rate), the MPD system \n213\n (e.g., position of the choke \n152\n), and the TH system \n211\n (e.g., tripping speed).', 'Thus, when it is intended to maintain certain downhole pressure during tripping, the central controller \n192\n may output control data to two or more of the participating subsystems \n211\n-\n218\n.', 'As described above, the central controller \n192\n may control various operations of the subsystems \n211\n-\n218\n via analysis of sensor data from one or more of the wellsite subsystems \n211\n-\n218\n to facilitate coordinated control between the subsystems \n211\n-\n218\n.', 'The central controller \n192\n may generate control data to coordinate operations of various well construction equipment of the subsystems \n211\n-\n218\n.', 'The control data may include, for example, commands from rig personnel, such as turn on or turn off a pump, switch on or off a fluid valve, and update a physical property set-point, among other examples.', 'The local controllers \n221\n-\n228\n may each include a fast control loop that directly obtains sensor data and executes, for example, a control algorithm to generate the control data.', 'The central controller \n192\n may include a slow control loop to periodically obtain sensor data and generate the control data.', 'The rig control system \n200\n, including the central controller \n192\n and the local controllers \n221\n-\n228\n, facilitates operation of the well construction equipment in an equipment focused manner, such as to maintain the choke pressure to a certain value or to rotate the drill string at a certain rotational speed.', 'The rig control system \n200\n may also coordinate operations of certain pieces of equipment to achieve intended operations, such as to move a tubular from the fingerboard to the well center, break up a tubular stand from the well center, or rack an individual tubular back to the fingerboard.', 'Each such operation utilizes coordinated control of multiple pieces of pipe handling equipment by the central controller \n192\n.', 'The central controller \n192\n, the local controllers \n221\n-\n228\n, and/or other controllers or processing devices (referred to hereinafter as “equipment controllers”) of the rig control system \n200\n may each or collectively be operable to receive and store machine-readable and executable program code instructions (e.g., computer program code, algorithms, programmed processes or operations, etc.)', 'on a memory device (e.g., a memory chip) and then execute the program code instructions to run, operate, or perform a control process for monitoring and/or controlling the well construction equipment of the well construction system \n100\n.', 'The central controller \n192\n may run (i.e., execute) a control process \n250\n (e.g., a coordinated control process or anther computer process) and each local controller \n221\n-\n228\n may run a corresponding control process (e.g., a local control process or another computer process) (not shown).', 'Two or more of the local controllers \n221\n-\n228\n may run their local control processes to collectively coordinate operations between well construction equipment of two or more of the subsystems \n211\n-\n218\n.', 'The control process \n250\n of the central controller \n192\n may operate as a mechanization manager of the rig control system \n200\n, coordinating well construction operations of the well construction equipment of the well construction system \n100\n.', 'The control process \n250\n of the central controller \n192\n may output control data directly to the actuators \n241\n-\n248\n to control the well construction operations.', 'The control process \n250\n may also or instead output control data to the control process of one or more local controllers \n221\n-\n228\n, wherein each control process of the local controllers \n221\n-\n228\n may then output control data to the actuators \n241\n-\n248\n of the corresponding subsystem \n211\n-\n218\n to control a portion of the well construction operations performed by that subsystem \n211\n-\n218\n.', 'Thus, the control processes of equipment controllers (e.g., the central controller \n192\n and/or the local controllers \n221\n-\n228\n) of the rig control system \n200\n individually and collectively perform monitoring and control operations described herein, including monitoring and controlling well construction operations.', 'The program code instructions forming the basis for the control processes described herein may comprise rules (e.g., algorithms) based on the laws of physics for drilling and other well construction operations.', 'Each control process being run by an equipment controller of the rig control system \n200\n may receive and process (i.e., analyze) sensor data from the sensors \n231\n-\n238\n according to the program code instructions, and generate control data (i.e., control signals or information) to operate or otherwise control the actuators \n241\n-\n248\n of the well construction equipment.', 'Equipment controllers within the scope of the present disclosure can include, for example, programmable logic controllers (PLCs), industrial computers (IPCs), personal computers (PCs), soft PLCs, variable frequency drives (VFDs) and/or other controllers or processing devices operable to store and execute program code instructions, receive sensor data, and output control data to cause operation of the well construction equipment based on the program code instructions, sensor data, and/or control data.', 'The well construction system \n100\n may instead be monitored and operated manually by rig personnel (e.g., a driller, operational planner, maintenance supervisor, etc.)', 'via a central control workstation \n197\n and/or a remote control workstation \n210\n.', 'The control workstations \n197\n, \n210\n may be utilized to monitor, configure, control, and/or otherwise operate one or more of the subsystems \n211\n-\n218\n by the rig personnel.', 'The control workstations \n197\n, \n210\n may be communicatively connected with the central controller \n192\n and/or the local controllers \n221\n-\n228\n via the communication network \n209\n and operable to receive sensor data from the sensors \n231\n-\n238\n and transmit control data to the central controller \n192\n and/or the local controllers \n221\n-\n228\n to control the actuators \n241\n-\n248\n.', 'The control workstations \n197\n, \n210\n may be operable for entering or otherwise communicating control data to the central controller \n192\n and/or the local controllers \n221\n-\n228\n by the rig personnel for controlling the well construction equipment of the well construction system \n100\n.', 'Accordingly, the control workstations \n197\n, \n210\n may be utilized by the rig personnel to monitor and control the actuators \n241\n-\n248\n and other portions of the subsystems \n211\n-\n218\n via the central controller \n192\n and/or local controllers \n221\n-\n228\n.', 'The control workstations \n197\n, \n210\n may be operable for displaying or otherwise communicating sensor data output by the sensors \n231\n-\n238\n to the rig personnel, thereby permitting the rig personnel to monitor the subsystems \n211\n-\n218\n.', 'For example, the control workstations \n197\n, \n210\n may be operable to display to the rig personnel the present (i.e., current) operational status of the well construction equipment, including of the various sources of electrical power of the PS system \n218\n.', 'Each workstation \n197\n, \n210\n may be or comprise a terminal, a computer, or another device comprising one or more input devices (e.g., a keyboard, a mouse, a joystick, a touchscreen, etc.) and one or more output devices (e.g., a video monitor, a touchscreen, a printer, audio speakers, etc.).', 'Communication between each workstation \n197\n, \n210\n and the central controller \n192\n may be via wired and/or wireless communication means.', 'The control workstation \n197\n may be located within the control center \n190\n and utilized by the driller.', 'The control workstation \n210\n may be located in association with one or more of the equipment subsystems \n211\n-\n218\n or otherwise externally from the control center \n190\n, and utilized by other rig personnel, such operational planners and maintenance personnel.', 'During manual operation, the rig personnel may be or operate as the mechanization manager of the rig control system \n200\n by manually coordinating operations of various well construction equipment, such as to achieve an intended operational status (or drilling state) of the well construction operations, such as tripping in or drilling at an intended rate of penetration (ROP).', 'The control process of each local controller \n221\n-\n228\n may facilitate a lower (e.g., basic) level of control within the rig control system \n200\n to operate a corresponding piece of well construction equipment or a plurality of pieces of well construction equipment of a corresponding subsystem \n211\n-\n218\n.', 'Such control process may facilitate, for example, starting, stopping, and setting or maintaining an operational speed of a piece of well construction equipment.', 'During manual operation of the well construction system \n100\n, rig personnel manually controls the individual pieces of well construction equipment to achieve the intended operational status of each piece of well construction equipment.', 'The central controller \n192\n may be operable to receive and store machine-readable and executable program code instructions on a memory device and then execute such program code instructions to run, operate, or perform a power manager \n262\n (e.g., a power control process, a power management process, and/or another computer process) operable to monitor and control the PS system \n218\n of the well construction system \n100\n.', 'The program code instructions forming the basis for the power manager \n262\n described herein may comprise or be based on, for example, optimum efficiency performance curves or data of the various pieces of equipment forming the PS system \n218\n.', 'The power manager \n262\n run of the central controller \n192\n may operate to monitor and control generation and distribution of electrical power performed by the PS system \n218\n.', 'The power manager \n262\n may receive and process (e.g., analyze) sensor data from the sensors \n238\n according to the program code instructions to monitor performance of the PS system \n218\n, and generate control data (i.e., control signals or information) to operate or otherwise control the actuators \n248\n of the PS system \n218\n thereby controlling operations of the PS system \n218\n.', 'The power manager \n262\n may output control data directly to the actuators \n248\n to control the generation and distribution of electrical power.', 'The power manager \n262\n may also or instead output control data to one or more local controllers \n228\n, wherein each of the local controllers \n228\n may then output control data to the actuators \n248\n of the PS system \n218\n to control a portion of the power generation and distribution operations performed by the PS system \n218\n.', 'The power manager \n262\n may also or instead output control data to the actuators \n248\n and/or one or more local controllers \n228\n via the control process \n250\n.', 'The electrical actuators \n248\n may comprise one or more of electric motors, linear actuators, magnetic coils, switches, and relays, among other examples.', 'The central controller \n192\n may comprise a memory device operable to receive and store a digital drilling program \n252\n (i.e., a digital well construction plan) for drilling and otherwise constructing a planned well.', 'The digital drilling program \n252\n may include well specifications, operational parameters of the well construction equipment, and other information indicative of the planned well and the well construction equipment of the well construction system \n100\n.', 'For example, the digital drilling program \n252\n may include properties of the subterranean formation through which the planned well is to be drilled, the path (e.g., direction, curvature, orientation, etc.) along which the planned well is to be drilled through the formation, the depth (e.g., true vertical depth (TVD), measured depth (MD)) of the planned well, operational specifications (e.g., power output, weight, torque capabilities, speed capabilities, dimensions, size, etc.) of the well construction equipment (e.g., top drive, mud pumps, \n144\n, downhole mud motor \n184\n, etc.)', 'that is planned to be used to construct the planned well, and/or specifications (e.g., diameter, length, weight, etc.) of tubulars (e.g., drill pipe) that are planned to be used to construct the planned well.', 'The digital drilling program \n252\n may include knowledge (e.g., efficiency of various parameters) learned from offset wells that have been drilled.', 'Optimal parameters associated with the offset wells may then be used as the recommended parameters in a digital drilling program \n252\n for the present well.', 'The knowledge learned from the offset wells, including operational limits, such as maximum WOB, RPM, ROP, and/or tripping speed versus depth, may be applied and used as an operational limit within the digital drilling program \n252\n.', 'The digital drilling program \n252\n may further include an equipment operational plan (or schedule) indicative of planned well construction operations (e.g., tasks, operational sequences, etc.) that are intended to be performed by the well construction equipment as part of the well construction operations to construct the well.', 'Each planned well construction operation may comprise a plurality of operational sequences and may be performed by the well construction equipment as part of the well construction operations to construct the well.', 'The equipment operational plan may comprise order and/or time of each planned well construction operation.', 'A planned well construction operation may be or comprise drilling a predetermined portion or depth of the planned well, completing a predetermined portion or stage of drilling operations, drilling through a predetermined section of the subterranean formation, and performing a predetermined plurality of operational sequences, among other examples.', 'Each planned well construction operation may comprise a plurality or sequence of physical (i.e., mechanical) operations (i.e., actions) performed by various pieces of well construction equipment.', 'Example planned well construction operations may include operations of one or more pieces of the well construction equipment of the well construction system \n100\n described above in association with \nFIG.', '1\n.', 'The equipment operational plan of the digital drilling program \n252\n may further include planned operational parameters of the well construction equipment during each planned well construction operation included in the digital drilling program \n252\n, such as weight on bit (WOB), drilling fluid flow rate, top drive speed (RPM), and ROP as a function of wellbore depth.', 'The equipment operational plan of the digital drilling program \n252\n may include detailed information indicative of each planned well construction operation to accomplish an intended drilling objective (e.g., complete drilling of the well or complete drilling of a section of the well), or the equipment operational plan may include general information to accomplish the drilling objective.', 'The digital drilling program \n252\n may also include an electrical power plan (or schedule) indicative of level or amount of planned (e.g., projected, estimated, expected, etc.) level or amount of electrical power demand of the well construction equipment for performing or otherwise associated with each corresponding planned well construction operation indicated in the equipment operational plan of the digital drilling program \n252\n.', 'Thus, the electrical power plan may comprise information (e.g., a plan, a schedule, a sequence, a profile) indicative of the amount or level of planned electrical power demand that has to be met for each piece of well construction equipment to perform each planned well construction operation.', 'The electrical power plan may include detailed information indicative of planned electrical power demand of each piece of equipment to complete each planned well construction operation to accomplish an intended drilling objective.', 'However, the electrical power plan may include summary information indicative of planned overall or total electrical power demand of the well construction equipment to accomplish the intended drilling objective.', 'The electrical power plan may also comprise information indicative of level or amount of planned (e.g., projected, estimated, expected, etc.) level or amount of electrical power output capacity (i.e., available electrical power limit) that the PS system \n218\n can supply (e.g., generate or output) to the various well construction equipment of the well construction system \n100\n, including the well construction equipment of the subsystems \n211\n-\n218\n, such as to facilitate performance of the equipment operational plan of the digital drilling program \n252\n.', 'The planned electrical power output capacity may be calculated or otherwise determined by the power manager \n262\n based on the planned electrical power demand, such that the PS system \n218\n can supply an amount of electrical power that is sufficient to power the well construction equipment to perform the planned well construction operations.', 'Thus, the planned electrical power output capacity may be indicative of a planned maximum electrical power that the PS system \n218\n can output to the well construction equipment to perform the planned well construction operations.', 'The planned electrical power output capacity indicated in the electrical power plan may be greater than or equal to the planned electrical power demand indicated in the electrical power plan.', 'The information forming the digital drilling program \n252\n may originate or be delivered in digital format, such that it can be directly loaded to or saved by a memory device of the central controller \n192\n.', 'The digital drilling program \n252\n can be executed or analyzed programmatically by the control process \n250\n and/or the power manager \n262\n of the central controller \n192\n without human intervention.', 'The memory device storing the digital drilling program \n252\n may be or form a portion of the central controller \n192\n or the memory device storing the digital drilling program \n252\n may be communicatively connected with the central controller \n192\n.', 'The control process \n250\n and/or the power manager \n262\n may analyze the digital drilling program \n252\n and generate or output control data to the local controllers \n221\n-\n228\n or directly to the actuators \n241\n-\n248\n to control the well construction equipment to cause, facilitate, or otherwise implement one or more aspects of methods and operations described herein.', 'As further described below, the equipment operational plan and the electrical power plan of the digital drilling program \n252\n may be entered and/or adjusted (e.g., changed, recalibrated, modified, delayed, etc.)', 'manually the by the rig personnel drilling via the workstations \n197\n, \n210\n or automatically by one or more processes (e.g., the control process \n250\n and/or the power manager \n262\n) of the central controller \n192\n.', 'An equipment controller of the rig control system \n200\n for controlling the well construction system \n100\n may be operable to automate the well construction equipment to perform well construction operations and change such well construction operations as operational parameters of the well construction operations change and/or when an abnormal event (e.g., state and/or condition) is detected during the well construction operations.', 'An equipment controller may be operable to detect an abnormal event based on the sensor data received from the sensors \n231\n-\n238\n and cause the predetermined operations to be performed or otherwise implemented to stop or mitigate the abnormal event or otherwise in response to the abnormal event, without manual control of the well construction equipment by the rig personnel via the control workstation \n197\n, \n210\n.', 'For example, an equipment controller may be operable to make decisions related to selection of actions or sequences of well construction operations that are to be implemented during the well construction operations and/or the manner (e.g., speed, torque, mechanical power, electrical power, etc.) in which such selected well construction operations are to be implemented to stop or mitigate a detected abnormal event.', 'An equipment controller may be further operable to receive and store information that may be analyzed by the control process \n250\n to facilitate the equipment controller to detect the abnormal event, and select and implement the well construction operations to stop or mitigate the abnormal event.', 'The central controller \n192\n may be operable to receive and store machine-readable and executable program code instructions on a memory device and then execute such program code instructions to run, operate, or perform an abnormal event detector \n254\n (e.g., an abnormal event detecting computer process), which may be operable to analyze or otherwise process the sensor data received from the sensors \n231\n-\n238\n and detect an abnormal event (e.g., state and/or condition) experienced by or otherwise associated with one or more pieces of well construction equipment, and/or an abnormal event experienced by or otherwise associated with a wellbore (e.g., the wellbore \n102\n shown in \nFIG.', '1\n).', 'The abnormal event detector \n254\n may be operable to detect the abnormal events based on the sensor data and output abnormal event data indicative of the detected abnormal event.', 'One or more of the local controllers \n221\n-\n228\n may also execute program code instructions to execute a corresponding abnormal event detector \n254\n to detect a local abnormal event.', 'The local controllers \n221\n-\n228\n may then transmit data indicative of the local abnormal event to the central controller \n190\n for analysis.', 'One or more of the processes of the central controller \n192\n may then re-plan the planned well construction operations based on the detected abnormal events or otherwise based on the condition of the well and/or the well construction equipment.', 'For example, an abnormal event may be or comprise an abnormal operational surface event experienced by surface equipment (e.g., the surface equipment \n110\n shown in \nFIG.', '1\n) and/or an abnormal operational downhole event experienced by a drill string (e.g., the drill string \n120\n shown in \nFIG.', '1\n).', 'An example abnormal operational downhole event may include stick slip, axial vibrations, lateral vibrations, rotational vibrations, and stuck drill pipe.', 'The abnormal event may instead be or comprise an abnormal downhole fluid event experienced by a downhole fluid, such as wellbore fluid (e.g., drilling fluid and/or formation fluid) within the wellbore, and/or formation fluid within a rock formation (e.g., rock formation \n106\n shown in \nFIG.', '1\n) through which the wellbore extends.', 'An example abnormal downhole fluid event may include underpressure of the formation fluid, overpressure of the formation fluid, gains of the wellbore fluid, and losses of the wellbore fluid.', 'The central controller \n192\n may be operable to receive and store machine-readable and executable program code instructions on a memory device and then execute such program code instructions to run, operate, or perform an operational state detector \n256\n (e.g., an operational state detecting computer process), which may be operable to analyze or otherwise process the sensor data received from the sensors \n231\n-\n238\n and detect a state (e.g., a status or stage) of the well construction operations the well construction system \n100\n is performing.', 'The operational state detector \n256\n may then output operational state data indicative of the operational state of the well construction system \n100\n.', 'Operational states of the well construction system \n100\n may comprise, for example, drilling, tripping, circulating, and reaming.', 'The control process \n250\n and/or the power manager \n262\n may be operable to automatically operate the well construction equipment based on abnormal events detected by the abnormal event detector \n254\n and/or based on an operational state of the well construction system \n100\n detected by the operational state detector \n256\n.\n \nFIG.', '3\n is a schematic view of at least a portion of an example implementation of a PS system \n300\n of a well construction system \n100\n.', 'The PS system \n300\n may be communicatively connected with and controlled by the central controller \n192\n shown in \nFIGS.', '1\n and \n2\n.', 'The PS system \n300\n may be an example implementation of, and/or comprise one or more features of, the PS system \n218\n shown in \nFIG.', '2\n.', 'Accordingly, the following description refers to \nFIGS.', '1\n-\n3\n, collectively.', 'The PS system \n300\n may comprise a plurality of sources of electrical power electrically connected to an electrical power supply line \n302\n (e.g., a 600 volt/60 Hertz main line or bus and/or other electrical networks) of the well construction system \n100\n, such as may permit the electrical power sources to output electrical power to wellsite equipment \n304\n via the line \n302\n.', 'The electrical power sources may comprise a plurality of combustion engine/electric generator units (hereinafter referred to as “generator units”) \n310\n and one or more electrical energy storage units \n312\n (i.e., electrical storage systems).', 'The PS system \n300\n may also comprise a source \n316\n of hydrocarbon or other combustible gas produced at the wellsite \n104\n during the well construction operations fluidly or otherwise operatively connected to each of the generator units \n310\n.', 'The central controller \n192\n may be communicatively connected with the electrical power sources \n310\n, \n312\n and the produced gas source \n316\n via the communication network \n209\n to permit communication of sensor data (e.g., output data, feedback data, etc.)', 'to the central controller \n192\n, thereby permitting the central controller \n192\n to monitor operational status of the electrical power sources \n310\n, \n312\n and the produced gas source \n316\n.', 'The central controller \n192\n may also be communicatively connected with the electrical power sources \n310\n, \n312\n via the communication network \n209\n to permit communication of control data (e.g., output data, control commands, etc.)', 'from the central controller \n192\n to the electrical power sources \n310\n, \n312\n, thereby permitting the central controller \n192\n to control operational parameters of the electrical power sources \n310\n, \n312\n and the produced gas source \n316\n.', 'Electrical actuators of the wellsite equipment \n304\n, such as the well construction equipment of one or more of the well construction subsystems \n211\n-\n217\n, may be electrically connected with the line \n302\n, such as may permit the wellsite equipment \n304\n to receive electrical power to facilitate well construction operations performed by the wellsite equipment \n304\n.', 'The wellsite equipment \n304\n may include, for example, electric motors of the top drive \n116\n, the drawworks \n118\n, and the mud pumps \n144\n.', 'For the sake of clarity, \nFIG.', '3\n shows the produced gas source \n316\n connected to just one generator unit \n310\n.', 'However, it is to be understood that the produced gas source \n316\n may be fluidly connected to an engine of each of the generator units \n310\n.', 'The well construction system \n100\n may comprise, for example, two, three, four, five, six, or more generator units \n310\n.', 'Each generator unit \n310\n may comprise a combustion engine (e.g., a diesel engine, a diesel/natural gas mixture engine, a gas turbine, etc.) mechanically connected with and configured to rotate or otherwise actuate an electric generator to output electrical power to the line \n302\n.', 'Each generator unit \n310\n may further comprise a local control system comprising various electrical controllers and actuators (e.g., speed controller, voltage controller, electrical connectors, switches, circuit breakers, relays, etc.) for controlling operational parameters of the generator unit \n310\n, as well as a plurality of sensors for monitoring operational status of the generator unit \n310\n.', 'The generator units \n310\n may be skidded or otherwise mounted to a frame permitting transportation (e.g., via roadways) and installation (e.g., via cranes or lifts) at the wellsite \n104\n.', 'Each generator unit \n310\n may be communicatively connected with the central controller \n192\n, such as may permit the power manager \n262\n to output control data to control operation of each generator unit \n310\n, including to control operational status (e.g., on/off status) of each generator unit \n310\n and/or to control the amount of electrical power that is output to the line \n302\n or otherwise made available to the wellsite equipment via the line \n302\n.', 'The power manager \n262\n may receive various sensor data from the generator units \n310\n, analyze such sensor data, and output control data to the generator units \n310\n to control operation of the generator units \n310\n based on the received sensor data.', 'The sensor data output by each generator unit \n310\n to the power manager \n262\n may comprise data indicative of, for example, present operational status of the engine and/or the electric generator, present fault status, present operational speed of the engine and/or the electric generator, present throttle position of the engine, present engine load (e.g., load percentage with respect to maximum engine load), present electrical power generated, present engine power output, present electrical voltage generated, present electrical current generated, present fuel (e.g., gasoline, diesel fuel, and/or produced gas) consumption rate (e.g., flow rate) of the engine, and present temperature of the engine and/or the electric generator.', 'The control data output by the power manager \n262\n to each generator unit \n310\n may comprise data indicative of, for example, intended operational status of the engine and/or the electric generator, intended operational speed of the engine and/or the electric generator, intended throttle position of the engine, intended engine load, intended electrical power generated, intended engine power output, intended electrical voltage generated, intended electrical current generated, intended fuel consumption rate of the engine, and intended blackout limits.', 'One or more exhaust sensors \n320\n (e.g., sniffers) may be operatively connected with or along an exhaust port or the line \n322\n of each generator unit \n310\n.', 'The exhaust sensors \n320\n may be operable to output sensor data (e.g., sensor signals or measurements) indicative of various quantitative and qualitative properties of the exhaust output by the engine of each generator unit \n310\n.', 'The exhaust sensors \n320\n may be communicatively connected with the central controller \n192\n, such as may permit the power manager \n262\n to receive the sensor data (i.e., feedback data) from the exhaust sensors \n320\n to monitor operational status of the engines, analyze such sensor data, and output control data to the generator units \n310\n to control operation of the generator units \n310\n and the produced gas source \n316\n based on the received sensor data.', 'The sensor data output by the exhaust sensors \n320\n to the power manager \n262\n may comprise data indicative of, for example, quantity of particulate material (PM), quantity of carbon monoxide (CO), quantity of carbon dioxide (CO\n2\n), quantity of nitric oxide (NO), and quantity of nitrogen dioxide (NO\n2\n) (collectively referred to hereinafter as “exhaust emissions”).', 'For the sake of clarity, \nFIG.', '3\n shows just one exhaust sensor \n320\n connected to one generator unit \n310\n.', 'However, it is to be understood that the PS system \n300\n may comprise additional exhaust sensors \n320\n, each connected to an engine of a corresponding generator unit \n310\n.', 'The storage unit \n312\n may comprise a plurality of electrical storage devices (e.g., batteries, capacitors, etc.) connected in series and in parallel, and collectively operable to store a predetermined amount of electrical power and then output such electrical power to operate or help operate one or more components of the wellsite equipment \n304\n for a predetermined period of time.', 'For example, the storage unit \n312\n may supplement the generator units \n310\n by temporarily supplying electrical power during power demand spikes.', 'The storage unit \n312\n may be operable to store, for example, between about 0.5-1.0 megawatt-hours of electrical power.', 'The storage unit \n312\n may be operable to output the stored electrical energy at maximum rates ranging, for example, between about 1.0-1.5 megawatts.', 'The electrical energy storage unit \n312\n may be operable to selectively receive and store electrical power generated by the generator units \n310\n, and then selectively output the stored electrical power to the various electric actuators of the wellsite equipment \n304\n.', 'The storage unit \n312\n may further comprise a bi-directional inverter operable to convert the alternating current (AC) supplied by the generator units \n310\n to direct current (DC) power for storage by the electrical storage devices, and convert the DC power stored by the electrical storage devices to AC power for use by the wellsite equipment \n304\n.', 'However, instead of comprising the rechargeable electrical storage devices, the storage unit \n312\n may comprise one or more non-rechargeable electrical storage devices (e.g., non-rechargeable batteries) storing a fixed amount of electrical power.', 'The non-rechargeable electrical storage devices may store a predetermined amount of electrical power and then output such electrical power to operate or help operate one or more components of the wellsite equipment \n304\n for a predetermined period of time.', 'After the stored electrical power is drained from the non-rechargeable electrical storage devices, the non-rechargeable electrical storage devices can be replaced with new (charged) non-rechargeable electrical storage devices.', 'If non-rechargeable electrical storage devices are used, the storage unit \n312\n may comprise just a unidirectional inverter to convert the DC power stored by the electrical storage devices to AC power for use by the wellsite equipment \n304\n.', 'The storage unit \n312\n may further comprise a control system comprising various electric controllers and actuators (e.g., electrical connectors, switches, circuit breakers, relays, etc.) for controlling operational parameters of the storage unit \n312\n and a plurality of sensors for monitoring operational status of the storage unit \n312\n.', 'The storage unit \n312\n may be skidded or otherwise mounted to a frame permitting transportation (e.g., via roadways) and installation (e.g., via cranes or lifts) at the wellsite \n104\n.', 'The electrical energy storage unit \n312\n may be communicatively connected with the central controller \n192\n, such as may permit the power manager \n262\n to output control data to control operation of the storage unit \n312\n, including to control operational status (e.g., on/off status, charge/discharge, rate of charge/discharge, etc.) of each storage unit \n312\n and/or to control the amount of electrical power that is output to the line \n302\n or otherwise made available to the wellsite equipment \n304\n via the line \n302\n.', 'The power manager \n262\n may receive various sensor data (i.e., feedback data) from the sensors of the storage unit \n312\n, analyze such sensor data, and output control data to the storage unit \n312\n to control operation of the storage unit \n312\n based on the received sensor data and other data.', 'The sensor data output by the storage unit \n312\n to the power manager \n262\n may comprise data indicative of, for example, present operational status, present fault status, present battery health status, present status of electrical connection with the line \n302\n, present state of battery charge (e.g., present battery charge percentage with respect to maximum battery capacity), present battery efficiency, present power output (e.g., real and reactive power) to the line \n302\n, present AC and DC electrical voltage, present AC and DC electrical current, present AC electrical frequency, quantity of charge cycles, present peak load shaving, present load applied to the engine of the generator units \n310\n, present temperature of the battery and/or the inverter.', 'The control data output by the power manager \n262\n to the storage unit \n312\n may comprise data indicative of, for example, intended operational status, intended status of electrical connection with the line \n302\n, intended battery charge, intended battery efficiency, intended power output to the line \n302\n, intended AC and DC electrical voltage, intended AC and DC electrical current, intended AC electrical frequency, intended quantity of charge cycles, intended peak load shaving, and intended load to be applied to the engine of the generator units \n310\n.', 'The storage unit \n312\n may be selectively electrically connected to the generator units \n310\n via the line \n302\n, such as may permit the storage unit \n312\n to be selectively operated by the power manager \n262\n to receive and store the electrical power output to the line \n302\n by the generator units \n310\n.', 'The storage unit \n312\n may be electrically connected to the generator units \n310\n in parallel, such that the storage unit \n312\n operates or appears as a load to the generator units \n310\n when the storage unit \n312\n is storing electrical power output by the generator units \n310\n.', 'Utilization of the storage unit \n312\n as a load can facilitate a more efficient operation of the engines of the generator units \n310\n.', 'Generator units operating at higher efficiencies have lower fuel consumption, as well as lower emissions at higher engine loads.', 'However, generator units operating at lower efficiencies have higher fuel consumption, as well as higher emissions at low engine loads.', 'Furthermore, generator units turning on and off frequently to match power demand will accelerate wear and tear, leading to an increase in maintenance costs.', 'Thus, if one or more of the generator units \n310\n are operating at low efficiency caused by low engine load, the storage unit \n312\n can be operated to a “charge” state to store the electrical energy output by the generator units \n310\n, thereby increasing load on the generator units \n310\n to cause the generator units \n310\n to operate at higher efficiency that will result in lower fuel consumption and lower emissions.', 'Furthermore, a temporary increase in power demand may be met by the storage unit \n312\n, without the need to turn on a spare generator unit \n310\n.', 'The storage unit \n312\n may also be selectively operated by the power manager \n262\n to output the stored electrical energy at a selected rate to the wellsite equipment \n304\n via the line \n302\n to provide electrical power to operate the wellsite equipment \n304\n as described herein.', 'The power manager \n262\n can also receive, analyze, and/or otherwise utilize the digital drilling program \n252\n to ensure that the storage unit \n312\n is fully charged to facilitate optimal distribution and utilization of electrical energy output by the energy storage unit \n312\n and the generator units \n310\n.', 'The produced gas source \n316\n may be operable to store and/or selectively discharge or output produced gas into an air intake of the engine of each of the generator units \n310\n via a corresponding fluid conduit \n317\n.', 'The produced gas may be or comprise hydrocarbon gas (e.g., natural gas, methane, propane, butane, and/or other combustible gas entrained in the drilling fluid) extracted from the drilling fluid flowing out of the wellbore during drilling operations.', 'For example, the produced gas may be separated from the drilling fluid by liquid gas separators (e.g., liquid gas separators \n171\n shown in \nFIG.', '1\n) and/or degassers, and transferred to the produced gas source \n316\n via a fluid conduit, instead of being transferred to a flare stack to be burned.', 'The produced gas source \n316\n may be or comprise a container (e.g., a tank or piping) of the produced gas, which can be selectively discharged and injected into the engines of the generator units \n310\n.', 'The produced gas may be the sole fuel injected into the engines, or the produced gas may be injected into the engines as part of a mixture comprising air, oxygen gas, gasoline, and/or diesel fuel.', 'The produced gas source \n316\n may operate in an “on demand” mode of operation, during which the produced gas is injected into the engines while the generator units \n310\n are running at the rate the produced gas is produced from the wellbore.', 'The produced gas may also be stored within the produced gas source \n316\n to permit regulated injection of the produced gas into the engines.', 'Flow rate of the produced gas into the engines may be regulated via remotely operated fluid flow control valves communicatively connected with the central controller \n192\n.', 'The total amount of produced gas injected, and the times during which injection occurs, may be determined based on sensor data output by the exhaust sensors \n320\n and/or based on control data output by a local controller (e.g., an onboard engine controller) of each generator unit \n310\n.', 'By combining the dual feedback sources, the power manager \n262\n can optimize the performance of the generator units \n310\n based on total output power performance and/or based on exhaust emissions discharged by the generator units \n310\n measured by the exhaust sensors \n320\n.', 'The PS system \n300\n may further comprise a kW/kVAR (real power/reactive power) transducer or other sensor \n332\n electrically connected to or along the line \n302\n.', 'The sensor \n332\n may output sensor data indicative of various electrical properties (e.g., voltage, current, real power electrical, reactive electrical power, apparent electrical power, etc.) of the electrical power demand of the wellsite equipment \n304\n of the well construction system \n100\n via the line \n302\n.', 'The sensor \n332\n may be communicatively connected with the central controller \n192\n, thereby permitting the power manager \n262\n to receive and process the sensor data, and thus monitor or measure the electrical properties of the electrical power available to the wellsite equipment \n304\n based on the received sensor data and other data.', 'The power manager \n262\n may then output control data to various portions of the PS system \n300\n (e.g., the generator units \n310\n and/or the storage unit \n312\n) to control the PS system \n300\n based on the total electrical power demand, including to control generation and distribution of electrical power to the line \n302\n by the electrical power sources \n310\n, \n312\n.', 'The power manager \n262\n may control generation and distribution of electrical power to the line \n302\n by the electrical power sources \n310\n, \n312\n based on the most efficient sources of power available, taking into consideration directive to reduce total fuel consumption, equipment wear and tear, and emissions into the local environment.\n \nFIG.', '4\n is a schematic view of at least a portion of an example implementation of a processing device \n400\n (or system) according to one or more aspects of the present disclosure.', 'The processing device \n400\n may be or form at least a portion of one or more equipment controllers and/or other electronic devices shown in one or more of the \nFIGS.', '1\n-\n3\n.', 'Accordingly, the following description refers to \nFIGS.', '1\n-\n4\n, collectively.', 'The processing device \n400\n may be or comprise, for example, one or more processors, controllers, special-purpose computing devices, PCs (e.g., desktop, laptop, tablet computers, etc.), personal digital assistants, smartphones, IPCs, PLCs, servers, internet appliances, and/or other types of computing devices.', 'The processing device \n400\n may be or form at least a portion of the rig control system \n200\n, including the central controller \n192\n, the local controllers \n221\n-\n228\n, and the control workstations \n197\n, \n210\n.', 'Although it is possible that the entirety of the processing device \n400\n is implemented within one device, it is also contemplated that one or more components or functions of the processing device \n400\n may be implemented across multiple devices, some or an entirety of which may be at the wellsite and/or remote from the wellsite.', 'The processing device \n400\n may comprise a processor \n412\n, such as a general-purpose programmable processor.', 'The processor \n412\n may comprise a local memory \n414\n, and may execute machine-readable and executable program code instructions \n432\n (i.e., computer program code) present in the local memory \n414\n and/or another memory device.', 'The processor \n412\n may be, comprise, or be implemented by one or more processors of various types suitable to the local application environment, and may include one or more of general-purpose computers, special-purpose computers, microprocessors, digital signal processors (DSPs), field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), and processors based on a multi-core processor architecture, as non-limiting examples.', 'Examples of the processor \n412\n include one or more INTEL microprocessors, microcontrollers from the ARM and/or PICO families of microcontrollers, embedded soft/hard processors in one or more FPGAs.', 'The processor \n412\n may execute, among other things, the program code instructions \n432\n and/or other instructions and/or programs to implement the example methods and/or operations described herein.', 'For example, the program code instructions \n432\n, when executed by the processor \n412\n of the processing device \n400\n, may cause the processor \n412\n to receive and process (e.g., compare) sensor data (e.g., sensor measurements).', 'The program code instructions \n432\n, when executed by the processor \n412\n of the processing device \n400\n, may also or instead output control data (i.e., control commands) to cause one or more portions or pieces of well construction equipment of a well construction system to perform the example methods and/or operations described herein.', 'The processor \n412\n may be in communication with a main memory \n416\n, such as may include a volatile memory \n418\n and a non-volatile memory \n420\n, perhaps via a bus \n422\n and/or other communication means.', 'The volatile memory \n418\n may be, comprise, or be implemented by random access memory (RAM), static random access memory (SRAM), synchronous dynamic random access memory (SDRAM), dynamic random access memory (DRAM), RAMBUS dynamic random access memory (RDRAM), and/or other types of random access memory devices.', 'The non-volatile memory \n420\n may be, comprise, or be implemented by read-only memory, flash memory, and/or other types of memory devices.', 'One or more memory controllers (not shown) may control access to the volatile memory \n418\n and/or non-volatile memory \n420\n.', 'The processing device \n400\n may also comprise an interface circuit \n424\n, which is in communication with the processor \n412\n, such as via the bus \n422\n.', 'The interface circuit \n424\n may be, comprise, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'The interface circuit \n424\n may comprise a graphics driver card.', 'The interface circuit \n424\n may comprise a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).', 'The processing device \n400\n may be in communication with various sensors, video cameras, actuators, processing devices, equipment controllers, and other devices of the well construction system via the interface circuit \n424\n.', 'The interface circuit \n424\n can facilitate communications between the processing device \n400\n and one or more devices by utilizing one or more communication protocols, such as an Ethernet-based network protocol (such as ProfiNET, OPC, OPC/UA, Modbus TCP/IP, EtherCAT, UDP multicast, Siemens S7 communication, or the like), a proprietary communication protocol, and/or another communication protocol.', 'One or more input devices \n426\n may also be connected to the interface circuit \n424\n.', 'The input devices \n426\n may permit rig personnel to enter the program code instructions \n432\n, which may be or comprise control data, operational parameters, operational set-points, a digital drilling program, and/or a database of well construction operations.', 'The program code instructions \n432\n may further comprise modeling or predictive routines, equations, algorithms, processes, applications, and/or other programs operable to perform example methods and/or operations described herein.', 'The input devices \n426\n may be, comprise, or be implemented by a keyboard, a mouse, a joystick, a touchscreen, a track-pad, a trackball, an isopoint, and/or a voice recognition system, among other examples.', 'One or more output devices \n428\n may also be connected to the interface circuit \n424\n.', 'The output devices \n428\n may permit for visualization or other sensory perception of various data, such as sensor data, status data, and/or other example data.', 'The output devices \n428\n may be, comprise, or be implemented by video output devices (e.g., an LCD, an LED display, a CRT display, a touchscreen, etc.), printers, and/or speakers, among other examples.', 'The one or more input devices \n426\n and the one or more output devices \n428\n connected to the interface circuit \n424\n may, at least in part, facilitate the HMIs described herein.', 'The processing device \n400\n may comprise a mass storage device \n430\n for storing data and program code instructions \n432\n.', 'The mass storage device \n430\n may be connected to the processor \n412\n, such as via the bus \n422\n.', 'The mass storage device \n430\n may be or comprise a tangible, non-transitory storage medium, such as a floppy disk drive, a hard disk drive, a compact disk (CD) drive, and/or digital versatile disk (DVD) drive, among other examples.', 'The processing device \n400\n may be communicatively connected with an external storage medium \n434\n via the interface circuit \n424\n.', 'The external storage medium \n434\n may be or comprise a removable storage medium (e.g., a CD or DVD), such as may be operable to store data and program code instructions \n432\n.', 'As described above, the program code instructions \n432\n may be stored in the mass storage device \n430\n, the main memory \n416\n, the local memory \n414\n, and/or the removable storage medium \n434\n.', 'Thus, the processing device \n400\n may be implemented in accordance with hardware (perhaps implemented in one or more chips including an integrated circuit, such as an ASIC), or may be implemented as software or firmware for execution by the processor \n412\n.', 'In the case of firmware or software, the implementation may be provided as a computer program product including a non-transitory, computer-readable medium or storage structure embodying computer program code instructions \n432\n (i.e., software or firmware) thereon for execution by the processor \n412\n.', 'The program code instructions \n432\n may include program instructions or computer program code that, when executed by the processor \n412\n, may perform and/or cause performance of example methods, processes, and/or operations described herein.', 'The present disclosure is further directed to example methods (e.g., operations and/or processes) of performing well construction operations described herein.', 'The methods may be performed by utilizing or otherwise in conjunction with at least a portion of one or more implementations of one or more instances of the apparatus shown in one or more of \nFIGS.', '1\n-\n4\n, and/or otherwise within the scope of the present disclosure.', 'The methods may be caused to be performed, at least partially, by a processing device, such as the processing device \n400\n executing program code instructions according to one or more aspects of the present disclosure.', 'Thus, the present disclosure is also directed to a non-transitory, computer-readable medium comprising computer program code that, when executed by the processing device, may cause such processing device to perform the example methods described herein.', 'The methods may also or instead be caused to be performed, at least partially, by a human operator (e.g., rig personnel) utilizing one or more instances of the apparatus shown in one or more of \nFIGS.', '1\n-\n4\n, and/or otherwise within the scope of the present disclosure.', 'The following description of example methods refer to apparatus shown in one or more of \nFIGS.', '1\n-\n4\n, however, the methods may also be performed in conjunction with implementations of apparatus other than those depicted in \nFIGS.', '1\n-\n4\n that are also within the scope of the present disclosure.', 'During well construction operations, electrical power demand changes frequently and significantly during different stages of the well construction operations.', 'For example, electrical power demand may be relatively high during actual drilling, when the top drive \n116\n rotates the drill string \n120\n and the mud pumps \n144\n are circulating drilling fluid into the wellbore \n102\n via the drill string \n120\n.', 'Such electrical power demand may increase while the total or true vertical depth of the wellbore \n102\n increases.', 'Electrical power demand may be relatively low during make-up operations, when the iron roughneck \n165\n is operating and the top drive \n116\n is not rotating the drill string \n120\n and the mud pumps \n144\n are not circulating the drilling fluid.', 'The electrical power demand may suddenly increase to relatively high levels during tripping operations, when the drawworks \n118\n lifts the drill string \n120\n upward.', 'Electrical power demand may be relatively low during break out operations, when the iron roughneck \n165\n is operating to disconnect each subsequent tubular joint and the drawworks \n118\n is not lifting the drill string \n120\n upward.', 'Electrical power demand may also progressively decrease during tripping operations while the total length of the drill string \n120\n decreases after each tubular joint is disconnected from the drill string \n120\n.', 'Electrical power demand changes significantly during transitions between actual drilling operations and make-up operations, and during transitions between tripping operations and break out operations.', 'For example, during a spudding stage of the well construction operations, electrical power demand may range between about 0.4 megawatt and about 0.6 megawatt.', 'During connection (e.g., make-up or break out) operations, electrical power demand may range between about 0.3 megawatt and about 0.7 megawatt.', 'During tripping operations, electrical power demand may range between about 0.3 megawatt and about 1.5 megawatt.', 'During actual drilling operations, electrical power demand may range between about 2.0 megawatt and about 3.0 megawatt.', 'Generally, when electrical power demand changes during the well construction operations, fuel efficiency and rate of exhaust emission discharge of the generator units also change.', 'As described above, efficiency of a generator unit increases when load on its engine increases.', 'Fuel efficiency of a generator unit may be optimal at engine loads ranging between, for example, about 50% and about 100%.', 'However, during well construction operations, generator units collectively output electrical power to match electrical power demands of the well construction equipment, regardless of efficiency.', 'Thus, during stages of well construction operations requiring relatively low levels of electrical power, the generator units may collectively operate at a low efficiency.', 'Efficiency of a generator unit is also relatively low during engine warm-up period, which may take several minutes.', 'However, during stages of well construction operations requiring a relatively high level of electrical power, one or more additional generator units may be quickly brought online (i.e., activated) to provide additional electrical power, without permitting the additional generator units to properly warm up.', 'While operating at low efficiency or before a proper warm-up, generator units discharge exhaust emissions and unburnt fuel at a relatively higher rate.', 'Accordingly, the present disclosure is directed to methods for monitoring and controlling collective operations of the electrical power sources \n310\n, \n312\n of the PS system \n300\n at the wellsite \n104\n to optimize collective operation of such electrical power sources \n310\n, \n312\n to optimize well construction operations at the wellsite \n104\n.', 'Operations of the PS system \n300\n may be managed (i.e., controlled) automatically by the power manager \n262\n (and the control process \n250\n) of the central controller \n192\n to provide electrical power to the wellsite equipment \n304\n to perform the well construction operations, while increasing efficiency of the PS system \n300\n, reducing use of nonrenewable energy sources (e.g., diesel fuel, natural gas, and/or other fossil fuels), reducing rate of discharge of exhaust emissions, and reducing operating and maintenance costs.', 'The power manager \n262\n may be operable to automatically monitor and control collective operations of the electrical power sources \n310\n, \n312\n and the produced gas source \n316\n based on the digital drilling program \n252\n comprising information indicative of planned well construction operations uploaded or saved to the central controller \n192\n.', 'The digital drilling program \n252\n may comprise an equipment operational plan indicative of upcoming planned well construction operations to be performed by the wellsite equipment \n304\n.', 'The digital drilling program \n252\n may also comprise an electrical power plan comprising information indicative of electrical power demand (i.e., requirements) for performing each planned well construction operation.', 'The electrical power plan may also comprise information indicative of electrical power output (i.e., supply) capacity of each power source of the PS system \n300\n.', 'The power manager \n262\n may be operable to automatically monitor and control the collective operations of the electrical power sources \n310\n, \n312\n and the produced gas source \n316\n based further on the actual (e.g., measured) level of electrical power demand (i.e., load demand) of the wellsite equipment \n304\n and/or the actual (e.g., measured) level of electrical power output capacity of the electrical power sources \n310\n, \n312\n that is available to the wellsite equipment \n304\n.', 'Thus, the power manager \n262\n may be operable to monitor and control operations (e.g., start/stop and engine load percentage) of the generator units \n310\n based on the actual electrical power demand (i.e., load demand) of the wellsite equipment \n304\n and the actual electrical power output capacity that is available from the electrical power sources \n310\n, \n312\n.', 'The power manager \n262\n may be further operable to monitor and control operations of the electrical power sources \n310\n, \n312\n and the produced gas source \n316\n based further on detected abnormal events at, and/or operational states of, the well construction system \n100\n.', 'The power manager \n262\n may be aware of times and levels of electrical power demand and/or output capacity for each well construction operation before each such operation begins, such as based on the digital drilling program \n252\n.', 'The power manager \n262\n may automatically manage operations of the PS system \n300\n, based on the digital drilling program \n252\n, to cause the PS system \n300\n to provide electrical power to the wellsite equipment \n304\n to perform the well construction operations, while increasing efficiency of the PS system \n300\n, reducing use of nonrenewable energy sources (e.g., diesel fuel, natural gas, and/or other fossil fuels), reducing rate of discharge of exhaust emissions, and reducing operating and maintenance costs.', 'For example, during times (e.g., stages or periods) of lower peak electrical power demand (e.g., below about 1.0 megawatt) during which the well construction operations require relatively low levels of electrical power, the power manager \n262\n may turn off one or more of the generator units \n310\n, thereby causing the remaining generator units \n310\n to increase their electrical power output to meet the electrical power demand and thus operate at higher efficiency.', 'During times of lower average electrical power demand of the wellsite equipment \n304\n, the power manager \n262\n may also or instead maintain each generator unit \n310\n as operational or turn off a lesser number of the generator units \n310\n while simultaneously establishing an electrical connection between one or more of the operating generator units \n310\n and the storage unit \n312\n to charge the storage unit \n312\n while the generator units \n310\n continue to provide electrical power to the wellsite equipment \n304\n.', 'Also, during a period when some planned operations may cause the power demand to temporarily exceed the existing available power, the power manager \n262\n may adjust the planned operation parameters to reduce the power demand, thus avoiding the need to bring on another generator unit \n310\n online, thereby reducing wear and tear on the generator unit \n310\n.', 'The power manager \n262\n may be operable to turn on or turn off one or more of the generator units \n310\n and/or charge the storage unit \n312\n based on the equipment operational plan contained in the digital drilling program \n252\n.', 'For example, during times of lower average electrical power demand, the power manager \n262\n may cause one or more of the generator units \n310\n to output electrical power, and may cause the storage unit \n312\n to receive and store the electrical power.', 'Charging of the storage unit \n312\n increases the load on each operating generator unit \n310\n, thereby causing each operating generator unit \n310\n to operate at a high efficiency.', 'Operating each generator unit \n310\n at higher efficiency reduces the amount of fuel consumed by each generator unit \n310\n per unit of electrical power produced.', 'If the storage unit \n312\n becomes charged to a predetermined level (e.g., between about 65% and about 100%) before the time of lower average electrical power demand of the wellsite equipment \n304\n is over, then the power manager \n262\n may turn off one or more of the generator units \n310\n, such as may permit the remaining operating generator units \n310\n to continue to operate at high efficiency.', 'However, if the storage unit \n312\n becomes charged to a predetermined level while the average electrical power demand of the wellsite equipment \n304\n is relatively low (e.g., below about 400 kilowatts), then the power manager \n262\n may turn off additional generator units \n310\n and cause the storage unit \n312\n to supply electrical power to the wellsite equipment \n304\n.', 'For example, during drill string tripping operations, the average electrical power demand may be about 460 kilowatts and the peak intermittent electrical power demand may be about 1.5 megawatts.', 'During such drill string tripping operations, the power manager \n262\n may operate the storage unit \n312\n and just one generator unit \n310\n capable of generating about 1.0 megawatt to collectively supply electrical power to the wellsite equipment \n304\n (e.g., the drawworks \n118\n) to facilitate the drill string tripping operations.', 'For example, the power manager \n262\n may cause the generator unit \n310\n and the storage unit \n312\n to collectively supply electrical power to the wellsite equipment \n304\n when the drill string \n120\n is being lifted.', 'However, during break out operations, the power manager \n262\n may cause some of the electrical power from the generator unit \n310\n to supply electrical power to other wellsite equipment \n304\n (e.g., the iron roughneck \n165\n and other auxiliary devices), and may cause some of the electrical power to be stored by the storage unit \n312\n, thereby retaining a high load on the generator unit \n310\n while continually charging and discharging the storage unit \n312\n.', 'The power manager \n262\n may turn on one or more of the generator units \n310\n when the storage unit \n312\n becomes discharged or when the average electrical power demand of the wellsite equipment \n304\n increases.', 'Such operations of the generator units \n310\n and the storage unit \n312\n may be caused by the power manager \n262\n based on the digital drilling program \n252\n, as well as the state of the storage unit \n312\n.', 'The power manager \n262\n may be further operable to optimize an electrical power limit process (i.e., anti-blackout process).', 'For example, the power manager \n262\n may be operable to change or otherwise control operation of the PS system \n300\n before the electrical power demand of the wellsite equipment \n304\n exceeds available power from the electrical power sources \n310\n, \n312\n.', 'Such operation may prevent overload of the line \n302\n or other electrical circuitry of the well construction system \n100\n, and thus prevent an electrical power blackout.', 'Hence, when the power manager \n262\n determines, based on the digital drilling program \n252\n, that a planned well construction operation associated with a lower average or intermittent power demand will be occurring in the near future, then the power manager \n262\n may turn off a generator unit \n310\n or start charging the storage unit \n312\n to increase load on the generator units \n310\n at substantially the same time as the period of lower power demand starts, because such time is indicated in the digital drilling program \n252\n.', 'Conversely, when the power manager \n262\n determines that a planned well construction operation associated with a higher average or intermittent power demand will be occurring in the near future, and if the power manager \n262\n determines that the available storage energy will not be able to meet such demand, the power manager \n262\n may then turn on a generator unit \n310\n a predetermined amount of time (e.g., a few minutes) before the period of higher power demand starts, permitting the generator unit \n310\n to properly warm-up.', 'The starting time of the period of higher power demand is known because such time is indicated in the digital drilling program \n252\n.', 'Furthermore, when the power manager \n262\n determines that a period of higher average or intermittent power demand is about to start in the near future, then the power manager \n262\n may cause the storage unit \n312\n to stop charging and output electrical power to the line \n302\n at substantially the same time that the period of higher power demand starts.', 'Additionally, when the power manager \n262\n determines that a time period of intermittent higher power demand, but relatively low average power demand (e.g., the drill string tripping operations), will be occurring in the near future, the power manager \n262\n may cause the storage unit \n312\n to store electrical power to meet such electrical power demand.', 'For example, the power manager \n262\n may cause the storage unit \n312\n to increase the electrical load of presently operating generator units \n310\n, and/or the power manager may turn on an additional generator unit \n310\n, whereby electrical power generated in excess of present electrical power demand can be stored by the storage unit \n312\n for use during a time period of intermittent high power demand.', 'When the high power demand period is over, the power manager \n262\n may operate or utilize the energy storage unit \n312\n as a load to help maintain a more steady-state power load demand on the generator units \n310\n.', 'With sufficient power storage capacity of the storage unit \n312\n, intermittent higher power demand over an operational period may be fully satisfied with the combination of the storage unit \n312\n and a small number of generator units \n310\n running, without the need to bring additional generator units \n310\n online.', 'The power manager \n262\n may also or instead cause the storage unit \n312\n output more electrical power to the line \n302\n when the generator units \n310\n are about to experience and/or are experiencing a high transient load (i.e., heavy block load or unload) based on the digital drilling program \n252\n.', 'A high transient load can cause the engine of the generator unit \n310\n to significantly increase power output to accelerate the electric generator of the generator unit \n310\n to ramp up electrical power output, such as based on sensor data from the transducer \n332\n.', 'During such high transient load, fuel is injected into the engine and burned at relatively high rates, resulting in relatively high output rates of exhaust emissions and unburnt fuel.', 'During such high transient load, the engine and various other mechanical components (e.g., gears, shafts, belts, etc.) of a generator unit \n310\n experience high rate of wear caused by high levels and/or sudden changes in torque, backlash, and impacts experienced during high rates of acceleration of the engine.', 'High rates of engine acceleration can also result in overshoot of engine speed and electrical power output, requiring the engine to slow down to a steady-state speed associated with the intended electrical power output, which causes further engine wear and decrease in efficiency.', 'Likewise, during high transient unloading of the generator unit \n310\n, the engine power output is suddenly decreased (e.g., by reducing fuel flow) to decelerate the engine, thereby permitting the speed of the generator unit \n310\n to decrease.', 'Such repetitive heavy loading and unloading of the generator units \n310\n causes high rates of mechanical wear to the generator units \n310\n.', 'Therefore, during a high transient load, the power manager \n262\n may cause the storage unit \n312\n to output more electrical power to the line \n302\n, such that the generator units \n310\n experience a gradual increase in load (i.e., a soft load).', 'The power manager \n262\n may cause the storage unit \n312\n to output more electrical power to the line \n302\n before or substantially at the same time that the generator units \n310\n are experiencing the high transient load, based on the digital drilling program \n252\n.', 'Outputting more electrical power into the line \n302\n by the storage unit \n312\n reduces the rate of load increase (i.e., soft-loading) to the generator units \n310\n, causing the generator units \n310\n to ramp up output of electrical power slowly, thereby burning less fuel and reducing output rates of exhaust emissions and unburnt fuel.', 'Soft-loading the generator units \n310\n prevents or inhibits high acceleration rates and overshooting of speed and electrical power production, thereby reducing rates of mechanical wear of the generator units \n310\n.', 'An example method according to one or more aspects of the present disclosure may comprise generating or otherwise displaying one or more display screens on a video output device of the control workstations \n190\n, \n210\n for viewing by rig personnel, thus permitting the rig personnel to monitor, configure, and control well construction equipment of the well construction system \n100\n.', 'FIGS.', '5\n and \n6\n are example implementations of display screens \n502\n, \n504\n, respectively, generated by a processing device, such as the central controller \n192\n shown in \nFIGS.', '1\n-\n3\n or the processing device \n400\n shown in \nFIG.', '4\n, based on sensor data output by the sensors \n231\n-\n238\n and processes executed by the central controller \n192\n, including the power manager \n262\n.', 'The display screens \n502\n, \n504\n may be displayed on a video output device of one or more of the workstations \n190\n, \n210\n for viewing by the rig personnel, thereby permitting the rig personnel to monitor, configure, and control the wellsite equipment \n304\n and/or the PS system \n300\n.', 'Accordingly, the following description refers to \nFIGS.', '1\n-\n6\n, collectively.', 'The display screen \n502\n may show or comprise a graph \n520\n indicative of at least a portion of an electrical power plan of a digital drilling program \n252\n for performing the well construction operations to construct a well \n102\n.', 'The graph \n520\n may indicate electrical power (e.g., in megawatts) along the vertical axis, and time along the horizontal axis.', 'The display screen \n502\n may also show or comprise a timeline \n522\n (e.g., text, windows, visual indicators, etc.)', 'indicative of at least a portion of an equipment operational plan of the digital drilling program \n252\n.', 'The timeline \n522\n may comprise text and/or other indicators describing or otherwise identifying successive planned well construction operations \n523\n (e.g., operational sequences, tasks, mechanical actions, etc.).', 'The graph \n520\n and the timeline \n522\n may be generated or otherwise output by a processing device, such as the processing device \n400\n, based on information output by the power manager \n262\n and/or other processes of the central controller \n192\n.', 'The electrical power plan shown on the graph \n520\n may comprise a profile (or curve) \n524\n indicative of a level or quantity of planned (e.g., projected, estimated, expected, etc.)', 'electrical power demand of the wellsite equipment \n304\n to perform the planned well construction operations \n523\n to be performed by the wellsite equipment \n304\n as part of well construction operations \n523\n to construct the well \n102\n.', 'The graph \n520\n may also comprise a profile (or curve) \n526\n indicative of a level or quantity of adjusted (i.e., changed) planned electrical power demand of the wellsite equipment \n304\n to perform the planned well construction operations \n523\n to be performed by the wellsite equipment \n304\n to construct the well \n102\n.', 'The adjusted planned electrical power demand \n526\n may be or comprise the planned electrical power demand \n524\n that is adjusted by the power manager \n262\n based on changing operational parameters described below.', 'The graph \n520\n may further comprise a profile (or curve) \n528\n indicative of a level or quantity of the actual (e.g., measured) electrical power demand of the wellsite equipment \n304\n during the performance of the planned well construction operations \n523\n.', 'The actual electrical power demand \n528\n may be determined by the power manager \n262\n based on electrical power measurements output by one or more electrical sensors, such as the sensor \n332\n.', 'The electrical power plan shown on the graph \n520\n may also comprise a profile (or curve) \n532\n indicative of a maximum electrical power output capacity of the PS system \n300\n.', 'The maximum power output capacity \n532\n may be or comprise the maximum level or amount of electrical power (i.e., maximum available electrical power limit or ceiling) that the PS system \n300\n can output to the wellsite equipment \n304\n to perform the planned well construction operations \n523\n indicated in the equipment operational plan when each of the generator units \n310\n is online and the storage unit \n312\n is fully charged.', 'Although the maximum power output capacity \n532\n is shown as a straight horizontal profile, the maximum power output capacity \n532\n of the PS system \n300\n may not be constant, but may vary with time depending on the condition of the generator units \n310\n and/or the storage unit \n312\n.', 'The electrical power plan shown on the graph \n520\n may also comprise a profile (or curve) \n534\n indicative of a maximum instantaneous electrical power output capacity of the PS system \n300\n.', 'The maximum instantaneous electrical power output capacity \n534\n may be or comprise the maximum level or amount of electrical power (i.e., maximum instantaneously available electrical power limit or ceiling) that the PS system \n300\n can instantaneously output to the wellsite equipment \n304\n from the generator units \n310\n that are currently online and the storage unit \n312\n as currently charged to perform the planned well construction operations \n523\n indicated in the equipment operational plan.', 'A present time indicator \n536\n (e.g., a line or window) may be displayed along or in association with the profiles \n524\n, \n526\n, \n528\n, \n532\n, \n534\n, the timeline \n522\n, and the horizontal time axis.', 'The present time indicator \n536\n may indicate the present time with respect to the performance of the equipment operational plan and the electrical power plan of the digital drilling program \n252\n.', 'During well construction operations, the present time indicator \n536\n may move to the right on the display screen \n502\n with respect to the profiles \n524\n, \n526\n, \n528\n, \n532\n, \n534\n, the timeline \n522\n, and the horizontal time axis to indicate the progression of time.', 'The present time indicator \n536\n may instead be fixed on the display screen \n502\n and the profiles \n524\n, \n526\n, \n528\n, \n532\n, \n534\n, the timeline \n522\n, and the horizontal time axis may move (scroll) to the left with respect to the present time indicator \n536\n to indicate the progression of time.', 'The display screen \n502\n may be displayed to and analyzed by rig personnel to determine operational status of the wellsite equipment \n304\n and PS system \n300\n with respect to various parameters of electrical power (e.g., as indicated by one or more of the profiles \n524\n, \n526\n, \n528\n, \n532\n, \n534\n) that is being and will be supplied to the wellsite equipment \n304\n by the PS system \n300\n to perform the planned well construction operations \n523\n.', 'For example, each planned well construction operation \n523\n may be displayed in association with (e.g., above) a corresponding portion of the planned electrical power demand \n524\n, the adjusted planned electrical power demand \n526\n, the actual electrical power demand \n528\n, and the maximum instantaneous power output capacity \n534\n.', 'The graph \n520\n and the timeline \n522\n may collectively indicate the level of electrical power demand \n524\n, \n526\n, \n528\n of the wellsite equipment \n304\n to perform each planned well construction operation \n523\n with respect to the electrical power output capacities \n532\n, \n534\n of the wellsite equipment \n304\n.', 'The graph \n520\n and the timeline \n522\n may thus collectively indicate to rig personnel if the electrical power capacities \n532\n, \n534\n are sufficient to meet the electrical power demand \n524\n, \n526\n, \n528\n of the wellsite equipment \n304\n during performance of the planned well construction operations \n523\n.', 'The power manager \n262\n may be operable to cause the PS system \n300\n to output the electrical power to the wellsite equipment \n304\n based on the electrical power plan, such that the electrical power output by the PS system \n300\n meets the electrical power demand \n524\n, \n526\n, \n528\n of the wellsite equipment \n304\n to perform the planned well construction operations \n523\n.', 'The maximum instantaneous power output capacity \n534\n may be set to exceed the planned electrical power demand \n524\n of the wellsite equipment \n304\n by a predetermined amount \n538\n (e.g., a safety margin).', 'Thus, the display screen \n502\n may display spare electrical power capacity of the PS system \n300\n to permit the rig personnel (e.g., maintenance supervisors) to schedule, delay, or otherwise manage unplanned rig activities (e.g., maintenance activities).', 'For example, the rig personnel may compare the maximum instantaneous power output capacity \n534\n to the planned and/or actual electrical power demands \n524\n, \n528\n or compare the maximum power output capacity \n532\n to the planned and/or actual electrical power demands \n524\n, \n528\n such as to determine if sufficient excess electrical power exists or will exist to perform the unplanned rig activities.', 'The display screen \n502\n may also provide advance warning for or otherwise determine when the planned electrical power demand \n524\n will exceed one or both of the maximum power output capacities \n532\n, \n534\n.', 'As shown on the display screen \n502\n, the power manager \n262\n may cause the PS system \n300\n (e.g., the generator units \n310\n and/or the electrical energy storage \n312\n) to output an amount of electrical power that is sufficient to satisfy the planned electrical power demand \n524\n indicated in the electrical power plan of the digital drilling program \n252\n to perform the planned well construction operations \n523\n indicated in the equipment operational plan of the digital drilling program \n252\n.', 'The power manager \n262\n may cause the PS system \n300\n to supply the maximum instantaneous power output capacity \n534\n based on the electrical power plan of the digital drilling program \n252\n.', 'In other words, the power manager \n262\n can cause the PS system \n300\n to output electrical power based on the planned electrical power demand \n524\n.', 'The power manager \n262\n may also cause the PS system \n300\n to output an amount of electrical power that exceeds the planned electrical power demand \n524\n by the safety margin \n538\n.', 'For example, during the relatively low electrical power demand of the wellsite equipment \n304\n to perform “Operation 2” of the planned well construction operations \n523\n, between time \n529\n and time \n531\n, the power manager \n262\n may lower the maximum instantaneous power output capacity \n534\n to meet the planned electrical power demand \n524\n of the wellsite equipment \n304\n to perform such operation while maintaining the safety margin \n538\n.', 'Similarly, during the relatively low electrical power demand of the wellsite equipment \n304\n to perform “Operation 4” of the planned well construction operations \n523\n, between time \n527\n and time \n535\n, the power manager \n262\n may lower the maximum instantaneous power output capacity \n534\n to meet the planned electrical power demand \n524\n of the wellsite equipment \n304\n to perform such operation while maintaining the safety margin \n538\n.', 'The power manager \n262\n may decrease the maximum instantaneous power output capacity \n534\n between time \n529\n and time \n531\n and between time \n527\n and time \n535\n by turning off a generator unit \n310\n (i.e., taking a generator unit \n310\n offline) and/or', 'by charging the storage unit \n312\n.', 'However, during the relatively high electrical power demand of the wellsite equipment \n304\n to perform “Operation 3” of the planned well construction operations \n523\n, between time \n531\n and time \n527\n, the power manager \n262\n may increase the maximum instantaneous power output capacity \n534\n to meet the planned electrical power demand \n524\n of the wellsite equipment \n304\n to perform such operation while maintaining the safety margin \n538\n.', 'Similarly, during the relatively high electrical power demand of the wellsite equipment \n304\n to perform “Operation 5” of the planned well construction operations \n523\n, between time \n535\n and time \n543\n, the power manager \n262\n may increase the maximum instantaneous power output capacity \n534\n to meet the planned electrical power demand \n524\n of the wellsite equipment \n304\n to perform such operation while maintaining the safety margin \n538\n.', 'The power manager \n262\n may increase the maximum instantaneous power output capacity \n534\n between time \n531\n and time \n527\n and between time \n535\n and time \n543\n by turning on another generator unit \n310\n (i.e., taking a generator unit \n310\n online)', 'and/or', 'by discharging the storage unit \n312\n.', 'Therefore, when the power manager \n262\n determines, based on the planned electrical power demand \n524\n, that the planned well construction “Operation 4” and the planned well construction “Operation 6” associated with a lower average or intermittent planned electrical power demand \n524\n will be starting at time \n527\n and time \n543\n, respectively, then the power manager \n262\n may turn off a generator unit \n310\n or start charging the storage unit \n312\n to increase load on the generator units \n310\n at substantially the same time that such operations start.', 'The starting time \n527\n of “Operation 4” and the starting time \n543\n of “Operation 6” are indicated in the planned electrical power demand \n524\n.', 'Conversely, when the power manager \n262\n determines that the planned well construction “Operation 3” and the planned well construction “Operation 5” associated with a higher average or intermittent planned power demand \n524\n will be occurring at time \n531\n and time \n535\n, respectively, and if the power manager \n262\n determines that the maximum instantaneous power output capacity \n534\n will not be able to meet such planned power demand \n524\n, the power manager \n262\n may then turn on a generator unit \n310\n a predetermined amount of time (e.g., a few minutes) before such operations start, permitting the generator unit \n310\n to properly warm-up.', 'The starting time \n531\n of “Operation 3” and the starting time \n535\n of “Operation 5” are indicated in the planned electrical power demand \n524\n.', 'Furthermore, when the power manager \n262\n determines that the planned well construction “Operation 3” and the planned well construction “Operation 5” is about to start in the near future, then the power manager \n262\n may cause the storage unit \n312\n to stop charging and output electrical power to the line \n302\n at substantially the same time \n531\n, \n535\n that such operations start.', 'The display screen \n502\n further shows example scenarios during which the power manager \n262\n adjusts (i.e., changes) the maximum instantaneous power output capacity \n534\n of the PS system \n300\n (e.g., the generator units \n310\n and/or the electrical energy storage \n312\n) based on the actual electrical power demand \n528\n of the wellsite equipment \n304\n.', 'For example, when the actual electrical power demand \n528\n approaches or is expected to surpass (i.e., be higher than) the maximum instantaneous power output capacity \n534\n, such as at time \n531\n during the start of “Operation 3” of the planned well construction operations \n523\n, the power manager \n262\n may cause the PS system \n300\n to increase the maximum instantaneous power output capacity \n534\n, as shown at time \n533\n, to meet the actual electrical power demand \n528\n (with the safety margin \n538\n) of the wellsite equipment \n304\n and to prevent an electrical power blackout between time \n533\n and time \n527\n.', 'However, when the actual electrical power demand \n528\n is lower than the planned electrical power demand \n524\n, such as at time \n535\n during the start of “Operation 5” of the planned well construction operations \n523\n, the power manager \n262\n may cause the PS system \n300\n to decrease the maximum instantaneous power output capacity \n534\n, as shown at time \n537\n, to reduce production of unnecessary electrical power.', 'Thus, if the maximum instantaneous power output capacity \n534\n is excessive or not sufficient to satisfy the actual electrical power demand \n528\n, the power manager \n262\n can also cause the PS system \n300\n to adjust the maximum instantaneous power output capacity \n534\n based on the actual electrical power demand \n528\n.', 'The power manager \n262\n may also be operable compare the actual electrical power demand \n528\n to the planned electrical power demand \n524\n and, based on the comparison, adjust the planned electrical power demand \n524\n, resulting in the adjusted planned electrical power demand \n526\n.', 'The power manager \n262\n may then cause the PS system \n300\n adjust the maximum instantaneous power output capacity \n534\n based on the adjusted planned electrical power demand \n526\n.', 'For example, when the actual electrical power demand \n528\n is higher than the planned electrical power demand \n524\n, such as at time \n531\n during the start of “Operation 3” of the planned well construction operations \n523\n, the power manager \n262\n may cause the PS system \n300\n to increase the planned electrical power demand \n524\n to the adjusted planned electrical power demand \n526\n, such as at time \n533\n.', 'The power manager \n262\n may then cause the PS system \n300\n to increase the maximum instantaneous power output capacity \n534\n, such as shown at time \n533\n, to meet the adjusted planned electrical power demand \n526\n (with the safety margin \n538\n) of the wellsite equipment \n304\n to perform “Operation 3” between time \n533\n and time \n527\n.', 'However, when the actual electrical power demand \n528\n is lower than the planned electrical power demand \n524\n, such as at time \n535\n during the start of “Operation 5” of the planned well construction operations \n523\n, the power manager \n262\n may cause the PS system \n300\n to decrease the planned electrical power demand \n524\n to the adjusted planned electrical power demand \n526\n, such as at time \n537\n.', 'The power manager \n262\n may then cause the PS system \n300\n to decrease the maximum instantaneous power output capacity \n534\n, such as shown at time \n537\n, to meet the adjusted planned electrical power demand \n526\n (with the safety margin \n538\n) of the wellsite equipment \n304\n to perform “Operation 5” between time \n537\n and time \n543\n.', 'The power manager \n262\n and/or another process of the central controller \n192\n may also be operable to the record the actual electrical power demand \n528\n of the well site equipment \n304\n during performance of the planned well construction operations \n523\n to a database (e.g., the memory device \n430\n of the processing device \n400\n) containing other actual electrical power demands from other wells and/other portions of the present well \n102\n.', 'The power manager \n262\n may be further operable to access the database and compare the recorded actual electrical power demands in the database to the present actual electrical power demand \n528\n.', 'Based on the comparison, the power manager \n262\n may adjust the planned electrical power demand \n524\n of the electrical power plan to the adjusted planned electrical power demand \n526\n if the power manager \n262\n detects a difference between the recorded actual electrical power demands and the present actual electrical power demand \n528\n.', 'If the recorded actual electrical power demands in the database is different from the present actual electrical power demand \n528\n, the planned electrical power demand \n524\n may have been miscalculated and/or there is a likelihood that the actual electrical power demand \n528\n will soon change and become similar to one or more of the recorded actual electrical power demands.', 'The power manager \n262\n may then cause the PS system \n300\n to output the electrical power to the wellsite equipment \n304\n based on the adjusted planned electrical power demand \n526\n, such as during “Operation 3” and “Operation 5” of the planned well construction operations \n523\n.', 'The power manager \n262\n may be further operable to adjust operation of the wellsite equipment \n304\n (directly or indirectly via the control process \n250\n) and/or adjust the equipment operational plan of the digital drilling program \n252\n to perform the planned well construction operations \n523\n based on the actual electrical power demand \n528\n of the well site equipment \n304\n and the maximum instantaneous power output capacity \n534\n of the PS system \n300\n.', 'For example, the power manager \n262\n may be operable to adjust operation of the wellsite equipment \n304\n and/or adjust the equipment operational plan of the digital drilling program \n252\n when the actual electrical power demand \n528\n of the wellsite equipment \n304\n is close to or about to exceed the maximum instantaneous power output capacity \n534\n of the PS system \n300\n (e.g., the electric generator units \n310\n and/or the electrical storage unit \n312\n).', 'Such operation of the power manager \n262\n may prevent overload of the line \n302\n or other electrical circuitry of the well construction system \n100\n and thus prevent an electrical power blackout.', 'Such scenario may happen when an unplanned event takes place at the wellsite.', 'An unplanned event may include, for example, an unforeseen drilling event requiring additional flow rate of drilling fluid or fast withdraw of the drill string \n120\n from the wellbore \n102\n.', 'An unplanned event may also include an unforeseen breakdown in one or more of the generator units \n310\n and/or the storage unit \n312\n, requiring such piece of equipment to be taken offline for maintenance.', 'The power manager \n262\n may adjust the equipment operational plan of the digital drilling program \n252\n and/or adjust the operation of the wellsite equipment \n304\n to lower the actual electrical power demand \n528\n, such as by changing a speed and/or acceleration of one or more components of the wellsite equipment \n304\n to perform the planned well construction operations \n523\n, by changing pressure generated by one or more components of the wellsite equipment \n304\n to perform the planned well construction operations \n523\n, and/or by changing a flow rate output by one or more components of the wellsite equipment \n304\n to perform the planned well construction operations \n523\n.', 'For example, the speed, the acceleration, the pressure, and/or the flow rate of the wellsite equipment \n304\n component(s) may be decreased to decrease the actual electrical power demand \n528\n of the well site equipment \n304\n.', 'The power manager \n262\n may slow down or otherwise adjust operations of selected pieces of the wellsite equipment \n304\n, such as the drawworks \n118\n, the top drive \n116\n, the pumps \n144\n, and various pipe handling equipment collectively operable to move tubulars during the well construction operations, in order to reduce the actual power demand.', 'The power manager \n262\n may also or instead delay or turn off predetermined operations of the well construction system \n100\n.', 'Thus, the power manager \n262\n may update, adjust, or delay the planned well construction operations \n523\n based on a difference between the actual electrical power demand \n528\n and the maximum instantaneous power output capacity \n534\n, such as to minimize the number of start/stop operations of the generator units \n310\n and/or to minimize the chance of electrical power blackout.', 'Thus, if the actual electrical power demand \n528\n is close to the maximum instantaneous power output capacity \n534\n, and the digital drilling program \n252\n calls for tripping out at a certain speed which could cause a blackout, the power manager \n262\n may adjust the tripping speed to avoid an electrical blackout.', 'The power manager \n262\n may be operable to adjust the operation of the wellsite equipment \n304\n during the performance of the planned well construction operations \n523\n based on the actual electrical power demand \n528\n of the well site equipment \n304\n and the maximum instantaneous power output capacity \n534\n of the PS system \n300\n.', 'For example, during the relatively high actual electrical power demand \n528\n of the wellsite equipment \n304\n to perform “Operation 3” of the planned well construction operations \n523\n, the power manager \n262\n may determine at time \n533\n that the maximum instantaneous power output capacity \n534\n is close to or not sufficient to meet the actual electrical power demand \n528\n of the wellsite equipment \n304\n.', 'The power manager \n262\n may therefore cause the wellsite equipment \n304\n to decrease its operational speed between time \n533\n and time \n527\n to decrease the actual electrical power demand \n528\n of the wellsite equipment \n304\n, and thereby permit the wellsite equipment \n304\n to perform the rest of “Operation 3” without causing an electrical blackout.', 'As described above, the power manager \n262\n may also adjust the planned electrical power demand \n524\n and cause the PS system \n300\n to simultaneously increasing the maximum instantaneous power output capacity \n534\n between time \n533\n and time \n527\n.', 'The power manager \n262\n may also be operable to adjust the equipment operational plan of the digital drilling program \n252\n during the performance of the planned well construction operations \n523\n based on the maximum instantaneous power output capacity \n534\n and the actual electrical power demand \n528\n of the wellsite equipment \n304\n.', 'The power manager \n262\n may compare the maximum instantaneous power output capacity \n534\n to the actual electrical power demand \n528\n and, based on the comparison, adjust the equipment operational plan of the digital drilling program \n252\n to lower the actual electrical power demand \n528\n of the wellsite equipment \n304\n.', 'For example, during the relatively high electrical power demand of the wellsite equipment \n304\n to perform “Operation 3” of the planned well construction operations \n523\n, the power manager \n262\n may determine at time \n533\n that the maximum instantaneous power output capacity \n534\n is close to or not sufficient to meet the actual electrical power demand \n528\n of the wellsite equipment \n304\n.', 'The power manager \n262\n may therefore cause the wellsite equipment \n304\n to adjust the equipment operational plan for the well site equipment \n304\n between time \n533\n and time \n527\n.', 'The adjusted equipment operational plan may cause a corresponding decrease of the actual electrical power demand \n528\n of the wellsite equipment \n304\n and thereby permit the wellsite equipment \n304\n to perform “Operation 3” without causing an electrical blackout.', 'The power manager \n262\n may be operable to delay performance of a planned well construction operation \n523\n based on the planned electrical power demand \n524\n of the wellsite equipment \n304\n and the maximum instantaneous power output capacity \n534\n of the PS system \n300\n.', 'For example, the power manager \n262\n may determine at time \n539\n that the maximum instantaneous power output capacity \n534\n is close to or not sufficient to meet the relatively high planned electrical power demand \n524\n of the wellsite equipment \n304\n to perform “Operation 7” of the planned well construction operations \n523\n.', 'The power manager \n262\n may then adjust the equipment operational plan and/or the electrical power plan of the digital drilling program \n252\n to delay the operation.', 'The power manager \n262\n may delay the start of “Operation 7” by the wellsite equipment \n304\n from time \n539\n until time \n541\n and adjust the electrical power plan by changing the planned electrical power demand \n524\n to the adjusted planned electrical power demand \n526\n, thereby delaying the supply of electrical power to perform “Operation 7” from time \n539\n to time \n541\n.', 'The time delay may permit the PS system \n300\n to increase the maximum instantaneous power output capacity \n534\n to a level that meets the relatively high electrical power demand \n524\n, \n526\n to perform “Operation 7.”', 'For example, the time delay may permit the power manager \n262\n to bring additional generator units \n310\n online (e.g., to warm up) and/or to permit the storage unit \n312\n to switch from a charging mode to a discharging mode.', 'The power manager \n262\n may be further operable to determine (e.g., calculate or output) a new electrical power plan indicative of a new planned electrical power demand based on the actual electrical power demand \n528\n.', 'The new electrical power plan may be a part of the digital drilling program for constructing another portion of the same (i.e., present) well, or the new electrical power plan may be a part of another digital drilling program for constructing another well (e.g., an offset well) that is at least partially substantially similar to the present well.', 'For example, the power manager \n262\n may be operable to the record to the database the actual electrical power demand \n528\n of the wellsite equipment \n304\n during performance of the planned well construction operations \n523\n for a portion of a well or the entire well.', 'After the actual electrical power demand \n528\n is recorded, determine the new electrical power plan indicative of the new planned electrical power demand of the wellsite equipment \n304\n to perform a plurality of new planned well construction operations based on the recorded actual electrical power demand \n528\n.', 'Such new planned electrical power demand may be determined for new planned well construction operations that are substantially similar to the planned well construction operations \n523\n and/or for a well or a portion of a well that is substantially similar to the well associated with the recorded actual electrical power demand \n528\n.', 'Thus, the power manager \n262\n may learn based on the recorded actual electrical power demand \n528\n (i.e., electrical power used) to determine the new planned electrical power demand indicated in the new digital drilling program.', 'The power manager \n262\n may then calibrate and update the new planned electrical power demand in the same or another digital drilling program.', 'The display screen \n504\n comprises a graph \n550\n showing at least a portion of an example new electrical power plan of a digital drilling program for performing well construction operations to construct another portion of the same well or a different well by the wellsite equipment \n304\n.', 'The graph \n550\n may indicate electrical power (e.g., in megawatts) along the vertical axis, and time along the horizontal axis.', 'The display screen \n504\n may also show or comprise a timeline \n552\n (e.g., text, windows, visual indicators) indicative of at least a portion of a new equipment operational plan.', 'The timeline \n552\n may comprise text or other indicators describing or otherwise identifying successive planned well construction operation \n556\n (e.g., an operational sequence, a task, a mechanical action, etc.).', 'The planned well construction operations \n556\n (e.g., operational sequences or tasks) may be substantially similar to the planned well construction operations \n523\n.', 'The graph \n550\n and the timeline \n552\n may be generated or otherwise output by a processing device, such as the processing device \n400\n, based on information output by the power manager \n262\n and/or other processes of the central controller \n192\n.', 'The new electrical power plan shown on the graph \n550\n may comprise a new profile \n554\n (or curve) indicative of level or quantity of planned (e.g., projected, estimated, expected, etc.)', 'electrical power demand of the wellsite equipment \n304\n to perform the new planned well construction operations \n556\n.', 'The new planned electrical power demand \n554\n may be similar to the planned electrical power demand \n524\n.', 'However, the new planned electrical power demand \n554\n reflects the actual electrical power demand \n528\n measured during the performance of the planned well construction operations \n523\n shown on the display screen \n502\n before the power manager \n262\n adjusted the planned electrical power demand \n524\n, as described above.', 'The similarities between the actual electrical power demand \n528\n and the new planned electrical power demand \n554\n may more closely reflect the actual electrical power demand associated with performing the new planned well construction operations \n556\n.', 'Thus, recorded actual electrical power demands may be implemented or otherwise considered when the power manager \n262\n determines (e.g., calculates or outputs) a new planned electrical power demand.', 'The power manager \n262\n may be operable to monitor and control operations of the generator units \n310\n further based on sensor data output by the exhaust sensors \n320\n indicative of properties of the exhaust emissions output by the engine of each generator unit \n310\n.', 'For example, if the power manager \n262\n determines that higher quantities or proportions of particulate material and/or gases are present in the engine exhaust, the power manager \n262\n may turn off the generator unit \n310\n or increase load on the generator unit \n310\n via the storage unit \n312\n.', 'The power manager \n262\n may be operable to monitor operations of the generator units \n310\n and control (e.g., adjust) operation of the produced gas source \n316\n to optimize operations of the generator units \n310\n by selectively injecting the produced gas into the engines of the generator units \n310\n.', 'For example, the power manager \n262\n may cause the produced gas source \n316\n to inject the produced gas into the engines of the generator units \n310\n instead of other fuel (e.g., gasoline or diesel fuel), such as when sufficient amount of the produced gas is available and/or to conserve the other fuel.', 'The power manager \n262\n may instead cause the produced gas source \n316\n to inject the produced gas into the engines of the generator units \n310\n on a limited basis, such as when produced gas substantially improves efficiency and/or reduces exhaust emissions.', 'The power manager \n262\n may monitor power output by the generator units \n310\n and change the flow rate of the produced gas into the engines based on the measured power output and/or fuel efficiency.', 'The power manager \n262\n may maintain the flow rate of the produced gas at a level resulting in the highest or otherwise optimal power output (e.g., when more engine torque is needed) and/or at a level resulting in the highest or otherwise optimal fuel efficiency (e.g., when steady state electrical power output is reached).', 'The power manager \n262\n may also or instead cause the produced gas source \n316\n to inject the produced gas into the engine of one or more of the generator units \n310\n that are about to experience a high transient load based on the equipment operational plan contained in the digital drilling program \n252\n.', 'Injecting produced gas into the engine that is experiencing a high transient load improves burning of the fuel and/or reduces flow rate of fuel into the engine, and thus reduces output rates of exhaust emissions and unburnt fuel.', 'The power manager \n262\n may be operable to monitor and control operation of the produced gas source \n316\n further based on sensor data output by the exhaust sensors \n320\n.', 'For example, the power manager \n262\n may monitor levels of exhaust emissions within the exhaust of the engines and change the flow rate of produced gas into the engines based on the measured levels of exhaust emissions.', 'When the power manager \n262\n determines that higher quantities or proportions of exhaust emissions are present in the engine exhaust, the power manager \n262\n may increase the flow rate of produced gas into the engines to improve burning of the fuel and thus reduce output of the exhaust emissions.', 'The power manager \n262\n may maintain the flow rate of produced gas at a level resulting in minimal output of the exhaust emissions.', 'Some of the electric motors of the wellsite equipment \n304\n electrically powered by the PS system \n300\n may be or comprise electric motor-generators configured to output electrical power when mechanically driven or actuated by corresponding loads, such as when the electric motor-generators used to slow down or stop movement of the corresponding loads.', 'For example, the electric motor driving the drum of the drawworks \n118\n may be or comprise an electric motor-generator configured to output electrical power when the electric motor-generator is used to slow down or stop downward movement of the drill string \n120\n, such as during drill string tripping operations.', 'Accordingly, the power manager \n262\n may be further operable to cause the storage unit \n312\n to store the electrical power output by the electric motor-generator of the drawworks \n118\n via the electrical line \n302\n during predetermined periods of well construction operations \n523\n (e.g., braking operations) when the electric motor-generator is used to slow down or stop downward movement of the drill string \n120\n.', 'The power manager \n262\n may also or instead cause the storage unit \n312\n not to store the electrical power output by the electric motor-generator of the drawworks \n118\n, but cause such electrical power to be used by other wellsite equipment electrically connected to the electrical line \n302\n.', 'In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces an apparatus comprising a well construction system comprising: (A) well construction equipment operable to construct a well at a wellsite; (B) a power supply system operable to output electrical power to the well construction equipment to facilitate operation of the well construction equipment; and (C) a control system for controlling the well construction system, wherein the control system comprises a processor and a memory storing a computer program code, and wherein the control system is operable to: (i) store a digital drilling program comprising: (a) an equipment operational plan indicative of planned well construction operations to be performed by the well construction equipment to construct the well; and (b) an electrical power plan indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations; and (ii) cause the well construction equipment to perform the planned well construction operations indicated in the equipment operational plan.', 'The control system may be further operable to cause the power supply system to output the electrical power to the well construction equipment based on the electrical power plan, and the electrical power output by the power supply system may meet the planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The electrical power output by the power supply system may exceed the planned electrical power demand of the well construction equipment by a predetermined amount.', 'The electrical power output by the power supply system may also minimize discharge rate of exhaust emissions.', 'The electrical power output by the power supply system may also minimize consumption rate of fuel.', 'The power supply system may comprise a plurality of electric generator units and an electrical energy storage unit, and the control system may be further operable to: cause the electrical energy storage unit to store the electrical power output by the electric generator units; and cause the electric generator units and the electrical energy storage unit to output the electrical power to the well construction equipment based on the electrical power plan, wherein the electrical power output by the electric generator units and the electrical energy storage unit may meet the planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The control system may be operable to: determine an actual electrical power demand of the well construction equipment during the performance of the planned well construction operations; compare the actual electrical power demand to the planned electrical power demand; adjust the planned electrical power demand based on the comparison; and cause the power supply system to output the electrical power to the well construction equipment based on the adjusted planned electrical power demand, wherein the electrical power output by the power supply system may meet the adjusted planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The control system may be operable to: determine an electrical power output capacity indicative of electrical power that the power supply system can output to the well construction equipment to perform the planned well construction operations; compare the electrical power output capacity to the planned electrical power demand; and based on the comparison, adjust the planned well construction operations to adjust the planned electrical power demand.', 'Adjusting the planned well construction operations to adjust the planned electrical power demand may comprise adjusting at least one of a speed of, an acceleration of, a pressure generated by, and a flow rate output by a component of the well construction equipment to perform the planned well construction operations.', 'Adjusting the planned well construction operations to adjust the planned electrical power demand may comprise delaying a start of one or more of the planned well construction operations.', 'The control system may be operable to: (A) determine an electrical power output capacity indicative of electrical power that the power supply system can output to the well construction equipment to perform the planned well construction operations; and (B) display on a video output device for viewing by personnel: (i) the electrical power output capacity; and (ii) the planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The present disclosure also introduces an apparatus comprising a well construction system comprising: well construction equipment operable to construct a well at a wellsite; a power supply system operable to output electrical power to the well construction equipment to facilitate operation of the well construction equipment; and a control system for controlling the well construction system, wherein the control system comprises a processor and a memory storing a computer program code.', 'The control system is operable to: (A) store a digital drilling program comprising: (i) an equipment operational plan indicative of planned well construction operations to be performed by the well construction equipment to construct the well; and (ii) an electrical power plan indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations; (B) cause the well construction equipment to perform the planned well construction operations indicated in the equipment operational plan; (C) cause the power supply system to output the electrical power to the well construction equipment based on the electrical power plan, wherein the electrical power output by the power supply system meets the planned electrical power demand of the well construction equipment to perform the planned well construction operations; (D) determine an electrical power output capacity indicative of electrical power that the power supply system can output to the well construction equipment to perform the planned well construction operations; (E) compare the electrical power output capacity to the planned electrical power demand; and (F) based on the comparison, adjust the planned well construction operations to adjust the planned electrical power demand.', 'The electrical power output by the power supply system may also minimize discharge rate of exhaust emissions.', 'The electrical power output by the power supply system may also minimize consumption rate of fuel.', 'The control system may be operable to: determine an actual electrical power demand of the well construction equipment during the performance of the planned well construction operations; compare the actual electrical power demand to the planned electrical power demand; based on the comparison, adjust the planned electrical power demand of the electrical power plan; and cause the power supply system to output the electrical power to the well construction equipment based on the adjusted planned electrical power demand, wherein the electrical power output by the power supply system may meet the adjusted planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The present disclosure also introduces a method comprising commencing operation of a control system of a well construction system, wherein the well construction system is located at a wellsite and comprises well construction equipment and a power supply system, and wherein the operating control system: (A) stores a digital drilling program comprising: (i) an equipment operational plan indicative of planned well construction operations to be performed by the well construction equipment to construct a well at the wellsite; and (ii) an electrical power plan indicative of a planned electrical power demand of the well construction equipment to perform the planned well construction operations; (B) causes the well construction equipment to perform the planned well construction operations indicated in the equipment operational plan; and (C) causes the power supply system to output the electrical power to the well construction equipment based on the electrical power plan, wherein the electrical power output by the power supply system meets the planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The operating control system may: determine an actual electrical power demand of the well construction equipment during the performance of the planned well construction operations; compare the actual electrical power demand to the planned electrical power demand; adjust the planned electrical power demand of the electrical power plan based on the comparison; and cause the power supply system to output the electrical power to the well construction equipment based on the adjusted planned electrical power demand, wherein the electrical power output by the power supply system may meet the adjusted planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The operating control system may: determine an electrical power output capacity indicative of electrical power that the power supply system can output to the well construction equipment to perform the planned well construction operations; compare the electrical power output capacity to the planned electrical power demand; and based on the comparison, adjust the planned well construction operations to adjust the planned electrical power demand.', 'Adjusting the planned well construction operations to adjust the planned electrical power demand may comprise delaying a start of one or more of the planned well construction operations.', 'The operating control system may: (A) determine an electrical power output capacity indicative of electrical power that the power supply system can output to the well construction equipment to perform the planned well construction operations; and display on a video output device for viewing by personnel: (i) the electrical power output capacity; and (ii) the planned electrical power demand of the well construction equipment to perform the planned well construction operations.', 'The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure.', 'A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein.', 'A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.']

['1.', 'A well construction system comprising:\nwell construction equipment operable to construct, at a wellsite, a well that extends to a reservoir;\na power supply system operable to output electrical power to the well construction equipment to facilitate operation of the well construction equipment and at least in part operable to generate electrical power using gas produced from the reservoir; and\na control system configured to control the well construction system, wherein the control system comprises a processor and a memory storing a computer program code, and wherein the control system is operable to:\nstore a digital drilling program comprising: an equipment operational plan indicative of a sequence of planned well construction operations to be performed by the well construction equipment over a period of time to construct the well, wherein each planned well construction operation in the sequence of planned well construction operations is scheduled to be performed at a respective time within the period of time; and an electrical power plan indicative of a planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations;\ndetermine an electrical power output capacity indicative of a total electrical power that the power supply system can output to the well construction equipment to perform the sequence of planned well construction operations;\ncompare the electrical power output capacity to the planned electrical power demand;\nbased on the comparison, adjust the sequence of planned well construction operations to adjust the planned electrical power demand by adjustment of at least one of a speed of, an acceleration of, a pressure generated by, and a flow rate output by a component of the well construction equipment to perform the sequence of planned well construction operations; and\noptimize performance of the power supply system based at least in part on availability of the gas produced from the reservoir; and\ncause the well construction equipment to perform the sequence of planned well construction operations indicated in the equipment operational plan.', '2.', 'The well construction system of claim 1 wherein the electrical power plan specifies a respective amount of electrical power at the respective time for each planned well construction operation in the sequence of planned well construction operations, and the control system is further operable to cause the power supply system to output the electrical power to the well construction equipment based on the electrical power plan to thereby meet the planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations.', '3.', 'The well construction system of claim 2 wherein the electrical power output by the power supply system exceeds the planned electrical power demand of the well construction equipment by a predetermined amount.', '4.', 'The well construction system of claim 2 wherein the electrical power output by the power supply system also minimizes discharge rate of exhaust emissions.', '5.', 'The well construction system of claim 2 wherein the electrical power output by the power supply system also minimizes consumption rate of fuel.', '6.', 'The well construction system of claim 2 wherein:\nthe power supply system comprises: a plurality of electric generator units, wherein one or more of the electric generator units are powerable using the gas produced from the reservoir; and an electrical energy storage unit; and\nthe control system is further operable to: cause the electrical energy storage unit to store at least some of the electrical power output by the plurality of electric generator units; and cause the plurality of electric generator units and the electrical energy storage unit to output the electrical power to the well construction equipment based on the electrical power plan to thereby meet the planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations.', '7.', 'The well construction system of claim 1 wherein the control system is further operable to:\ndetermine an actual electrical power demand of the well construction equipment during the performance of the sequence of planned well construction operations;\ncompare the actual electrical power demand to the planned electrical power demand;\nbased on the comparison, adjust the planned electrical power demand to form an adjusted planned electrical power demand; and\ncause the power supply system to output the electrical power to the well construction equipment based on the adjusted planned electrical power demand to thereby meet the adjusted planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations.', '8.', 'The well construction system of claim 1 wherein adjusting the sequence of planned well construction operations to adjust the planned electrical power demand comprises delaying a start of one or more of the planned well construction operations in the sequence of planned well construction operations.', '9.', 'The well construction system of claim 8, wherein the delaying a start of one or more of the planned well construction operations in the sequence of planned well construction operations provides time for one or more electrical generators to operate at higher efficiency.', '10.', 'The well construction system of claim 1 wherein the control system is further operable to:\ndetermine an electrical power output capacity indicative of a total electrical power that the power supply system can output to the well construction equipment to perform the sequence of planned well construction operations; and\ndisplay on a video output device for viewing by personnel: the electrical power output capacity; and a graph that represents variations in the planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations over the period of time.\n\n\n\n\n\n\n11.', 'The well construction system of claim 1 wherein the control system is further operable to display on a video output device for viewing by personnel:\na graph comprising a curve that indicates variations in the planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations over the period of time.', '12.', 'The well construction system of claim 11 wherein the control system is further operable to display on the video output device for view by personnel:\nthe graph comprising an additional curve that indicates an actual electrical power demand of the well construction equipment during the performance of the sequence of planned well construction operations over the period of time.', '13.', 'The well construction system of claim 1, wherein the gas produced from the reservoir is at least in part produced via the well.\n\n\n\n\n\n\n14.', 'The well construction system of claim 1, wherein the gas produced from the reservoir is at least in part produced during one or more of the planned well construction operations.', '15.', 'A method comprising:\nstoring, via a control system of a well construction system, a digital drilling program comprising: an equipment operational plan indicative of a sequence of planned well construction operations to be performed by well construction equipment to construct, at a wellsite, a well that extends to a reservoir; and an electrical power plan indicative of a planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations;\ninstructing, via the control system, the well construction equipment to perform each planned well construction operation in the sequence of planned well construction operations at a respective time indicated in the equipment operational plan;\ndetermining, using the control system, an electrical power output capacity indicative of a total electrical power that a power supply system can output to the well construction equipment to perform the sequence of planned well construction operations, wherein the power supply system is at least in part operable to generate electrical power using gas produced from the reservoir;\ncomparing, using the control system, the electrical power output capacity to the planned electrical power demand;\nbased on the comparing and using the control system, adjusting at least one planned well construction operation in the sequence of planned well construction operations by adjusting at least one of a speed of, an acceleration of, a pressure generated by, and a flow rate output by a component of the well construction equipment to perform the sequence of planned well construction operations; and\noptimize performance of the power supply system based at least in part on availability of the gas produced from the reservoir.', '16.', 'The method of claim 15 wherein adjusting the at least one planned well construction operation to adjust the planned electrical power demand comprises delaying a start of the at least one planned well construction operation.', '17.', 'The method of claim 16, wherein the delaying a start of the at least one planned well construction operation provides time for one or more electrical generators to operate at higher efficiency.', '18.', 'The method of claim 15 further comprising:\nprior to instructing the well construction equipment to perform the sequence of planned well construction operations and using the control system, instructing a video output device to display for viewing by personnel: a graph comprising a curve that indicates variations in the planned electrical power demand of the well construction equipment to perform the sequence of planned well construction operations over time.']

['FIG.', '1 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG.', '2 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG.', '3 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG.', '4 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.; FIGS. 5 and 6 are example implementations of screens displayed by the apparatus shown in one or more of FIGS.', '1 and 2 according to one or more aspects of the present disclosure.', '; FIG. 1 is a schematic view of at least a portion of an example implementation of a well construction system 100 according to one or more aspects of the present disclosure.', 'The well construction system 100 represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'The well construction system 100 may be or comprise a well construction rig (e.g., a well drilling rig).', 'Although the well construction system 100 is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', '; FIG.', '3 is a schematic view of at least a portion of an example implementation of a PS system 300 of a well construction system 100.', 'The PS system 300 may be communicatively connected with and controlled by the central controller 192 shown in FIGS.', '1 and 2.', 'The PS system 300 may be an example implementation of, and/or comprise one or more features of, the PS system 218 shown in FIG.', '2.', 'Accordingly, the following description refers to FIGS.', '1-3, collectively.;', 'FIG. 4 is a schematic view of at least a portion of an example implementation of a processing device 400 (or system) according to one or more aspects of the present disclosure.', 'The processing device 400 may be or form at least a portion of one or more equipment controllers and/or other electronic devices shown in one or more of the FIGS.', '1-3.', 'Accordingly, the following description refers to FIGS.', '1-4, collectively.']

US11727191

Process for highlighting text with varied orientation

May 21, 2020

Mohit Sajwan

Schlumberger Technology Corporation

Nov. 10, 2021_International Search Report and Written Opinion for the equivalent PCT/US20/033906 dated Sep. 3, 2020.; Anonymous, “HTML Canvas—Rotating images on canvas—2-D transformations”, retrieved from the internet on Apr. 26, 2023 from [https://web.archive.org/web/20111030014015/http://falcon80.com/HTMLCanvas/CanvasTransformations/Rotate.html] dated Oct. 30, 2011, 2 pages.; Extended Search Report issued in European Patent Application No. 20809252.8 dated May 8, 2023, 6 pages.

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1995037116; February 1995; JP

['A computer-implemented method and apparatus for highlighting text in an image disposed in a markup language document are disclosed.', 'Location data identifying a location, size and orientation of a text element in the image may be obtained, where the text element is oriented in a direction that is non-orthogonal to vertical and horizontal axes of the image.', 'A context for a canvas element in the document may be obtained and rotated to align the context to the orientation of the text element using the location data.', 'The context may also be translated to the location of the text element using the location data, and a text highlighting element that at least partially overlays the text element may be generated.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE PARAGRAPH\n \nThis application claims the benefit of Indian Non-Provisional Application No. 201921020069, entitled “PROCESS FOR HIGHLIGHTING TEXT WITH VARIED ORIENTATION,” filed May 21, 2019, the disclosure of which is hereby incorporated herein by reference.', 'BACKGROUND\n \nText highlighting is supported by numerous computer software applications, e.g., to highlight particular terms or phrases searched for by a user, including, for example, markup language documents such as HTML documents that may include text and/or images incorporating text.', 'However, in many applications, all text is oriented horizontally, or in some instances, vertically (e.g., at a 90 degree offset from horizontal), and highlighting such text is generally a straightforward operation.', 'For other software applications, however, it may be desirable to orient text in different arbitrary orientations, e.g., when displaying labels on maps or other spatially-oriented data visualizations.', 'Such arbitrarily-oriented text, for example, is used in many applications used in the oil & gas industry.', 'In addition, where text is disposed in an image, any rotation of the image may result in text that, while oriented horizontally or vertically within the image, may nonetheless be at a non-horizontal and non-vertical orientation from the perspective of a document within which the image is disposed.', 'Conventionally, when text is oriented at an angle other than 0 degrees or 90 degrees, text highlighting is typically not possible or not accurate, such that even a slight change in the angle may alter the text highlighting effect and may result in a negative user experience.', "In some instances, some applications may even simply ignore text not oriented at 0 degrees or 90 degrees, which reduces the application's functionality, particularly if a search is conducted for a particular term and that term is never highlighted.", 'A need therefore exists in the art for a manner of highlighting text at various angles of orientation, particularly text found in images in HTML and other markup language documents.', 'SUMMARY\n \nThe embodiments disclosed herein provide a method, apparatus, and program product for highlighting text at any arbitrary orientation in an image disposed in a markup language document (e.g. HTML), in part by rotating and/or translating a context of a canvas element in the markup language document.', 'Therefore, consistent with one aspect of the invention, a computer-implemented method for highlighting text in an image disposed in a markup language document is described, the method including: obtaining, by a processor, location data identifying a location, size and orientation of a text element in the image, where the text element is oriented in a direction that is non-orthogonal to vertical and horizontal axes of the image; obtaining, by the processor, a context for a canvas element in the document; rotating, by the processor, the context for the canvas element to align the context to the orientation of the text element using the location data; translating, by the processor, the context for the canvas element to the location of the text element using the location data; and generating, by the processor, a text highlighting element having a size that at least partially overlays the text element on the rotated and translated canvas using the location data.', 'In some embodiments, the computer implemented method may additionally include: saving, by the processor, the context for the canvas element in the document, where the text element is oriented in the direction that is non-orthogonal to vertical and horizontal axes of the image; and clearing, by the processor, the context for the canvas element prior to rotating and translating the context for the canvas element.', 'In some embodiments, the computer implemented method may additionally include restoring, by the processor, the context of the canvas element such that the text element is reoriented in the direction that is non-orthogonal to vertical and horizontal axes of the image following the generation of the text highlighting.', 'In some embodiments, the text element in the image is one of a plurality of text elements in the image, where first and second text elements of the plurality of text elements are oriented in first and second directions that are non-orthogonal to vertical and horizontal axes of the image.', 'In some such embodiments, the computer implemented method may further include repeating the location data obtaining, the context obtaining, the rotating, the translating and the generating steps for each of the first and second text elements.', 'In some embodiments, rotating the context for the canvas element to align the context to the orientation of the text element using the location data further includes determining, by the processor, an angle of the text element in the image using the location data.', 'In other embodiments, the angle of the text element equals tan\n−1 \n(slope), wherein the slope equals: (a Y coordinate of a top right corner of a bounding box−a Y coordinate of a top left corner of the bounding box)/(an X coordinate of the top right corner of the bounding box−an X coordinate of the top left corner of the bounding box).', 'In another aspect, an apparatus is described herein, where the apparatus includes: at least one processing unit; and program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document including: obtaining location data identifying a location, size and orientation of a text element in the image, where the text element is oriented in a direction that is non-orthogonal to vertical and horizontal axes of the image; obtaining a context for a canvas element in the document; rotating the context for the canvas element to align the context to the orientation of the text element using the location data; translating the context for the canvas element to the location of the text element using the location data; and generating a text highlighting element having a size that at least partially overlays the text element on the rotated and translated canvas using the location data.', 'In some embodiments, the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes: saving the context for the canvas element in the document, where the text element is oriented in the direction that is non-orthogonal to vertical and horizontal axes of the image; and clearing the context for the canvas element prior to rotating and translating the context for the canvas element.', 'In some such embodiments, the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document may further include restoring the context of the canvas element such that the text element is reoriented in the direction that is non-orthogonal to vertical and horizontal axes of the image following the generation of the text highlighting.', 'In some embodiments, the text element in the image is one of a plurality of text elements in the image and where first and second text elements of the plurality of text elements are oriented in first and second directions that are non-orthogonal to vertical and horizontal axes of the image.', 'In some such embodiments, the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document may further include repeating the location data obtaining, the context obtaining, the rotating, the translating and the generating steps for each of the first and second text elements.', 'In some embodiments, rotating the context for the canvas element to align the context to the orientation of the text element using the location data further includes determining an angle of the text element in the image using the location data.', 'In some such embodiments, the angle of the text element equals tan\n−1 \n(slope), where the slope equals: (a Y coordinate of a top right corner of a bounding box−a Y coordinate of a top left corner of the bounding box)/(an X coordinate of the top right corner of the bounding box−an X coordinate of the top left corner of the bounding box).', 'In yet another aspect, a program product is described, the program product including: a computer readable medium; and program code stored on the computer readable medium and configured upon execution by at least one processing unit to highlight text in an image disposed in a markup language document including by: obtaining location data identifying a location, size and orientation of a text element in the image, where the text element is oriented in a direction that is non-orthogonal to vertical and horizontal axes of the image; obtaining a context for a canvas element in the document; rotating the context for the canvas element to align the context to the orientation of the text element using the location data; translating the context for the canvas element to the location of the text element using the location data; and generating a text highlighting element having a size that at least partially overlays the text element on the rotated and translated canvas using the location data.', 'In some embodiments, the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document may further include: saving the context for the canvas element in the document, where the text element is oriented in the direction that is non-orthogonal to vertical and horizontal axes of the image; and clearing the context for the canvas element prior to rotating and translating the context for the canvas element.', 'In other embodiments, the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes restoring the context of the canvas element such that the text element is reoriented in the direction that is non-orthogonal to vertical and horizontal axes of the image following the generation of the text highlighting.', 'In some embodiments, the text element in the image is one of a plurality of text elements in the image and wherein first and second text elements of the plurality of text elements are oriented in first and second directions that are non-orthogonal to vertical and horizontal axes of the image.', 'In some such embodiments, the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document may additionally include repeating the location data obtaining, the context obtaining, the rotating, the translating and the generating steps for each of the first and second text elements.', 'These and other advantages and features, which characterize the invention, are set forth in the claims annexed hereto and forming a further part hereof.', 'However, for a better understanding of the invention, and of the advantages and objectives attained through its use, reference should be made to the Drawings, and to the accompanying descriptive matter, in which there is described example embodiments of the invention.', 'This summary is merely provided to introduce a selection of concepts that are further described below in the detailed description, and is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a block diagram of an example hardware and software environment for a data processing system in accordance with implementation of various technologies and techniques described herein.', 'FIGS.', '2\nA-\n2\nD\n illustrate simplified, schematic views of an oilfield having subterranean formations containing reservoirs therein in accordance with implementations of various technologies and techniques described herein.\n \nFIG.', '3\n illustrates a schematic view, partially in cross section of an oilfield having a plurality of data acquisition tools positioned at various locations along the oilfield for collecting data from the subterranean formations in accordance with implementations of various technologies and techniques described herein.\n \nFIG.', '4\n illustrates a production system for performing one or more oilfield operations in accordance with implementations of various technologies and techniques described herein.\n \nFIG.', '5\n is a flowchart illustrating an example sequence of operations for highlighting text in an image disposed in a markup language document using the data processing system of \nFIG.', '1\n.', 'FIGS.', '6\nA-\n6\nG\n illustrate simplified, schematic views of an exemplary process of highlighting text in an image disposed in a markup language document.', 'FIG.', '6\nA\n is a schematic view of a text element to be highlighted.', 'FIG.', '6\nB\n is a schematic view of various location data obtained about the text element.', 'FIG.', '6\nC\n is a schematic view of the context of the canvas element.', 'FIG.', '6\nD\n is a schematic view of a rotated context of the canvas element.', 'FIG.', '6\nE\n is a schematic view of a translated context of the canvas element.', 'FIG.', '6\nF\n is a schematic view of the generated highlighted text element on the rotated and translated canvas.', 'FIG.', '6\nG\n is a schematic view of the restored context of the canvas element with the highlighted canvas element overlaying at least a part of the text element.', 'DETAILED DESCRIPTION', 'The herein-described embodiments provide a method, apparatus, and program product that highlight text in an image in a markup language document, where the text may be oriented at varying angles (e.g. in a direction that may be non-orthogonal to vertical and horizontal axes of the image).', 'In some embodiments, location data of the text element, which may include the size and orientation of the text element, are obtained.', 'A context of a canvas element in the document may then be obtained and manipulated in various manners described herein in order to generate a text highlighting element that may overlay at least a portion of the text.', 'Other variations and modifications will be apparent to one of ordinary skill in the art.', 'Hardware and Software Environment\n \nTurning now to the drawings, wherein like numbers denote like parts throughout the several views, \nFIG.', '1\n illustrates an example data processing system \n10\n in which the various technologies and techniques described herein may be implemented.', 'System \n10\n is illustrated as including one or more computers \n12\n, e.g., client computers, each including a central processing unit (CPU) \n14\n including at least one hardware-based processor or processing core \n16\n.', 'CPU \n14\n is coupled to a memory \n18\n, which may represent the random access memory (RAM) devices comprising the main storage of a computer \n12\n, as well as any supplemental levels of memory, e.g., cache memories, non-volatile or backup memories (e.g., programmable or flash memories), read-only memories, etc.', 'In addition, memory \n18\n may be considered to include memory storage physically located elsewhere in a computer \n12\n, e.g., any cache memory in a microprocessor or processing core, as well as any storage capacity used as a virtual memory, e.g., as stored on a mass storage device \n20\n or on another computer coupled to a computer \n12\n.', 'Each computer \n12\n also generally receives a number of inputs and outputs for communicating information externally.', 'For interface with a user or operator, a computer \n12\n generally includes a user interface \n22\n incorporating one or more user input/output devices, e.g., a keyboard, a pointing device, a display, a printer, etc.', 'Otherwise, user input may be received, e.g., over a network interface \n24\n coupled to a network \n26\n, from one or more external computers, e.g., one or more servers \n28\n or other computers \n12\n.', 'A computer \n12\n also may be in communication with one or more mass storage devices \n20\n, which may be, for example, internal hard disk storage devices, external hard disk storage devices, storage area network devices, etc.', 'A computer \n12\n generally operates under the control of an operating system \n30\n and executes or otherwise relies upon various computer software applications, components, programs, objects, modules, data structures, etc.', 'For example, a petro-technical module or component \n32\n executing within an exploration and production (E&P) platform \n34\n may be used to access, process, generate, modify or otherwise utilize petro-technical data, e.g., as stored locally in a database \n36\n and/or accessible remotely from a collaboration platform \n38\n.', 'Collaboration platform \n38\n may be implemented using multiple servers \n28\n in some implementations, and it will be appreciated that each server \n28\n may incorporate a CPU, memory, and other hardware components similar to a computer \n12\n.', 'In one non-limiting embodiment, for example, E&P platform \n34\n may implemented as the PETREL Exploration & Production (E&P) software platform, while collaboration platform \n38\n may be implemented as the STUDIO E&P KNOWLEDGE ENVIRONMENT platform, both of which are available from Schlumberger Ltd. and its affiliates.', 'It will be appreciated, however, that the techniques discussed herein may be utilized in connection with other platforms and environments, so the invention is not limited to the particular software platforms and environments discussed herein.', 'It will be appreciated that the herein-described techniques may be implemented in a number of different computers, computer systems, devices, etc.', 'In some embodiments, the herein-described techniques may be implemented within a production computer.', 'In other embodiments, the implementation may be within an on-site computer at an oil field, within a pump itself (e.g. a smart pump), in a well or pump controller, in a cloud service, in a remote server, in another computer or electric device, or in various combinations thereof.', 'In general, the routines executed to implement the embodiments disclosed herein, whether implemented as part of an operating system or a specific application, component, program, object, module or sequence of instructions, or even a subset thereof, will be referred to herein as “computer program code,” or simply “program code.”', 'Program code generally comprises one or more instructions that are resident at various times in various memory and storage devices in a computer, and that, when read and executed by one or more hardware-based processing units in a computer (e.g., microprocessors, processing cores, or other hardware-based circuit logic), cause that computer to perform the steps embodying desired functionality.', 'Moreover, while embodiments have and hereinafter will be described in the context of fully functioning computers and computer systems, those skilled in the art will appreciate that the various embodiments are capable of being distributed as a program product in a variety of forms, and that the invention applies equally regardless of the particular type of computer readable media used to actually carry out the distribution.', 'Such computer readable media may include computer readable storage media and communication media.', 'Computer readable storage media is non-transitory in nature, and may include volatile and non-volatile, and removable and non-removable media implemented in any method or technology for storage of information, such as computer-readable instructions, data structures, program modules or other data.', 'Computer readable storage media may further include RAM, ROM, erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other solid state memory technology, CD-ROM, DVD, or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other medium that can be used to store the desired information and which can be accessed by computer \n10\n.', 'Communication media may embody computer readable instructions, data structures or other program modules.', 'By way of example, and not limitation, communication media may include wired media such as a wired network or direct-wired connection, and wireless media such as acoustic, RF, infrared and other wireless media.', 'Combinations of any of the above may also be included within the scope of computer readable media.', 'Various program code described hereinafter may be identified based upon the application within which it is implemented in a specific embodiment of the invention.', 'However, it should be appreciated that any particular program nomenclature that follows is used merely for convenience, and thus the invention should not be limited to use solely in any specific application identified and/or implied by such nomenclature.', "Furthermore, given the endless number of manners in which computer programs may be organized into routines, procedures, methods, modules, objects, and the like, as well as the various manners in which program functionality may be allocated among various software layers that are resident within a typical computer (e.g., operating systems, libraries, API's, applications, applets, etc.), it should be appreciated that the invention is not limited to the specific organization and allocation of program functionality described herein.", 'Furthermore, it will be appreciated by those of ordinary skill in the art having the benefit of the instant disclosure that the various operations described herein that may be performed by any program code, or performed in any routines, workflows, or the like, may be combined, split, reordered, omitted, and/or supplemented with other techniques known in the art, and therefore, the invention is not limited to the particular sequences of operations described herein.', 'Those skilled in the art will recognize that the example environment illustrated in \nFIG.', '1\n is not intended to limit the invention.', 'Indeed, those skilled in the art will recognize that other alternative hardware and/or software environments may be used without departing from the scope of the invention.', 'Oilfield Operations\n \nFIGS.', '2\nA-\n2\nD\n illustrate simplified, schematic views of an oilfield \n100\n having subterranean formation \n102\n containing reservoir \n104\n therein in accordance with implementations of various technologies and techniques described herein. \nFIG.', '2\nA\n illustrates a survey operation being performed by a survey tool, such as seismic truck \n106\n.', '1\n, to measure properties of the subterranean formation.', 'The survey operation is a seismic survey operation for producing sound vibrations.', 'In \nFIG.', '2\nA\n, one such sound vibration, sound vibration \n112\n generated by source \n110\n, reflects off horizons \n114\n in earth formation \n116\n.', "A set of sound vibrations is received by sensors, such as geophone-receivers \n118\n, situated on the earth's surface.", 'The data received \n120\n is provided as input data to a computer \n122\n.\n1\n of a seismic truck \n106\n.\n1\n, and responsive to the input data, computer \n122\n.\n1\n generates seismic data output \n124\n.', 'This seismic data output may be stored, transmitted or further processed as desired, for example, by data reduction.', 'FIG.', '2\nB\n illustrates a drilling operation being performed by drilling tools \n106\n.\n2\n suspended by rig \n128\n and advanced into subterranean formations \n102\n to form wellbore \n136\n.', 'Mud pit \n130\n is used to draw drilling mud into the drilling tools via flow line \n132\n for circulating drilling mud down through the drilling tools, then up wellbore \n136\n and back to the surface.', 'The drilling mud may be filtered and returned to the mud pit.', 'A circulating system may be used for storing, controlling, or filtering the flowing drilling muds.', 'The drilling tools are advanced into subterranean formations \n102\n to reach reservoir \n104\n.', 'Each well may target one or more reservoirs.', 'The drilling tools are adapted for measuring downhole properties using logging while drilling tools.', 'The logging while drilling tools may also be adapted for taking core sample \n133\n as shown.', 'Computer facilities may be positioned at various locations about the oilfield \n100\n (e.g., the surface unit \n134\n) and/or at remote locations.', 'Surface unit \n134\n may be used to communicate with the drilling tools and/or offsite operations, as well as with other surface or downhole sensors.', 'Surface unit \n134\n is capable of communicating with the drilling tools to send commands to the drilling tools, and to receive data therefrom.', 'Surface unit \n134\n may also collect data generated during the drilling operation and produces data output \n135\n, which may then be stored or transmitted.', 'Sensors (S), such as gauges, may be positioned about oilfield \n100\n to collect data relating to various oilfield operations as described previously.', 'As shown, sensor (S) is positioned in one or more locations in the drilling tools and/or at rig \n128\n to measure drilling parameters, such as weight on bit, torque on bit, pressures, temperatures, flow rates, compositions, rotary speed, and/or other parameters of the field operation.', 'Sensors (S) may also be positioned in one or more locations in the circulating system.', 'Drilling tools \n106\n.', '2\n may include a bottom hole assembly (BHA) (not shown), generally referenced, near the drill bit (e.g., within several drill collar lengths from the drill bit).', 'The bottom hole assembly includes capabilities for measuring, processing, and storing information, as well as communicating with surface unit \n134\n.', 'The bottom hole assembly further includes drill collars for performing various other measurement functions.', 'The bottom hole assembly may include a communication subassembly that communicates with surface unit \n134\n.', 'The communication subassembly is adapted to send signals to and receive signals from the surface using a communications channel such as mud pulse telemetry, electro-magnetic telemetry, or wired drill pipe communications.', 'The communication subassembly may include, for example, a transmitter that generates a signal, such as an acoustic or electromagnetic signal, which is representative of the measured drilling parameters.', 'It will be appreciated by one of skill in the art that a variety of telemetry systems may be employed, such as wired drill pipe, electromagnetic or other known telemetry systems.', 'Generally, the wellbore is drilled according to a drilling plan that is established prior to drilling.', 'The drilling plan sets forth equipment, pressures, trajectories and/or other parameters that define the drilling process for the wellsite.', 'The drilling operation may then be performed according to the drilling plan.', 'However, as information is gathered, the drilling operation may need to deviate from the drilling plan.', 'Additionally, as drilling or other operations are performed, the subsurface conditions may change.', 'The earth model may also need adjustment as new information is collected.', 'The data gathered by sensors (S) may be collected by surface unit \n134\n and/or other data collection sources for analysis or other processing.', 'The data collected by sensors (S) may be used alone or in combination with other data.', 'The data may be collected in one or more databases and/or transmitted on or offsite.', 'The data may be historical data, real time data, or combinations thereof.', 'The real time data may be used in real time, or stored for later use.', 'The data may also be combined with historical data or other inputs for further analysis.', 'The data may be stored in separate databases, or combined into a single database.', 'Surface unit \n134\n may include transceiver \n137\n to allow communications between surface unit \n134\n and various portions of the oilfield \n100\n or other locations.', 'Surface unit \n134\n may also be provided with or functionally connected to one or more controllers (not shown) for actuating mechanisms at oilfield \n100\n.', 'Surface unit \n134\n may then send command signals to oilfield \n100\n in response to data received.', 'Surface unit \n134\n may receive commands via transceiver \n137\n or may itself execute commands to the controller.', 'A processor may be provided to analyze the data (locally or remotely), make the decisions and/or actuate the controller.', 'In this manner, oilfield \n100\n may be selectively adjusted based on the data collected.', 'This technique may be used to optimize portions of the field operation, such as controlling drilling, weight on bit, pump rates, or other parameters.', 'These adjustments may be made automatically based on computer protocol, and/or manually by an operator.', 'In some cases, well plans may be adjusted to select optimum operating conditions, or to avoid problems.', 'FIG.', '2\nC\n illustrates a wireline operation being performed by wireline tool \n106\n.\n3\n suspended by rig \n128\n and into wellbore \n136\n of \nFIG.', '2\nB\n.', 'Wireline tool \n106\n.', '3\n is adapted for deployment into wellbore \n136\n for generating well logs, performing downhole tests and/or collecting samples.', 'Wireline tool \n106\n.\n3\n may be used to provide another method and apparatus for performing a seismic survey operation.', 'Wireline tool \n106\n.\n3\n may, for example, have an explosive, radioactive, electrical, or acoustic energy source \n144\n that sends and/or receives electrical signals to surrounding subterranean formations \n102\n and fluids therein.', 'Wireline tool \n106\n.\n3\n may be operatively connected to, for example, geophones \n118\n and a computer \n122\n.', '1\n of a seismic truck \n106\n.', '1\n of \nFIG.', '2\nA\n.', 'Wireline tool \n106\n.\n3\n may also provide data to surface unit \n134\n.', 'Surface unit \n134\n may collect data generated during the wireline operation and may produce data output \n135\n that may be stored or transmitted.', 'Wireline tool \n106\n.\n3\n may be positioned at various depths in the wellbore \n136\n to provide a survey or other information relating to the subterranean formation \n102\n.', 'Sensors (S), such as gauges, may be positioned about oilfield \n100\n to collect data relating to various field operations as described previously.', 'As shown, sensor S is positioned in wireline tool \n106\n.', '3\n to measure downhole parameters which relate to, for example porosity, permeability, fluid composition and/or other parameters of the field operation.', 'FIG.', '2\nD\n illustrates a production operation being performed by production tool \n106\n.\n4\n deployed from a production unit or Christmas tree \n129\n and into completed wellbore \n136\n for drawing fluid from the downhole reservoirs into surface facilities \n142\n.', 'The fluid flows from reservoir \n104\n through perforations in the casing (not shown) and into production tool \n106\n.\n4\n in wellbore \n136\n and to surface facilities \n142\n via gathering network \n146\n.', 'Sensors (S), such as gauges, may be positioned about oilfield \n100\n to collect data relating to various field operations as described previously.', 'As shown, the sensor (S) may be positioned in production tool \n106\n.', '4\n or associated equipment, such as christmas tree \n129\n, gathering network \n146\n, surface facility \n142\n, and/or the production facility, to measure fluid parameters, such as fluid composition, flow rates, pressures, temperatures, and/or other parameters of the production operation.', 'Production may also include injection wells for added recovery.', 'One or more gathering facilities may be operatively connected to one or more of the wellsites for selectively collecting downhole fluids from the wellsite(s).', 'While \nFIGS.', '2\nB-\n2\nD\n illustrate tools used to measure properties of an oilfield, it will be appreciated that the tools may be used in connection with non-oilfield operations, such as gas fields, mines, aquifers, storage, or other subterranean facilities.', 'Also, while certain data acquisition tools are depicted, it will be appreciated that various measurement tools capable of sensing parameters, such as seismic two-way travel time, density, resistivity, production rate, etc., of the subterranean formation and/or its geological formations may be used.', 'Various sensors (S) may be located at various positions along the wellbore and/or the monitoring tools to collect and/or monitor the desired data.', 'Other sources of data may also be provided from offsite locations.', 'The field configurations of \nFIGS.', '2\nA-\n2\nD\n are intended to provide a brief description of an example of a field usable with oilfield application frameworks.', 'Part, or all, of oilfield \n100\n may be on land, water, and/or sea.', 'Also, while a single field measured at a single location is depicted, oilfield applications may be utilized with any combination of one or more oilfields, one or more processing facilities and one or more wellsites.\n \nFIG.', '3\n illustrates a schematic view, partially in cross section of oilfield \n200\n having data acquisition tools \n202\n.', '1\n, \n202\n.', '2\n, \n202\n.', '3\n and \n202\n.', '4\n positioned at various locations along oilfield \n200\n for collecting data of subterranean formation \n204\n in accordance with implementations of various technologies and techniques described herein.', 'Data acquisition tools \n202\n.', '1\n-\n202\n.', '4\n may be the same as data acquisition tools \n106\n.\n1\n-\n106\n.\n4\n of \nFIGS.', '2\nA-\n2\nD\n, respectively, or others not depicted.', 'As shown, data acquisition tools \n202\n.', '1\n-\n202\n.', '4\n generate data plots or measurements \n208\n.\n1\n-\n208\n.\n4\n, respectively.', 'These data plots are depicted along oilfield \n200\n to demonstrate the data generated by the various operations.', 'Data plots \n208\n.', '1\n-\n208\n.', '3\n are examples of static data plots that may be generated by data acquisition tools \n202\n.\n1\n-\n202\n.', '3\n, respectively, however, it should be understood that data plots \n208\n.', '1\n-\n208\n.', '3\n may also be data plots that are updated in real time.', 'These measurements may be analyzed to better define the properties of the formation(s) and/or determine the accuracy of the measurements and/or for checking for errors.', 'The plots of each of the respective measurements may be aligned and scaled for comparison and verification of the properties.', 'Static data plot \n208\n.', '1\n is a seismic two-way response over a period of time.', 'Static plot \n208\n.', '2\n is core sample data measured from a core sample of the formation \n204\n.', 'The core sample may be used to provide data, such as a graph of the density, porosity, permeability, or some other physical property of the core sample over the length of the core.', 'Tests for density and viscosity may be performed on the fluids in the core at varying pressures and temperatures.', 'Static data plot \n208\n.', '3\n is a logging trace that generally provides a resistivity or other measurement of the formation at various depths.', 'A production decline curve or graph \n208\n.', '4\n is a dynamic data plot of the fluid flow rate over time.', 'The production decline curve generally provides the production rate as a function of time.', 'As the fluid flows through the wellbore, measurements are taken of fluid properties, such as flow rates, pressures, composition, etc.', 'Other data may also be collected, such as historical data, user inputs, economic information, and/or other measurement data and other parameters of interest.', 'As described below, the static and dynamic measurements may be analyzed and used to generate models of the subterranean formation to determine characteristics thereof.', 'Similar measurements may also be used to measure changes in formation aspects over time.', 'The subterranean structure \n204\n has a plurality of geological formations \n206\n.', '1\n-\n206\n.', '4\n.', 'As shown, this structure has several formations or layers, including a shale layer \n206\n.', '1\n, a carbonate layer \n206\n.', '2\n, a shale layer \n206\n.', '3\n and a sand layer \n206\n.', '4\n.', 'A fault \n207\n extends through the shale layer \n206\n.', '1\n and the carbonate layer \n206\n.', '2\n.', 'The static data acquisition tools are adapted to take measurements and detect characteristics of the formations.', 'While a specific subterranean formation with specific geological structures is depicted, it will be appreciated that oilfield \n200\n may contain a variety of geological structures and/or formations, sometimes having extreme complexity.', 'In some locations, generally below the water line, fluid may occupy pore spaces of the formations.', 'Each of the measurement devices may be used to measure properties of the formations and/or its geological features.', 'While each acquisition tool is shown as being in specific locations in oilfield \n200\n, it will be appreciated that one or more types of measurement may be taken at one or more locations across one or more fields or other locations for comparison and/or analysis.', 'The data collected from various sources, such as the data acquisition tools of \nFIG.', '3\n, may then be processed and/or evaluated.', 'Generally, seismic data displayed in static data plot \n208\n.', '1\n from data acquisition tool \n202\n.\n1\n is used by a geophysicist to determine characteristics of the subterranean formations and features.', 'The core data shown in static plot \n208\n.', '2\n and/or log data from well log \n208\n.', '3\n are generally used by a geologist to determine various characteristics of the subterranean formation.', 'The production data from graph \n208\n.\n4\n is generally used by the reservoir engineer to determine fluid flow reservoir characteristics.', 'The data analyzed by the geologist, geophysicist and the reservoir engineer may be analyzed using modeling techniques.\n \nFIG.', '4\n illustrates an oilfield \n300\n for performing production operations in accordance with implementations of various technologies and techniques described herein.', 'As shown, the oilfield has a plurality of wellsites \n302\n operatively connected to central processing facility \n354\n.', 'The oilfield configuration of \nFIG.', '4\n is not intended to limit the scope of the oilfield application system.', 'Part or all of the oilfield may be on land and/or sea.', 'Also, while a single oilfield with a single processing facility and a plurality of wellsites is depicted, any combination of one or more oilfields, one or more processing facilities and one or more wellsites may be present.', 'Each wellsite \n302\n has equipment that forms wellbore \n336\n into the earth.', 'The wellbores extend through subterranean formations \n306\n including reservoirs \n304\n.', 'These reservoirs \n304\n contain fluids, such as hydrocarbons.', 'The wellsites draw fluid from the reservoirs and pass them to the processing facilities via surface networks \n344\n.', 'The surface networks \n344\n have tubing and control mechanisms for controlling the flow of fluids from the wellsite to processing facility \n354\n.\n \nProcess for Highlighting Text with Varied Orientation\n \nAs previously mentioned, text highlighting is used in various user interface based applications, including those used in the oil and gas industry.', 'In some applications, for example, markup language documents such as Hypertext Markup Language (HTML)-compatible markup language documents are used to display information to an end user, with the markup language documents including various tags or elements that describe how to render information in the document on a display screen.', 'Text, for example, may be represented as a string of characters and including one or more tags or elements that describe how to format the characters to be rendered, e.g., using different fonts, colors, backgrounds, highlights, effects, etc.', 'Text may also, however, be rendered within graphical images that are embedded in a markup language document, and various image processing techniques such as optical character recognition may be used to identify the text rendered within an image.', 'However, conventional text highlighting may be unable to accurately highlight text that is oriented at an angle other than 0 degrees or 90 degrees, particularly when that text is rendered in a graphical image.', 'In many oil & gas applications, however, text may be oriented in various arbitrary angles, e.g., when incorporated into mapping data or into two-dimensional or three-dimensional data visualizations, and oftentimes the text may be oriented at an angle that is non-orthogonal to horizontal and vertical directions, e.g., the horizontal and vertical axes of an image.', 'As such, a method of text highlighting that allows for accurate highlighting of text rendered within an image regardless of the orientation of the text may be desirable for some applications.', 'As will become more apparent below, the described method of text highlighting may use a container, such as an HTML canvas element, that may be manipulated to a correct angle and position in order to highlight at least a portion of the text disposed at an arbitrary angle within an image of a hypertext markup language document.\n \nFIG.', '5\n illustrates a flowchart of an example sequence of operations \n500\n for highlighting text in an image disposed in a markup language document using the data processing system of \nFIG.', '1\n.', 'In the illustrated embodiment, the markup language document is a Hypertext Markup Language (HTML)-compatible document and the container is defined by an HTML canvas element, although other containers may be used in other embodiments in order to properly orient highlighting on an arbitrarily oriented text element.', 'In addition, in the context of this disclosure, the text to be highlighted is referred to as a text element; however, the term text element is used to generically refer to one or more text characters that are represented in an image, and not to any specific markup language element or tag that may define text within a markup language document.', 'Sequence \n500\n begins at block \n505\n, where a variety of location data may be obtained regarding the text element.', 'The location data may be imported from any number of sources including, but not limited to, any one of the user interface based applications used in oil and gas production systems.', 'In some instances, the location data may be the result of a keyword search and image processing (e.g., optical character recognition) of one or more images to identify one or more matching keywords in the image(s) within a markup language document.', 'Cascading Style Sheets (CSS) may also be used to define the area where the text to be highlighted is present.', 'However, CSS may not provide an exact location in some instances.', 'The location data may be obtained in the form of a bounding box, or the X, Y coordinates of each corner (upper left, upper right, lower left, and lower right) of the bounding box.', 'In some instances, additional location-based data points may be calculated from the bounding box and/or the X, Y coordinates of the same.', 'For example, the length and width of the text element may be determined based on the perimeters of the bounding box.', 'In another example, an X, Y coordinate of each corner may be used to calculate a slope and/or angle of rotation of the text element.', 'In other instances, the height, width, slope, angle of rotation, and the like may be predetermined and obtained as a part of the location data.', 'At block \n510\n, a context for a canvas in the markup language document may be obtained.', 'The canvas of a markup language document may be used to draw various graphics, and may be defined, for example, using an HTML canvas element in some embodiments.', 'A context of the canvas may provide a two-dimensional rendering of the drawing surface of the canvas; in some instances, the context may be used for drawing shapes, text, images, etc.', 'In some instances, the canvas may then be optionally saved (block \n515\n) and cleared (block \n520\n) so that a fresh canvas may be used for the generation of the highlighted text element.', 'In some embodiments, clearing the canvas may include removal of all graphics, text, etc., which may, in some instances, improve processing time since the canvas is empty.', 'At block \n525\n, the canvas element is rotated so that the orientation of the context may be aligned with the text element.', 'For example, in some embodiments, the angle of the rotation for the context may be identical to that of the angle of rotation of the text element (for example, as identified using the slope of the text element).', 'However, in some embodiments, such as when utilizing HTML as the markup language, the center point of the rotation may be the canvas origin.', 'The context of the canvas, similar to other two dimensional platforms, utilizes a flat Cartesian coordinate system with the origin (0, 0) positioned at the upper left of the context.', 'Therefore, in some instances, in order for the context to be rotationally aligned with the text element, the canvas element may also be translated.', 'At block \n530\n, the canvas may be translated such that each point of the text element moves in the same direction for the same distance.', 'In some instances, the translation may be so that the upper left corner of the canvas (the origin) aligns with the upper left corner of the of text element.', 'Such an alignment would allow the canvas to rotate to align with the text element.', 'Furthermore, it is to be understood from the description herein that although described first that rotating the canvas and translating the canvas may occur in any order necessary to achieve alignment of the context with the text element.', 'At block \n535\n, a text highlighting element is generated.', 'In some instances, the text highlighting element may completely overlay the text element, for example in the form of a traditional colored highlight.', 'In such instances, the highlighting element may be in the form of a transparent colored area with the same dimensions as the bounding box.', 'A pale yellow color may be used in for the text highlighting element, but this is not to be understood as limiting, as any color may be used.', 'The color may be defined, for example in HTML, by an RGBA (red, green, blue, alpha) color values.', 'RGBA color values are an extension of RGB color values that include an alpha channel—which allows for the specification of an opacity for the defined color.', 'For example, the alpha parameter may be a number between 0.0 (fully transparent) and 1.0 (fully opaque).', 'In other instances, the text highlighting element may only partially overlay the text element, for example if the text highlighting element is an underline of the text element or a line crossing through the text element, or any other marking known in the art.', 'At block \n540\n, a determination is made regarding whether there are any additional text elements to be highlighted, for example where the original canvas included multiple text elements to be highlighted.', 'If there are additional text elements to be highlighted the sequence of operations \n500\n may be repeated for each remaining text element, one at a time, for each remaining text element beginning with obtaining the location data of the next text element (block \n505\n).', 'In some instances, once all of the text elements have been highlighted, the canvas may be restored (block \n545\n) to its original state.', 'In such instances, this restoration may include restoring all of the graphics, text, etc., that were cleared at block \n520\n and leaving the text element properly highlighted, so that the canvas is identical to its original state with the exception of the newly added text highlighting element.\n \nFIGS.', '6\nA-\n6\nG\n illustrate simplified, schematic views of an embodiment of a process described with reference to \nFIG.', '5\n for highlighting text in an image.', 'For example, \nFIG.', '6\nA\n illustrates the text element \n600\n to be highlighted in an image \n602\n of a canvas of a markup language document \n604\n (e.g. HTML).', 'As is clear in \nFIG.', '6\nA\n, the text element \n600\n may be at an angle other than 0 degrees or 90 degrees.', 'For example, referring now to \nFIG.', '6\nB\n, the text element \n600\n may be oriented in a direction that is non-orthogonal to vertical (Y) and horizontal (X) axes of the image.', 'In some instances, the text element \n600\n to be highlighted may be identified by a user-initiated search of the document; and as such, there may be a plurality of text elements \n600\n to be highlighted.', 'Although \nFIGS.', '6\nA-\n6\nG\n only illustrate a single text element \n600\n, it is to be understood that the process illustrated in \nFIGS.', '6\nA-\n6\nG\n may be repeated for any number of text elements \n600\n to be highlighted.', 'FIG.', '6\nB\n illustrates various location data points that may be obtained regarding the text element \n600\n.', 'Generally, a bounding box \n605\n may be formed around the text element \n605\n defining a perimeter of the text.', 'In some instances, this bounding box \n605\n may then to be used to determine a number of other location-based data points.', 'For example, the length \n635\n and width \n640\n of the text element may be determined based on the perimeters of the bounding box \n605\n.', 'In another example, an X, Y coordinate of each corner (upper left \n610\n, upper right \n615\n, lower left \n620\n, and lower right \n625\n) of the bounding box \n605\n may be determined.', 'In such instances, these coordinates may be used to calculate a slope \n630\n of the text element \n600\n.', 'For example, the slope may be calculated as:\n \n \n \n \n \nslope\n \n=\n \n \n \n \n \n \n \nY\n \n\u2062\n \n \n \n \n\u2062\n \nCoordinate\n \n\u2062\n \n \n \n \n\u2062\n \nof\n \n\u2062\n \n \n \n \n\u2062\n \nUpper\n \n\u2062\n \n \n \n \n\u2062\n \nRight\n \n\u2062\n \n \n \n \n\u2062\n \n615\n \n \n-\n \n \n \n \n \n \n \nY\n \n\u2062\n \n \n \n \n\u2062\n \nCoordinate\n \n\u2062\n \n \n \n \n\u2062\n \nof\n \n\u2062\n \n \n \n \n\u2062\n \nUpper\n \n\u2062\n \n \n \n \n\u2062\n \nLeft\n \n\u2062\n \n \n \n \n\u2062\n \n610\n \n \n \n \n \n \n \n \n \n \nX\n \n\u2062\n \n \n \n \n\u2062\n \nCoordinate\n \n\u2062\n \n \n \n \n\u2062\n \nof\n \n\u2062\n \n \n \n \n\u2062\n \nUpper\n \n\u2062\n \n \n \n \n\u2062\n \nRight\n \n\u2062\n \n \n \n \n\u2062\n \n625\n \n \n-\n \n \n \n \n \n \n \nY\n \n\u2062\n \n \n \n \n\u2062\n \nCoordinate\n \n\u2062\n \n \n \n \n\u2062\n \nof\n \n\u2062\n \n \n \n \n\u2062\n \nUpper\n \n\u2062\n \n \n \n \n\u2062\n \nLeft\n \n\u2062\n \n \n \n \n\u2062\n \n620\n \n \n \n \n \n \n \n \n \n An angle of rotation of the text element may also then be determined (in radian) from the calculated slope by: \n Angle of Rotation (radian)=tan\n−1\n(slope)', 'In some instances, particularly where the X coordinate of upper right \n615\n corner is less than the X coordinate of upper left corner, it may be desirable to add π radian and then divide by 180 degrees when determining the angle of rotation in radian.', 'FIG.', '6\nC\n illustrates a schematic view of a context \n645\n created in the markup language document.', 'For example, in hypertext markup language 5 (HTML5) the pseudocode for generating a context may be “context=canvas.getContext‘2d’);” which provides a two-dimensional rendering context for a drawing surface of the canvas element.', 'Although HTML may be the markup language referenced herein, it is merely exemplary and not to be understood as limiting, as any markup language known in the art may be used.', 'For example, other markup languages may including, but not limited to, extensible hypertext markup language (XHTML), keyhole markup language (KML), scalable vector graphics (SVG), etc.', 'The context \n645\n of the canvas element may then be used for drawing various shapes, text, images, etc., including highlighting the text element \n600\n described herein.', 'Once the context \n645\n is created, the X, Y coordinates of the corners (upper left \n610\n, upper right \n615\n, lower left \n620\n, and lower right \n625\n) of the bounding box \n605\n may be used to determine a point at which the text element \n600\n starts, in relationship to the center of the canvas.', 'The X, Y coordinates of the corners (upper left \n610\n, upper right \n615\n, lower left \n620\n, and lower right \n625\n) of the bounding box \n605\n may also be used to determine a point at which the text element \n600\n starts, in relationship to the origin (e.g. the upper left) of the canvas.', 'FIGS.', '6\nD-\n6\nE\n illustrate what may be a multi-step process of moving the canvas to the starting point (e.g. the upper left corner \n610\n) of the text element \n600\n to be highlighted.', 'Specifically, \nFIG.', '6\nD\n illustrates rotating the canvas.', 'The angle of the rotation of the canvas may be identical to that of the angle of rotation identified using the slope \n630\n of the text element \n600\n, so that the plane of canvas aligns with the text element \n600\n.', 'For example, in HTML5 the pseudocode may be “context.rotate(radian measurement of angle of rotation);”. \nFIG.', '6\nE\n illustrates the translating the canvas, such that each point of the text element \n600\n may be moved in the same direction for the same distance.', 'In some instances, the translation may be so that the upper left corner \n650\n of the canvas aligns with the upper left corner \n610\n of the of text element \n600\n, as illustrated in \nFIG.', '6\nE\n.', 'As a non-limiting example, in HTML5 the pseudocode may be “context.translate (X, Y);” where X, Y represent the amount to be moved in each of the X-axis and the Y-axis.\n \nFIG.', '6\nF\n illustrates a text highlighting element \n655\n the text element \n600\n.', 'For example, in some instances, the translation described herein may orient the upper left corner \n650\n of the canvas in such a way that it aligns with the upper left corner \n610\n of the of text element \n600\n (as illustrated in \nFIG.', '6\nE\n)', ', this alignment allows the text highlighting element \n655\n to be added at an angle of 0 degrees or 90 degrees relative to the rotated and translated canvas.', 'As a non-limiting example, in HTML5 the pseudocode may be “context.fillStyle=‘rgba (255, 255, 0, 0.4)’; context.fillRect (0, 0, width height);”.', 'The text highlighting element \n655\n may be colored highlighting over the entirety of the text element \n600\n, as illustrated in \nFIG.', '6\nF\n, but this is not intended to be limiting.', 'In other instances, the highlighting may be in form of underling the text element \n600\n, crossing through the text element \n600\n, or any other marking known in the art.', 'FIG.', '6\nG\n illustrates restoring the context \n645\n to its original position, leaving the text element \n600\n in its original angled position with a text highlighting element \n660\n overlaying it.', 'While particular embodiments have been described, it is not intended that the invention be limited thereto, as it is intended that the invention be as broad in scope as the art will allow and that the specification be read likewise.', 'It will therefore be appreciated by those skilled in the art that yet other modifications could be made without deviating from its spirit and scope as claimed.']

['1.', 'A computer-implemented method for highlighting text in an image disposed in a markup language document, the method comprising:\nobtaining, by a processor, location data identifying a location, size and orientation of a text element in the image, wherein the text element is oriented in a direction that is non-orthogonal to vertical and horizontal axes of the image;\nobtaining, by the processor, a context for a canvas element in the document;\nrotating, by the processor, the context for the canvas element to align the context to the orientation of the text element using the location data;\ntranslating, by the processor, the context for the canvas element to the location of the text element using the location data; and\ngenerating, by the processor, a text highlighting element having a size that at least partially overlays the text element on the rotated and translated canvas using the location data.', '2.', 'The computer implemented method of claim 1 further including:\nsaving, by the processor, the context for the canvas element in the document, wherein the text element is oriented in the direction that is non-orthogonal to vertical and horizontal axes of the image; and\nclearing, by the processor, the context for the canvas element prior to rotating and translating the context for the canvas element.', '3.', 'The computer implemented method of claim 2 further including restoring, by the processor, the context of the canvas element such that the text element is reoriented in the direction that is non-orthogonal to vertical and horizontal axes of the image following the generation of the text highlighting.', '4.', 'The computer implemented method of claim 1, wherein the text element in the image is one of a plurality of text elements in the image and wherein first and second text elements of the plurality of text elements are oriented in first and second directions that are non-orthogonal to vertical and horizontal axes of the image.', '5.', 'The computer implemented method of claim 4 further comprising repeating the location data obtaining, the context obtaining, the rotating, the translating and the generating steps for each of the first and second text elements.', '6.', 'The computer implemented method of claim 1, wherein rotating the context for the canvas element to align the context to the orientation of the text element using the location data further includes determining, by the processor, an angle of the text element in the image using the location data.', '7.', 'The computer implemented method of claim 6, wherein the angle of the text element equals tan−1 (slope), wherein the slope equals: (a Y coordinate of a top right corner of a bounding box−a Y coordinate of a top left corner of the bounding box)/(an X coordinate of the top right corner of the bounding box−an X coordinate of the top left corner of the bounding box).', '8.', 'An apparatus, comprising:\nat least one processing unit; and\nprogram code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document including:\nobtaining location data identifying a location, size and orientation of a text element in the image, wherein the text element is oriented in a direction that is non-orthogonal to vertical and horizontal axes of the image;\nobtaining a context for a canvas element in the document;\nrotating the context for the canvas element to align the context to the orientation of the text element using the location data;\ntranslating the context for the canvas element to the location of the text element using the location data; and\ngenerating a text highlighting element having a size that at least partially overlays the text element on the rotated and translated canvas using the location data.', '9.', 'The apparatus of claim 8, wherein the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes:\nsaving the context for the canvas element in the document, wherein the text element is oriented in the direction that is non-orthogonal to vertical and horizontal axes of the image; and\nclearing the context for the canvas element prior to rotating and translating the context for the canvas element.', '10.', 'The apparatus of claim 8, wherein the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes restoring the context of the canvas element such that the text element is reoriented in the direction that is non-orthogonal to vertical and horizontal axes of the image following the generation of the text highlighting.', '11.', 'The apparatus of claim 8, wherein the text element in the image is one of a plurality of text elements in the image and wherein first and second text elements of the plurality of text elements are oriented in first and second directions that are non-orthogonal to vertical and horizontal axes of the image.', '12.', 'The apparatus of claim 11 wherein the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes repeating the location data obtaining, the context obtaining, the rotating, the translating and the generating steps for each of the first and second text elements.', '13.', 'The apparatus of claim 8, wherein rotating the context for the canvas element to align the context to the orientation of the text element using the location data further includes determining an angle of the text element in the image using the location data.', '14.', 'The apparatus of claim 13, wherein the angle of the text element equals tan−1 (slope), wherein the slope equals: (a Y coordinate of a top right corner of a bounding box−a Y coordinate of a top left corner of the bounding box)/(an X coordinate of the top right corner of the bounding box−an X coordinate of the top left corner of the bounding box).', '15.', 'A program product, comprising:\na computer readable medium; and\nprogram code stored on the computer readable medium and configured upon execution by at least one processing unit to highlight text in an image disposed in a markup language document including by: obtaining location data identifying a location, size and orientation of a text element in the image, wherein the text element is oriented in a direction that is non-orthogonal to vertical and horizontal axes of the image; obtaining a context for a canvas element in the document; rotating the context for the canvas element to align the context to the orientation of the text element using the location data; translating the context for the canvas element to the location of the text element using the location data; and generating a text highlighting element having a size that at least partially overlays the text element on the rotated and translated canvas using the location data.', '16.', 'The program product of claim 15, wherein the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes:\nsaving the context for the canvas element in the document, wherein the text element is oriented in the direction that is non-orthogonal to vertical and horizontal axes of the image; and\nclearing the context for the canvas element prior to rotating and translating the context for the canvas element.', '17.', 'The program product of claim 15, wherein the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes restoring the context of the canvas element such that the text element is reoriented in the direction that is non-orthogonal to vertical and horizontal axes of the image following the generation of the text highlighting.', '18.', 'The program product of claim 15, wherein the text element in the image is one of a plurality of text elements in the image and wherein first and second text elements of the plurality of text elements are oriented in first and second directions that are non-orthogonal to vertical and horizontal axes of the image.', '19.', 'The program product of claim 18, wherein the program code configured upon execution by the at least one processing unit to highlight text in an image disposed in a markup language document further includes repeating the location data obtaining, the context obtaining, the rotating, the translating and the generating steps for each of the first and second text elements.']

['FIG.', '1 is a block diagram of an example hardware and software environment for a data processing system in accordance with implementation of various technologies and techniques described herein.; FIGS.', '2A-2D illustrate simplified, schematic views of an oilfield having subterranean formations containing reservoirs therein in accordance with implementations of various technologies and techniques described herein.; FIG. 3 illustrates a schematic view, partially in cross section of an oilfield having a plurality of data acquisition tools positioned at various locations along the oilfield for collecting data from the subterranean formations in accordance with implementations of various technologies and techniques described herein.; FIG.', '4 illustrates a production system for performing one or more oilfield operations in accordance with implementations of various technologies and techniques described herein.; FIG.', '5 is a flowchart illustrating an example sequence of operations for highlighting text in an image disposed in a markup language document using the data processing system of FIG.', '1.; FIGS.', '6A-6G illustrate simplified, schematic views of an exemplary process of highlighting text in an image disposed in a markup language document.', 'FIG.', '6A is a schematic view of a text element to be highlighted.', 'FIG.', '6B is a schematic view of various location data obtained about the text element.', 'FIG.', '6C is a schematic view of the context of the canvas element.', 'FIG.', '6D is a schematic view of a rotated context of the canvas element.', 'FIG.', '6E is a schematic view of a translated context of the canvas element.', 'FIG.', '6F is a schematic view of the generated highlighted text element on the rotated and translated canvas.', 'FIG.', '6G is a schematic view of the restored context of the canvas element with the highlighted canvas element overlaying at least a part of the text element.; FIGS.', '2A-2D illustrate simplified, schematic views of an oilfield 100 having subterranean formation 102 containing reservoir 104 therein in accordance with implementations of various technologies and techniques described herein.', 'FIG.', '2A illustrates a survey operation being performed by a survey tool, such as seismic truck 106.1, to measure properties of the subterranean formation.', 'The survey operation is a seismic survey operation for producing sound vibrations.', 'In FIG.', '2A, one such sound vibration, sound vibration 112 generated by source 110, reflects off horizons 114 in earth formation 116.', "A set of sound vibrations is received by sensors, such as geophone-receivers 118, situated on the earth's surface.", 'The data received 120 is provided as input data to a computer 122.1 of a seismic truck 106.1, and responsive to the input data, computer 122.1 generates seismic data output 124.', 'This seismic data output may be stored, transmitted or further processed as desired, for example, by data reduction.;', 'FIG.', '2B illustrates a drilling operation being performed by drilling tools 106.2 suspended by rig 128 and advanced into subterranean formations 102 to form wellbore 136.', 'Mud pit 130 is used to draw drilling mud into the drilling tools via flow line 132 for circulating drilling mud down through the drilling tools, then up wellbore 136 and back to the surface.', 'The drilling mud may be filtered and returned to the mud pit.', 'A circulating system may be used for storing, controlling, or filtering the flowing drilling muds.', 'The drilling tools are advanced into subterranean formations 102 to reach reservoir 104.', 'Each well may target one or more reservoirs.', 'The drilling tools are adapted for measuring downhole properties using logging while drilling tools.', 'The logging while drilling tools may also be adapted for taking core sample 133 as shown.; FIG.', '2C illustrates a wireline operation being performed by wireline tool 106.3 suspended by rig 128 and into wellbore 136 of FIG.', '2B. Wireline tool 106.3 is adapted for deployment into wellbore 136 for generating well logs, performing downhole tests and/or collecting samples.', 'Wireline tool 106.3 may be used to provide another method and apparatus for performing a seismic survey operation.', 'Wireline tool 106.3 may, for example, have an explosive, radioactive, electrical, or acoustic energy source 144 that sends and/or receives electrical signals to surrounding subterranean formations 102 and fluids therein.;', 'FIG.', '2D illustrates a production operation being performed by production tool 106.4 deployed from a production unit or Christmas tree 129 and into completed wellbore 136 for drawing fluid from the downhole reservoirs into surface facilities 142.', 'The fluid flows from reservoir 104 through perforations in the casing (not shown) and into production tool 106.4 in wellbore 136 and to surface facilities 142 via gathering network 146.; FIG.', '3 illustrates a schematic view, partially in cross section of oilfield 200 having data acquisition tools 202.1, 202.2, 202.3 and 202.4 positioned at various locations along oilfield 200 for collecting data of subterranean formation 204 in accordance with implementations of various technologies and techniques described herein.', 'Data acquisition tools 202.1-202.4 may be the same as data acquisition tools 106.1-106.4 of FIGS.', '2A-2D, respectively, or others not depicted.', 'As shown, data acquisition tools 202.1-202.4 generate data plots or measurements 208.1-208.4, respectively.', 'These data plots are depicted along oilfield 200 to demonstrate the data generated by the various operations.', '; FIG.', '4 illustrates an oilfield 300 for performing production operations in accordance with implementations of various technologies and techniques described herein.', 'As shown, the oilfield has a plurality of wellsites 302 operatively connected to central processing facility 354.', 'The oilfield configuration of FIG.', '4 is not intended to limit the scope of the oilfield application system.', 'Part or all of the oilfield may be on land and/or sea.', 'Also, while a single oilfield with a single processing facility and a plurality of wellsites is depicted, any combination of one or more oilfields, one or more processing facilities and one or more wellsites may be present.; FIG.', '5 illustrates a flowchart of an example sequence of operations 500 for highlighting text in an image disposed in a markup language document using the data processing system of FIG.', '1.', 'In the illustrated embodiment, the markup language document is a Hypertext Markup Language (HTML)-compatible document and the container is defined by an HTML canvas element, although other containers may be used in other embodiments in order to properly orient highlighting on an arbitrarily oriented text element.', 'In addition, in the context of this disclosure, the text to be highlighted is referred to as a text element; however, the term text element is used to generically refer to one or more text characters that are represented in an image, and not to any specific markup language element or tag that may define text within a markup language document.; FIGS.', '6A-6G illustrate simplified, schematic views of an embodiment of a process described with reference to FIG.', '5 for highlighting text in an image.', 'For example, FIG.', '6A illustrates the text element 600 to be highlighted in an image 602 of a canvas of a markup language document 604 (e.g. HTML).', 'As is clear in FIG.', '6A, the text element 600 may be at an angle other than 0 degrees or 90 degrees.', 'For example, referring now to FIG.', '6B, the text element 600 may be oriented in a direction that is non-orthogonal to vertical (Y) and horizontal (X) axes of the image.', 'In some instances, the text element 600 to be highlighted may be identified by a user-initiated search of the document; and as such, there may be a plurality of text elements 600 to be highlighted.', 'Although FIGS.', '6A-6G only illustrate a single text element 600, it is to be understood that the process illustrated in FIGS.', '6A-6G may be repeated for any number of text elements 600 to be highlighted.', '; FIG.', '6B illustrates various location data points that may be obtained regarding the text element 600.', 'Generally, a bounding box 605 may be formed around the text element 605 defining a perimeter of the text.', 'In some instances, this bounding box 605 may then to be used to determine a number of other location-based data points.', 'For example, the length 635 and width 640 of the text element may be determined based on the perimeters of the bounding box 605.', 'In another example, an X, Y coordinate of each corner (upper left 610, upper right 615, lower left 620, and lower right 625) of the bounding box 605 may be determined.', 'In such instances, these coordinates may be used to calculate a slope 630 of the text element 600.', 'For example, the slope may be calculated as:; FIG.', '6C illustrates a schematic view of a context 645 created in the markup language document.', 'For example, in hypertext markup language 5 (HTML5) the pseudocode for generating a context may be “context=canvas.getContext‘2d’);” which provides a two-dimensional rendering context for a drawing surface of the canvas element.', 'Although HTML may be the markup language referenced herein, it is merely exemplary and not to be understood as limiting, as any markup language known in the art may be used.', 'For example, other markup languages may including, but not limited to, extensible hypertext markup language (XHTML), keyhole markup language (KML), scalable vector graphics (SVG), etc.; FIGS.', '6D-6E illustrate what may be a multi-step process of moving the canvas to the starting point (e.g. the upper left corner 610) of the text element 600 to be highlighted.', 'Specifically, FIG.', '6D illustrates rotating the canvas.', 'The angle of the rotation of the canvas may be identical to that of the angle of rotation identified using the slope 630 of the text element 600, so that the plane of canvas aligns with the text element 600.', 'For example, in HTML5 the pseudocode may be “context.rotate(radian measurement of angle of rotation);”.', 'FIG.', '6E illustrates the translating the canvas, such that each point of the text element 600 may be moved in the same direction for the same distance.', 'In some instances, the translation may be so that the upper left corner 650 of the canvas aligns with the upper left corner 610 of the of text element 600, as illustrated in FIG.', '6E.', 'As a non-limiting example, in HTML5 the pseudocode may be “context.translate (X, Y);” where X, Y represent the amount to be moved in each of the X-axis and the Y-axis.', '; FIG.', '6F illustrates a text highlighting element 655 the text element 600.', 'For example, in some instances, the translation described herein may orient the upper left corner 650 of the canvas in such a way that it aligns with the upper left corner 610 of the of text element 600 (as illustrated in FIG.', '6E), this alignment allows the text highlighting element 655 to be added at an angle of 0 degrees or 90 degrees relative to the rotated and translated canvas.', 'As a non-limiting example, in HTML5 the pseudocode may be “context.fillStyle=‘rgba (255, 255, 0, 0.4)’; context.fillRect (0, 0, width height);”.', 'The text highlighting element 655 may be colored highlighting over the entirety of the text element 600, as illustrated in FIG.', '6F, but this is not intended to be limiting.', 'In other instances, the highlighting may be in form of underling the text element 600, crossing through the text element 600, or any other marking known in the art.', 'FIG.', '6G illustrates restoring the context 645 to its original position, leaving the text element 600 in its original angled position with a text highlighting element 660 overlaying it.']

US11933127

System and method for controlled downhole chemical release

Oct 9, 2020

Richard Morrison, Sascha Trummer

SCHLUMBERGER TECHNOLOGY CORPORATION

International Preliminary Report on Patentability issued in International Patent application PCT/2020/07063, dated Apr. 21, 2022, 7 pages.; International Search Report and Written Opinion issued in International Patent applicationPCT/US2020/070637 dated Jan. 20, 2021, 10 pages.; Extended Search Report issued in European Patent Application No. 20875371.5 dated Aug. 8, 2023, 7 pages.; First Examination Report SA Application No. 522432227 dated Nov. 21, 2023; 16 pages (with English Translation).

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Foreign Citations not found.

['A technique facilitates precision fluid conveyance and placement to one or more desired locations in a borehole, e.g. a wellbore.', 'According to an embodiment, a material container, e.g. a fluid container, and/or a fluid flow path system may be deployed downhole via coiled tubing.', 'A release system is selectively actuatable to release a specific amount or amounts of material, e.g. treatment fluid, at the one or more desired locations along the borehole.', 'Depending on the application, various discharge mechanisms and/or supply mechanisms may be used in cooperation with the material container and/or fluid flow path system to provide the precision fluid conveyance and placement.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'The present document is a National Stage Entry of International Application No. PCT/US2020/070637, filed Oct. 9, 2020, which is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/914,116, filed Oct. 11, 2019, which is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nIn many well applications, coiled tubing equipment is used in well servicing and intervention operations.', 'Depending on the operation, a bottom hole assembly (BHA) and/or other tools may be attached to an end of the coiled tubing and deployed to an area or areas of interest in the well.', 'Coiled tubing equipment may comprise a continuous metal or composite tube deployable in a wellbore via a reel, an injector, and associated equipment located at the surface.', 'The overall coiled tubing system also may comprise other equipment for pumping fluid through the coiled tubing, for controlling various equipment, and for providing various manifold and pressure control.', 'Fluid may be pumped from the surface through the entire length of coiled tubing for treatment of the wellbore and/or to operate hydraulically powered downhole tools.', 'However, current systems are limited with respect to precision fluid conveyance and placement at desired locations in a borehole.', 'For example, use of traditional coiled tubing pumping techniques involves filling the entire volume of coiled tubing to displace fluid into the reservoir when overbalanced conditions exist.', 'Conversely, when underbalanced conditions exist, the treatment may suffer due to uncontrolled fluid loss from the coiled tubing to the reservoir via a u-tubing effect.', 'Thus, placement of a controlled and relatively small volume of fluid can be problematic.', 'For wireline and slick line applications, small quantities of fluid can sometimes be placed using a dump bailer.', 'However, dump bailers have very limited volume; are not easily conveyed into deviated, e.g. horizontal, well sections; and are not amenable to providing mixing with secondary fluid treatments due to a lack of pumping capacity.', 'Furthermore, reliance on gravity release limits the effectiveness of fluid placement in horizontal sections.', 'SUMMARY', 'In general, a system and methodology provide for precision fluid conveyance and placement to one or more desired locations in a borehole, e.g. a wellbore.', 'According to an embodiment, a material delivery system may comprise a material container and/or a fluid flow path system.', 'The material delivery system may be deployed downhole via coiled tubing.', 'A release system is selectively actuatable to release a specific amount or amounts of material, e.g. treatment fluid or other material, at the one or more desired locations along the borehole.', 'Depending on the application, various discharge mechanisms and/or supply mechanisms may be used in cooperation with the material container and/or fluid flow path system to provide the precision fluid conveyance and placement.', 'The precision fluid conveyance and placement may be initiated by, for example, sending a signal via a telemetric line from the surface to thus enable on-command precision fluid placement using coiled tubing.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is a schematic illustration of an example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure;\n \nFIG.', '2\n is a schematic illustration of another example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure;\n \nFIG.', '3\n is a schematic illustration of another example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure; and\n \nFIG.', '4\n is a schematic illustration of another example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'The disclosure herein generally involves a system and methodology for precision fluid conveyance and placement to one or more desired locations in a borehole, e.g. a wellbore.', 'The technique enables on-command precision fluid placement while using a coiled tubing system.', 'According to an embodiment, the technique employs a material delivery system which may comprise a material container and/or a fluid flow path system which are deployed downhole via coiled tubing.', 'A release system is selectively actuatable to release a specific amount or amounts of fluid, e.g. treatment fluid, at the one or more desired locations along the borehole.', 'Depending on the application, various discharge mechanisms and/or supply mechanisms may be used in cooperation with the material container and/or fluid flow path system to provide the precision fluid conveyance and placement.', 'Actuation of the release system and/or discharge mechanism may be initiated by, for example, sending a signal via a telemetric line from the surface to thus enable precision fluid placement using coiled tubing.', 'In some embodiments, the equipment for providing the precision fluid placement may be located in a bottom hole assembly (BHA) deployed downhole via the coiled tubing.', 'In such a system, a signal may be sent via a wired or wireless telemetric line from the surface to the BHA.', 'The signal is used to trigger release of a controlled amount of material, e.g. cement slurry or other treatment fluid.', 'The controlled release of fluid may be done “on-command” when real-time telemetry is present or on a delay.', 'Furthermore, the signal may be carried from the surface via a physical telemetric line, e.g. a telemetric line routed along the interior of the coiled tubing or within a wall of the coiled tubing.', 'In some embodiments, a complementary fluid or fluid mixture may be pumped down through the coiled tubing for downhole combination with a secondary material.', 'For example, the BHA may be constructed to enable initiation of a controlled release of the secondary material on-command to act with or mix with the pumped fluid to form a desired treatment fluid.', 'Referring generally to \nFIG.', '1\n, an example of a well system \n30\n able to provide precision fluid conveyance and placement along a borehole is illustrated.', 'In this example, well system \n30\n comprises a well string \n31\n.', 'The well string \n31\n includes well equipment \n32\n deployed downhole into a borehole \n34\n, e.g. a wellbore, via coiled tubing \n36\n.', 'The well equipment \n32\n may comprise various types and combinations of equipment and may be in the form of a bottom hole assembly (BHA) \n38\n.', 'Additionally, the well equipment \n32\n comprises a material delivery system \n39\n for precisely placing relatively small quantities of a material \n40\n, e.g. cement slurry, treatment chemicals, and/or other materials, at a desired location or locations downhole.', 'According to the embodiment illustrated, the material delivery system \n39\n may employ a prefilled volume of material \n40\n placed in a container, e.g. a fluid chamber, \n42\n which may be part of BHA \n38\n (or other suitable downhole equipment).', 'The container \n42\n may be constructed as a fit-for-purpose material chamber for containing desired material \n40\n which may be in the form of fluids and/or other materials.', 'Additionally, container \n42\n may be formed of various metal materials or non-metal materials, e.g. polytetrafluoroethylene (PTFE).', 'The material \n40\n is contained in container \n42\n via a release system \n44\n which may comprise an actuatable valve \n46\n or other suitable release mechanism.', 'The actuatable valve \n46\n may be located at a downhole end of container \n42\n or at another suitable position.', 'In the illustrated example, the release system \n44\n is actuated in response to a signal sent from, for example, the surface.', 'The signal may be sent over a suitable wireless or wired telemetric line \n48\n coupled with a control system \n50\n, e.g. a surface control system.', 'By way of example, the telemetric line \n48\n may be a physical line routed from the surface down through an interior of the coiled tubing \n36\n to a downhole receiver \n52\n.', 'However, the telemetric line \n48\n may be routed along other paths, e.g. within a wall of the coiled tubing \n36\n.', 'In some embodiments, the telemetric line \n48\n may be wireless in whole or in part.', 'The downhole receiver \n52\n may be located within BHA \n38\n or within other suitable equipment and may be coupled with release system \n44\n via a release command signal control line \n54\n.', 'The control line \n54\n may be an electric control line, hydraulic control line, or other suitable control line selected to operate the corresponding release system \n44\n.', 'In operation, the prefilled container \n42\n is conveyed downhole to a desired location at a target depth to enable an on-command release of the material \n40\n.', 'For example, a signal may be sent from surface control system \n50\n via telemetric line \n48\n.', 'The signal is received by the downhole receiver \n52\n which commands the release system \n44\n, e.g. an actuator of the release system \n44\n, to actuate and thus release material \n40\n from the prefilled container \n42\n and into the borehole \n34\n.', 'A metered quantity of the material \n40\n or the entire volume of material \n40\n may be selectively released.', 'In some embodiments, the container \n42\n may comprise a plurality of individual fluid chambers \n56\n or other material chambers.', 'The chambers \n56\n work in cooperation with corresponding release valves \n46\n or other release mechanisms to enable selective, e.g. sequential, release of similar or dissimilar materials \n40\n from the plurality of containers \n56\n.', 'Referring generally to \nFIG.', '2\n, another embodiment of material delivery system \n39\n is illustrated as having a discharge mechanism \n58\n which works in cooperation with release system \n44\n.', 'By way of example, the discharge mechanism \n58\n may be a forcing mechanism which may be automated or actuated via suitable signals sent via telemetric line \n48\n.', 'In some embodiments, the discharge mechanism \n58\n may comprise a piston \n60\n selectively shiftable along the interior of container \n42\n to forcibly discharge a predetermined quantity of material \n40\n into the surrounding borehole \n34\n at a desired location.', 'For example, release system \n44\n may comprise a burst disc which bursts once sufficient force is applied via piston \n60\n so that piston \n60\n may then be shifted to discharge the desired material \n40\n from container \n42\n.', 'In another embodiment of material delivery system \n39\n, material \n40\n may comprise a fluid contained along a flow path \n62\n located within BHA \n38\n and closed off by release system \n44\n, as illustrated in \nFIG.', '3\n.', 'The flow path \n62\n may extend up to and, in some applications, may include at least a portion of the coiled tubing \n36\n to provide the desired quantity of fluid/material \n40\n for placement at the desired location along borehole \n34\n.', 'Embodiments of material delivery system \n39\n may comprise various combinations of containers \n42\n, flow paths \n62\n, telemetric lines \n48\n, and/or other system components.', 'As illustrated in \nFIG.', '4\n, for example, the BHA \n38\n comprises container \n42\n (which may have one or more chambers \n56\n) for containing desired materials \n40\n.', 'Additionally, the BHA \n38\n comprises separate flow path \n62\n along which material \n40\n may be contained or along which a complementary fluid may be pumped.', 'The flow path \n62\n may have a corresponding fluid exit \n64\n combined with another release system \n44\n through which fluids may be discharged via, for example, the pressure of fluid pumped down through coiled tubing \n36\n.', 'The materials \n40\n within container \n42\n and/or disposed along flow path \n62\n may be independently delivered and placed at a desired location or locations in borehole \n34\n.', 'The material \n40\n may be discharged at the desired location via gravity or via an actuator, e.g. piston \n60\n.', 'In some embodiments, a complementary fluid or fluid mixture may be pumped down through coiled tubing \n36\n and flow path \n62\n for discharge through fluid exit \n64\n.', 'This complementary fluid may be mixed with a secondary chemical/material \n40\n selectively released from container \n42\n to set off a desired chemical reaction.', 'Depending on the application, the chemical/material \n40\n may be released into the complementary fluid/mixture or the chemical/material \n40\n may be released first and the complementary fluid/mixture may then be pumped down on top of the chemical/material \n40\n.', 'Embodiments described herein enable on-command downhole release of desired materials.', 'For example, an operator can pre-fill a container \n42\n and/or flow path \n62\n (which may include at least a portion of coiled tubing \n36\n) with a predetermined volume of at least one material \n40\n, e.g. a fluid treatment material.', 'The material (or materials) \n40\n is then conveyed downhole via coiled tubing \n36\n to a target location within the borehole/wellbore \n34\n.', 'Once at the desired location and at target depth, the material \n40\n is selectively released.', 'Using on-command downhole release of a desired chemical/material \n40\n enables operators to pump downhole a sufficient volume of a first chemical and then use a different material/chemical \n40\n of smaller volume for activation.', 'The smaller volume of chemical \n40\n may be contained within container \n42\n (and/or sometimes flow path \n62\n) and then selectively released into the first chemical, according to methods described herein.', 'Controlled release of the smaller volume of chemical \n40\n creates a desired chemical reaction at target depth.', 'This can produce an improved chemical reaction at the desired location as opposed to co-mingling the chemicals in pumping equipment and/or within the coiled tubing.', 'Examples of reactions include exothermic reactions so that changes may be sensed using, for example, a distributed temperature sensing system.', 'Additional examples of reactions include solidifying reactions to intentionally create obstructions.', 'However, a variety of other reactions may be initiated downhole via the controlled placement and release of a desired chemical from, for example, container \n42\n.', 'Furthermore, use of discharge mechanism \n58\n, e.g. piston \n60\n, and/or pumped pressure on top of a prefilled volume of fluid along the flow path \n62\n/coiled tubing \n36\n enables forced release of desired materials \n40\n.', 'This approach can effectively create a different type of dump bailer for small volumes of material \n40\n, e.g. cement slurry, for placement in horizontal or otherwise deviated sections of the borehole \n34\n where the force of gravity acts transversely with respect to BHA \n38\n.', 'It should be noted the configuration of well system \n30\n may change according to the parameters of a given operation and environment.', 'Well system \n30\n may comprise various types of well strings \n31\n which have suitable equipment \n32\n constructed as bottom hole assembly \n38\n and/or as other types of equipment located along the coiled tubing \n36\n.', 'Similarly, various containers \n42\n, flow paths \n62\n, release systems \n44\n, discharge mechanisms \n58\n, downhole receivers \n52\n, telemetry systems, and/or other systems and components may be selected according to objectives and environmental considerations of a given operation.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A system for use in a well, comprising:\na well string having well equipment coupled to coiled tubing for deployment downhole into a borehole, the well equipment including a material delivery system configured to release material into the borehole, wherein the material delivery system comprises a flow path system configured to receive a fluid, different from the material, from the coiled tubing and to release the fluid into the borehole before, after, or while the material delivery system releases the material into the borehole such that the fluid mixes with the material in the borehole, wherein mixing of the fluid and the material within the borehole causes a chemical reaction;\na control system positioned at a surface location; and\na telemetric line coupling the control system with the material delivery system, the control system being configured to provide signals to the material delivery system to initiate the release of a metered amount of the material at a desired location along the borehole.', '2.', 'The system as recited in claim 1, wherein the well equipment comprises a bottom hole assembly (BHA).', '3.', 'The system as recited in claim 1, wherein the material delivery system comprises a material container configured to hold a volume of the material and a release system actuatable to selectively release the metered amount of the material.', '4.', 'The system as recited in claim 3, wherein the release system comprises an actuatable valve disposed at a distal end of a downhole end of the material container.', '5.', 'The system as recited in claim 3, wherein the material container comprises a plurality of separate fluid chambers.', '6.', 'The system as recited in claim 3, wherein the material delivery system further comprises a discharge mechanism which cooperates with the material container to force discharge of the metered amount of the material.', '7.', 'The system as recited in claim 6, wherein the discharge mechanism comprises an actuatable piston.', '8.', 'The system as recited in claim 3, wherein the material delivery system further comprises a downhole receiver, the telemetric line being coupled between the control system and the downhole receiver, the downhole receiver being connected to the release system via a control line.', '9.', 'The system as recited in claim 3, wherein the release system comprises a burst disc configured to burst in response to an applied force and release the metered amount of the material.', '10.', 'The system as recited in claim 3, wherein the metered amount of the material comprises an entirety of the volume of the material of the material container.', '11.', 'The system as recited in claim 1, wherein the material delivery system comprises a fluid flow path system configured to receive the material from the coiled tubing and release the metered amount of the material into the borehole.', '12.', 'The system as recited in claim 1, wherein the telemetric line comprises a wired telemetric line disposed along an interior of the coiled tubing or within a sidewall of the coiled tubing.', '13.', 'A system for use in a well, comprising:\na coiled tubing;\na material delivery system coupled to the coiled tubing for deployment downhole into a borehole, the material delivery system comprising: a container configured to hold a volume of a first material; a release mechanism configured to selectively release at least a portion of the first material from the container and into the borehole; and a flow path fluidly coupled to the coiled tubing and configured to receive a second material via the coiled tubing and to release the second material into the borehole; and\na control system configured to independently regulate the release of the first material into the borehole and the release of the second material into the borehole.', '14.', 'The system as recited in claim 13, wherein the container comprises a plurality of fluid chambers configured to hold a plurality of respective fluids, wherein the first material comprises a respective fluid of the plurality of respective fluids.', '15.', 'The system as recited in claim 13, wherein the release mechanism comprises an actuatable valve.', '16.', 'The system as recited in claim 13, wherein the material delivery system further comprises a discharge mechanism for forcing discharge of the first material from the container.', '17.', 'The system as recited in claim 13, wherein the flow path comprises a second release mechanism configured to selectively release at least a portion of the second material into the borehole.', '18.', 'A method, comprising:\nconveying a material delivery system into a borehole via coiled tubing, the material delivery system comprising: a container configured to hold a volume of a first material; a first release mechanism configured to release at least a portion of the volume of the first material from the container and into the borehole; and a second release mechanism fluidly coupled to the coiled tubing and configured to receive a second material from the coiled tubing and to release the second material into the borehole; and\nindependently actuating the first release mechanism, the second release mechanism, or both, to respectively release the first material, the second material, or both into the borehole.', '19.', 'The method as recited in claim 18, wherein actuating the first release mechanism comprises opening a valve.', '20.', 'The method as recited in claim 18, wherein independently actuating the first release mechanism, the second release mechanism, or both comprises independently actuating the first release mechanism, and wherein the method further comprises, during actuating of the first release mechanism, actuating a discharge mechanism to forcibly discharge the first material from the container and into the borehole.']

['FIG.', '1 is a schematic illustration of an example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure;; FIG.', '2 is a schematic illustration of another example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure;; FIG.', '3 is a schematic illustration of another example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure; and; FIG.', '4 is a schematic illustration of another example of a downhole fluid conveyance and placement system, according to an embodiment of the disclosure.']

USD1016958

Shaped charge frame

Sep 11, 2020

Andrew Prisbell, Todd Busch, Atsushi Nakano, Erick Lowe

SCHLUMBERGER TECHNOLOGY CORPORATION

“Stimulation-Optimized Shaped Charges” [online]. slb.com. [Retrieved on Oct. 2, 2023]. Retrieved from the Internet: <https://www.slb.com/products-and-services/innovating-in-oil-and-gas/completions/well-completions/perforating/perforating-guns-and-charges/stimulation-optimized-shaped-charges>.; “Shaped Charges, engineered for your rock” [online]. JRC designs. [Retrieved on Oct. 2, 2023]. Retrieved from the Internet: <https://www.jetresearch.com/en/energetics/shaped-charges>.; Extended Search issued in European Patent Application No. 20752538.7 dated Sep. 30, 2022, 8 pages.; Advisory Action issued in U.S. Appl. No. 14/888,882 dated Sep. 21, 2021, 6 pages.; Communication article 94-3 issued in the related EP application 13860417.8, dated Jan. 19, 2018 (5 pages).; Communication article 94-3 issued in the related EP application 13860417.8, dated Mar. 8, 2017 (6 pages).; Communication article 94-3 issued in the related EP application 13860417.8, dated Mar. 9, 2016 (6 pages).; Decision of Grant issued in the related RU application 2015126872, dated Dec. 1, 2016 (12 pages).; English translation of Exam Report issued in the related AR Patent Application No. 20140101829, dated Aug. 30, 2021, 2 pages.; European Search Report issued in the related EP application 13860417.8, dated Feb. 22, 2016 (6 pages).; Exam Report issued in the related AR Patent Application No. 20140101829 dated Apr. 16, 2020, 5 pages.; Exam Report issued in the related CA Application 2892378 dated Nov. 15, 2019, 4 pages.; H-2 Perforating System, Titan division, 2019 (1 page).; International Preliminary Report on Patentability issued in the PCT Application PCT/US2020/017262 dated Aug. 19, 2021, 11 pages.; International Preliminary Report on Patentability issued in the PCT Application PCT/US2020/032879 dated Nov. 25, 2021, 8 pages.; International Preliminary Report on Patentability issued in the related PCT application PCT/US2013/073094, dated Jun. 9, 2015 (5 pages).; International Preliminary Report on Patentability issued in the related PCT application PCT/US2014/036541, dated Nov. 3, 2015 (09 pages).; International Search Report and Written Opinion issued in the PCT Application PCT/US2020/017262 dated Jun. 19, 2020, 13 pages.; International Search Report and Written Opinion issued in the PCT Application PCT/US2020/032879, dated Aug. 28, 2020 (10 pages).; International Search Report and Written Opinion issued in the related PCT application PCT/US2013/073094, dated Mar. 20, 2014 (9 pages).; International Search Report and Written Opinion issued in the related PCT application PCT/US2014/036541, dated Sep. 12, 2014 (13 pages).; Merriam-Webster Dictionary, multiple various definitions for the term “bulkhead”, published in Jan. 2013. (Year: 2013).; Notice of Allowance issued in U.S. Appl. No. 16/021,061 dated Aug. 11, 2021, 8 pages.; Office action issued in the related CN application 201380062953.4, dated Feb. 27, 2018 (11 pages).; Office action issued in the related CN application 201380062953.4, dated Jun. 15, 2017 (20 pages).; Office action issued in the related CN application 201380062953.4, dated Sep. 1, 2016 (22 pages).; Office action issued in the related RU application 2015126872, dated Aug. 19, 2016 (8 pages).; Office Action issued in the related U.S. Appl. No. 14/888,882 dated Dec. 3, 2021, 16 pages.; Office Action issued in the related U.S. Appl. No. 14/888,882 dated Apr. 13, 2021, 16 pages.; Office Action issued in the related U.S. Appl. No. 14/888,882 dated Jan. 30, 2020, 26 pages.; Office Action issued in the related U.S. Appl. No. 14/888,882 dated May 25, 2018 (36 pages).; Office Action issued in the related U.S. Appl. No. 16/021,061 dated Sep. 9, 2020, 11 pages.; Titan H2 Perforating Gun System, (2019) 2 pages, Link: https://www.oilfieldtechnology.com/product-news/07022019/hunting-introduces-h-2-perforating-system/.; Office Action issued in U.S. Appl. No. 17/235,616 dated Mar. 16, 2022, 8 pages.; International Search Report and Written Opinion issued in the PCT Application No. PCT/US/2021/059401 dated Feb. 24, 2022, 11 pages.; International Preliminary Report on Patentability issued in the PCT Application PCT/US2021/059401 dated May 25, 2023, 8 pages.; Hunting introduces H-2 Perforating System, downloaded from https://www.oilfieldtechnology.com/product-news/07022019/hunting-introduces-h-2-perforating-system/, Oilfield Technology, Feb. 7, 2019, 2 pages.; GEODynamics, Hellfire perforating system, 2019, 2 pages.; International Search Report and Written Opinion issued in the PCT Application No. PCT/US2021/059400 dated Feb. 24, 2022, 8 pages.; International Preliminary Report on Patentability issued in the PCT Application No. PCT/US2021/059400 dated May 25, 2023, 7 pages.

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['No Abstract Available']

['Description\n\n\n\n\n\n\n \nFIG.', '1\n is an isometric view of the first embodiment of a shaped charge frame at a first top angle;\n \nFIG.', '2\n is an isometric view of the shaped charge frame of \nFIG.', '1\n at a second top angle;\n \nFIG.', '3\n is an isometric view of the shaped charge frame of \nFIG.', '1\n at a third top angle;\n \nFIG.', '4\n is an isometric view of the shaped charge frame of \nFIG.', '1\n at a first bottom angle;\n \nFIG.', '5\n is an isometric view of the shaped charge frame of \nFIG.', '1\n at a second bottom angle;\n \nFIG.', '6\n is an isometric view of the shaped charge frame of \nFIG.', '1\n at a third bottom angle;\n \nFIG.', '7\n is a side view of the shaped charge frame of \nFIG.', '1\n at a first angle;\n \nFIG.', '8\n is a side view of the shaped charge frame of \nFIG.', '1\n at a second angle;\n \nFIG.', '9\n a side view of the shaped charge frame of \nFIG.', '1\n at a third angle;\n \nFIG.', '10\n is a side view of the shaped charge frame of \nFIG.', '1\n at a fourth angle;\n \nFIG.', '11\n is a top view of the shaped charge frame of \nFIG.', '1\n;\n \nFIG.', '12\n is a bottom view of the shaped charge frame of \nFIG.', '1\n;\n \nFIG.', '13\n is a cross-sectional view of the shaped charge frame of \nFIG.', '7\n taken along section line \n13\n; and\n \nFIG.', '14\n is a cross-sectional view of the shaped charge frame of \nFIG.', '7\n taken along section line \n14\n.\n \nFIG.', '15\n is a cross-sectional view of the second embodiment of a shaped charge frame along the first longitudinal section;\n \nFIG.', '16\n is an isometric view of the shaped charge frame of \nFIG.', '15\n at a first top angle;\n \nFIG.', '17\n is an isometric view of the shaped charge frame of \nFIG.', '15\n at a second top angle;\n \nFIG.', '18\n is an isometric view of the shaped charge frame of \nFIG.', '15\n at a first bottom angle;\n \nFIG.', '19\n is an isometric view of the shaped charge frame of \nFIG.', '15\n at a second bottom angle;\n \nFIG.', '20\n is a side view of the shaped charge frame of \nFIG.', '15\n at a first angle;\n \nFIG.', '21\n is a side view of the shaped charge frame of \nFIG.', '15\n at a second angle;\n \nFIG.', '22\n is a side view of the shaped charge frame of \nFIG.', '15\n at a third angle;\n \nFIG.', '23\n is a side view of the shaped charge frame of \nFIG.', '15\n at a fourth angle;\n \nFIG.', '24\n is a top view of the shaped charge frame of \nFIG.', '15\n;\n \nFIG.', '25\n is a bottom view of the shaped charge frame of \nFIG.', '15\n;\n \nFIG.', '26\n is a cross-sectional view of the shaped charge frame of \nFIG.', '15\n along a lateral section; and,\n \nFIG.', '27\n is a cross-sectional view of the shaped charge frame of \nFIG.', '15\n along a second longitudinal section.', 'The broken lines in the drawings show environmental structure and form no part of the claimed design.']

['The ornamental design for a shaped charge frame, as shown and described.']

['FIG.', '1 is an isometric view of the first embodiment of a shaped charge frame at a first top angle;; FIG.', '2 is an isometric view of the shaped charge frame of FIG.', '1 at a second top angle;; FIG. 3 is an isometric view of the shaped charge frame of FIG.', '1 at a third top angle;; FIG. 4 is an isometric view of the shaped charge frame of FIG.', '1 at a first bottom angle;; FIG. 5 is an isometric view of the shaped charge frame of FIG.', '1 at a second bottom angle;; FIG.', '6 is an isometric view of the shaped charge frame of FIG.', '1 at a third bottom angle;; FIG. 7 is a side view of the shaped charge frame of FIG.', '1 at a first angle;; FIG.', '8 is a side view of the shaped charge frame of FIG.', '1 at a second angle;; FIG.', '9 a side view of the shaped charge frame of FIG.', '1 at a third angle;; FIG.', '10 is a side view of the shaped charge frame of FIG.', '1 at a fourth angle;; FIG.', '11 is a top view of the shaped charge frame of FIG.', '1;; FIG.', '12 is a bottom view of the shaped charge frame of FIG.', '1;; FIG. 13 is a cross-sectional view of the shaped charge frame of FIG.', '7 taken along section line 13; and; FIG.', '14 is a cross-sectional view of the shaped charge frame of FIG.', '7 taken along section line 14.; FIG.', '15 is a cross-sectional view of the second embodiment of a shaped charge frame along the first longitudinal section;; FIG.', '16 is an isometric view of the shaped charge frame of FIG.', '15 at a first top angle;; FIG.', '17 is an isometric view of the shaped charge frame of FIG.', '15 at a second top angle;; FIG.', '18 is an isometric view of the shaped charge frame of FIG.', '15 at a first bottom angle;; FIG.', '19 is an isometric view of the shaped charge frame of FIG.', '15 at a second bottom angle;; FIG.', '20 is a side view of the shaped charge frame of FIG.', '15 at a first angle;; FIG.', '21 is a side view of the shaped charge frame of FIG.', '15 at a second angle;; FIG.', '22 is a side view of the shaped charge frame of FIG.', '15 at a third angle;; FIG.', '23 is a side view of the shaped charge frame of FIG.', '15 at a fourth angle;; FIG.', '24 is a top view of the shaped charge frame of FIG.', '15;; FIG.', '25 is a bottom view of the shaped charge frame of FIG.', '15;; FIG.', '26 is a cross-sectional view of the shaped charge frame of FIG.', '15 along a lateral section; and,; FIG.', '27 is a cross-sectional view of the shaped charge frame of FIG.', '15 along a second longitudinal section.']

US11933133

Combined actuation of slips and packer sealing element

Oct 20, 2020

Farhan Ahmed Omer, Susan Wu, Thomas Eric Dudley, Yiming Fan, Weiming Lan, Nitin Verroju

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in PCT Application PCT/US2020/056406 dated Feb. 1, 2021 (12 pages).; Examination report issued in GC application GC2020-40690, dated Nov. 30, 2021 (6 pages).; Exam Report issued Under Section 18(3) issued in United Kingdom Patent Application No. GB2205702.0 dated Feb. 20, 2023, 4 pages.

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2308138; June 1997; GB; 158674; January 2016; RU; 2674781; December 2018; RU

['A technique facilitates actuation of a packer to a sealing and gripping position along a borehole.', 'The packer includes a packer element structure mounted about a center structure.', 'The packer element structure includes a sealing element mounted along an expandable base such that the sealing element may be radially expanded.', 'Additionally, the packer includes an actuator member connected to a portion of the packer element structure via a release mechanism, e.g. a shear member.', 'A plurality of slips may be located on the actuator member such that linear movement of the actuator member causes successive movement of the packer sealing element and then the slips in the radially outward direction.', 'The packer may be constructed such that this sequential setting motion creates a jarring effect to ensure the slips securely bite into the surrounding wellbore surface, e.g. casing surface.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThe present document is the National Stage of International Application No. PCT/US2020/056406, filed Oct. 20, 2020, and is based on and claims priority to U.S. Provisional Patent Application Ser.', 'No. 62/923,575, filed Oct. 20, 2019, and U.S. Provisional Patent Application Ser.', 'No. 63/051,019, filed Jul. 13, 2020, which are incorporated herein by reference in their entirety.', 'BACKGROUND\n \nIn many well applications, packers are used along a well string to seal off sections of a borehole.', 'Generally, a packer comprises a sealing element which may be expanded in a radially outward direction to form a seal between a central packer mandrel and a surrounding borehole surface, e.g. an interior casing surface.', 'The packer also may comprise or work in cooperation with slips which have gripping members oriented to engage the surrounding borehole surface.', 'The slips also may be expanded in a radially outward direction until forced into gripping engagement with the surrounding borehole surface so as to securely position the packer at a desired location along the borehole.', 'SUMMARY', 'In general, a system and methodology are provided for enabling a packer to be actuated to a sealing and gripping position along a borehole.', 'The packer may be positioned along a variety of well strings and may include a center structure, e.g. mandrel, having a passage therethrough.', 'A packer element structure is mounted about the center structure and includes a sealing element mounted along an expandable base such that the sealing element may be radially expanded.', 'Additionally, the packer includes an actuator member connected to a portion of the packer element structure via a release mechanism, e.g. a shear member.', 'A plurality of slips may be located on the actuator member such that linear movement of the actuator member causes successive movement of the packer sealing element and then the slips in the radially outward direction.', 'The packer may be constructed such that this sequential setting motion creates a jarring effect to ensure the slips securely bite into the surrounding wellbore surface, e.g. casing surface.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is a schematic illustration of an example of a packer positioned along a well string located in a borehole, according to an embodiment of the disclosure;\n \nFIG.', '2\n is a cutaway view of another example of a packer positioned along a well string, according to an embodiment of the disclosure;\n \nFIG.', '3\n is a cross-sectional illustration of a portion of the packer illustrated in \nFIG.', '2\n, according to an embodiment of the disclosure;\n \nFIG.', '4\n is a cross-sectional illustration showing features of an example of a packer element structure, according to an embodiment of the disclosure;\n \nFIG.', '5\n is an illustration demonstrating actuation of the packer illustrated in \nFIGS.', '2\n and \n3\n, according to an embodiment of the disclosure;\n \nFIG.', '6\n shows a liner top packer system according to one or more embodiments of the present disclosure; and\n \nFIGS.', '7\n-\n8\n show comparative results of forces experienced by the liner top packer system during setting of the liner top packer.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'The disclosure herein generally involves a system and methodology for enabling a packer to be actuated to a sealing and gripping position along a borehole.', 'The packer is constructed to enable sequential actuation of the sealing element and then the slips via an actuation input, e.g. a mechanical actuation or a pressure input along the annulus and/or interior of the well string.', 'The packer may be positioned along a variety of well strings and may be located in many types of boreholes, e.g. vertical or deviated wellbores including cased wellbores.', 'According to an embodiment, the packer may comprise a center structure, e.g. a mandrel structure, having a passage therethrough.', 'A packer element structure is positioned about the center structure and includes a sealing element mounted along an expandable base such that the sealing element may be radially expanded.', 'The sealing element may be formed of a suitable elastomeric material, and the expandable base may comprise a plurality of metal base elements, which can be shifted in a radially outward direction.', 'Additionally, the packer comprises an actuator member connected to a portion of the packer element structure via a release mechanism, e.g., a shear member.', 'The shear member may comprise a tab or a plurality of tabs extending between the expandable base and the actuator member.', 'The shear member effectively provides a shearing mechanism on a radially expanding packer element structure formed of a seal element and a metal substrate to sequentially set the packer.', 'The sequential setting comprises setting the seal element first followed by shearing of the shear member, which then allows setting of the slips.', 'This sequential method creates a jarring effect, which ensures that engagement features, e.g. teeth, of the slips bite into the surrounding borehole surface or harder casing metallurgies.', 'Referring generally to \nFIG.', '1\n, an example of a well system \n30\n is illustrated.', 'In this embodiment, the well system \n30\n comprises a well string \n32\n including at least one packer \n34\n having a packer element structure \n36\n with a sealing element \n38\n.', 'The packer \n34\n also comprises a slip section \n40\n which may have a plurality of slips \n42\n.', 'In this example, the well string \n32\n is positioned in a borehole \n44\n, e.g. a wellbore, having a borehole surface \n46\n against which the packer \n34\n may be set.', 'In some applications, the wellbore \n44\n may be lined with a casing \n48\n and the borehole surface \n46\n may be an internal casing surface surrounding the packer \n34\n.', 'Referring generally to \nFIG.', '2\n, a packer \n34\n according to one or more embodiments of the present disclosure is shown.', 'As shown, the packer \n34\n has a center structure \n50\n having an outer surface \n54\n that includes a conical/sloped section \n56\n sloping in a radially outward direction with respect to a longitudinal axis \n58\n of the packer \n34\n.', 'In this example, the conical/sloped surface \n56\n of the center structure \n50\n is created by a cone \n88\n mounted along a mandrel \n90\n.', 'Cone \n88\n may be secured to mandrel \n90\n via various attachment mechanisms, such as fasteners \n92\n.', 'As also shown in \nFIG. \n2\n, the packer \n34\n also includes a packer element structure \n36\n having a packer sealing element \n38\n, which is expandable and mounted on an expandable base \n60\n (\nFIGS.', '3\n-\n4\n) positioned along the outer surface \n54\n of the center structure \n50\n.', 'The packer sealing element \n38\n may be formed of a suitable elastomeric material, for example.', 'Referring now to \nFIGS.', '2\n and \n3', ', the packer \n34\n may also include an actuator member \n62\n connected to the packer element structure \n36\n.', 'As shown in \nFIG.', '3\n, the actuator member \n62\n may be in the form of a push collet \n64\n in one or more embodiments of the present disclosure, for example.', 'As further shown in \nFIG.', '3\n, the actuator member \n62\n may be coupled to the expandable base \n60\n via a release mechanism \n66\n.', 'The release mechanism \n66\n may be in the form of a shear member \n68\n, e.g., at least one shear tab.', 'According to the illustrated embodiment of \nFIG.', '3\n, the shear member \n68\n may include at least one shear tab extending from the expandable base \n60\n into a corresponding recess \n70\n of the actuator member.', 'With further reference to \nFIG.', '2\n, it should be noted that one method of causing the linear actuation motion of actuator member \n62\n involves applying annulus pressure to a sealed pressure chamber via ports \n94\n.', 'The pressure is used to drive actuator member \n62\n linearly along mandrel \n90\n.', 'Still referring to \nFIGS.', '2\n and \n3\n, the packer \n34\n according to one or more embodiments of the present disclosure also includes a slip structure \n40\n having a plurality of slips \n42\n.', 'In one or more embodiments of the present disclosure, the slips \n42\n include engagement members \n76\n, e.g., teeth, constructed to securely engage a surrounding borehole surface \n46\n, e.g., an internal casing surface, when the slips \n42\n are radially expanded during setting of the packer \n34\n.', 'As shown in \nFIG. \n3\n, for example, the slips \n42\n and corresponding teeth \n76\n are located on the actuator member \n62\n, e.g., on push collet \n64\n, in one or more embodiments of the present disclosure.', 'Additionally, as shown in \nFIG.', '3\n, a portion of the expandable base \n60\n is provided with an outwardly sloped surface \n80\n, e.g., a conical surface.', 'In one or more embodiments of the present disclosure, the actuator member \n62\n may move linearly to set the packer sealing element \n38\n and to then shear the shear member \n68\n.', 'Once shear member \n68\n is sheared, continued linear movement of actuator member \n62\n forces radial expansion of slips \n42\n as they slide along outwardly sloped surface \n80\n of expandable base \n60\n.', 'More specifically, during a packer setting operation, the actuator member \n62\n is shifted linearly, e.g., in a direction toward packer sealing element \n38\n along axis \n58\n.', 'The shifting of actuator member \n62\n may be achieved via application of pressure along interior passage \n52\n and/or along the annulus between well string \n32\n and surrounding borehole surface \n46\n.', 'A variety of pressure piston actuation techniques and other pressure actuation techniques are known in the industry.', 'In some applications, however, the actuator member \n62\n may be constructed to be shifted mechanically.', 'The linear movement of the actuator member \n62\n causes linear/axial movement of the packer element structure \n36\n along sloped section \n56\n of outer surface \n54\n due to actuator member \n62\n being coupled to expandable base \n60\n via shear member \n68\n.', 'Because of the radially outward slope of section \n56\n, the expandable base \n60\n and the packer sealing element \n38\n are also forced in a radially outward direction until packer sealing element \n38\n is moved into sealing engagement with the surrounding borehole surface \n46\n.', 'As the packer sealing element \n38\n is forced into engagement with surface \n46\n, further linear movement is resisted.', 'Continued linear movement of actuator member \n62\n is then able to shear the shear member \n68\n so as to release the actuator member \n62\n from packer element structure \n36\n.', 'As a result, the actuator member \n62\n is able to slide along sloped surface \n80\n of expandable base \n60\n, which forces slips \n42\n in a radially outward direction until engagement members/teeth \n76\n are secured against/into the surrounding wall surface \n46\n.', 'The release due to the shearing of shear member \n68\n creates a jarring effect during setting of the slips \n42\n, which results in improved engagement of members/teeth \n76\n with the surrounding wall surface \n46\n.', 'Thus, the packer \n34\n is able to independently set the packer sealing element \n38\n followed by subsequent setting of slips \n42\n.', 'Still referring to \nFIG.', '3', ', the packer element structure \n36\n according to one or more embodiments of the present disclosure is in the form of a deflecting rib seal having ribs \n82\n.', 'Ribs \n82\n extend from a radially inward portion of expandable base \n60\n such that they are disposed in packer sealing element \n38\n.', 'The ribs \n82\n deflect during setting and when experiencing borehole pressure from either side, e.g., above or below, of the packer sealing element \n38\n.', 'The expandable base \n60\n and packer sealing element \n38\n combine to provide an expandable bonded seal, which energizes when pressure is applied.', 'Such a packer element structure \n36\n may be used in a variety of packers \n34\n including liner top packers.', 'In combination with deflecting ribs \n82\n, the packer element structure \n36\n may comprise additional ribs \n84\n, e.g. vertical ribs, extending outwardly into packer sealing element \n38\n.', 'In the illustrated example, the deflecting ribs \n82\n are on an upper and lower side of the additional ribs \n84\n.', 'For example, the lower deflecting rib \n82\n may be oriented in a generally outward and downward direction, and the upper deflecting rib \n82\n may be oriented in a generally outward and upward direction.', 'The centrally located ribs \n84\n may be oriented to project in a radially outward direction and serve to prevent the packer sealing element \n38\n from undue swaging and also serve as a hard stop which limits the amount of deflection of deflecting ribs \n82\n.', 'The deflecting ribs \n82\n deflect when the packer sealing element \n38\n is set in a sealing position against surrounding borehole surface \n46\n via application of force.', 'The deflection of the ribs \n82\n effectively stores setting energy when sealing element \n38\n is in the sealing position.', 'Advantageously, the deflecting rib seal design according to one or more embodiments of the present disclosure may only require about 50,000 lbf or less of a setting load, which is at least half of what is required in prior art seal assemblies.', 'In some embodiments, the elastomeric material of packer sealing element \n38\n may be shaped with a profile so that when pressure is applied the elastomer further pushes the deflected ribs \n82\n against the surrounding borehole surface \n46\n, e.g. surrounding casing surface.', 'This ensures the sealing action with the surrounding borehole surface \n46\n is robust.', 'The ribs \n82\n, \n84\n and packer sealing element \n38\n cooperate to provide a self-energizing seal.', 'For example, the deflecting ribs \n82\n help energize the packer sealing element \n38\n with applied pressure which forces the packer sealing element \n38\n into improved sealing with the surrounding borehole surface \n46\n.', 'Features such as deflecting ribs \n82\n also help energize the sealing action with applied annular pressure.', 'For example, when pressure is applied from either/both directions (see right side of \nFIG.', '5\n) the deflecting ribs \n82\n help energize sealing both on the outside diameter and the inside diameter of packer element structure \n36\n.', 'This energization helps sealing element \n38\n hold against increased annular pressures acting on packer \n34\n, e.g. pressures upwards of 15,000 psi.', 'In various applications, the deflecting ribs \n82\n may be angled upwardly and downwardly to deflect upon setting and to become further energized when pressure is applied from above or below.', 'In some embodiments, the expandable base \n60\n also may include internal metal bumps \n86\n oriented to form an improved metal-to-metal seal with the corresponding outer surface \n54\n of center structure \n50\n.', 'The internal metal bumps \n86\n create high contact pressure when the packer sealing element \n38\n is set against the surrounding borehole wall surface \n46\n.', 'Such a metal-to-metal seal provides a higher resistance to backlash.', 'When pressure is applied from either side of the packer \n34\n, for example, the deflecting ribs \n82\n and the metal bumps \n86\n help maintain the seal along the exterior and interior of the packer element structure \n36\n.', 'It should be noted that an inner seal \n78\n, e.g., an O-ring style seal, may be positioned between outer surface \n54\n and expandable base \n60\n, such as between internal metal bumps \n86\n, for example, to form a suitable seal along the interior of element structure.', 'According to an embodiment, the packer element structure \n36\n may be a swage type seal having expandable base \n60\n in the form of a metal substrate.', 'The metal substrate may comprise a ductile metal material, e.g. 8620 steel or other suitable ductile steel.', 'In this example, the packer sealing element \n38\n may be in the form of a suitable elastomer, e.g. HNBR, bonded to the metal expandable base \n60\n.', 'Depending on the parameters of a given application and/or environment, the materials and configurations selected for the expandable base \n60\n and packer sealing element \n38\n may be adjusted accordingly.', 'According to an example, slips \n42\n may be mounted to or integrally formed with the actuator member \n62\n, e.g. collet \n64\n, and positioned for sliding engagement with a secondary ramp created by sloped surface \n80\n of expandable base \n60\n (see \nFIG.', '3\n).', 'The secondary ramp/sloped surface \n80\n helps to energize slips \n42\n for improved slip bite when pressure is applied, e.g., applied on packer sealing element \n38\n.', 'This type of construction effectively provides a high hold down load capacity with a relatively compact slip length by enabling energization of the slips \n42\n when pressure is applied.', 'As further shown in \nFIG.', '4\n, it should be noted the packer element structure \n36\n may be similar to that described with reference to \nFIG.', '3\n, having deflecting ribs \n82\n, centrally located ribs \n84\n, packer sealing element \n38\n, and internal metal bumps \n86\n, and this type of construction reduces backlash to improve sealing pressure, as previously described.', 'For example, the configuration prevents backlash on the packer sealing element \n38\n when lower annulus pressure is applied and energizes the bite of slips \n42\n as pressure increases (see \nFIG. \n5\n).', 'Additionally, with reference to \nFIG.', '5\n, a higher ramp angle or compound ramp angle of secondary ramp/sloped surface \n80\n may be used to reduce radial loading experienced by the casing \n48\n and the mandrel \n90\n, thus providing higher hold down capacity.', 'In this example, the teeth \n76\n of slips \n42\n are fully supported by the secondary ramp/sloped surface \n80\n to help each tooth bite into the surrounding casing \n48\n.', 'Similar to other embodiments, the slips \n42\n are sequentially actuated using a shear sequence, as described above, so slips \n42\n become set after the packer sealing element \n38\n is fully set.', 'The shearing sequence can be used to achieve the desired jarring effect that ensures slips \n42\n bite into harder metallurgies associated with certain types of casing \n48\n.', 'It should be noted the packer \n34\n may be constructed in various sizes and configurations.', 'For example, the center structure \n50\n, packer element structure \n36\n, actuator member \n62\n, and slips \n42\n may have a variety of sizes and configurations.', 'In some embodiments, the slips \n42\n are formed as a unitary part of the actuator member \n62\n while in other embodiments the slips \n42\n are formed as a slip ring or other structure separate from actuator member \n62\n.', 'The packer element structure \n36\n may comprise various types of materials and configurations for forming packer sealing element \n38\n as well as expandable base \n60\n.', 'Additionally, various integral or separate components may be used in forming sloped surfaces \n56\n and/or \n80\n.', 'Referring now to \nFIG.', '6\n, a liner top packer system including a packer element \n36\n, a cone \n88\n, and a mandrel \n90\n, according to one or more embodiments of the present disclosure is shown.', 'In a typical liner top packer system, the entire packer element is disposed on the cone in the unset position.', 'This typical configuration reduces the cross section of the packer element as the inner diameter (ID) of the packer element is restricted by the outer diameter (OD) of the cone, and the OD of the packer element is restricted by the packer OD.', 'In contrast, in the liner top packer system according to one or more embodiments of the present disclosure, an undercut \n96\n is added to the mandrel \n90\n under the cone nose, which allows the packer element ID to be smaller than the cone nose and to be only restricted by the mandrel OD.', 'As further shown in \nFIG. \n6\n, the packer element \n36\n is partially off the cone \n88\n in the unset condition, which increases the cross-section of the packer element \n36\n.', 'Moreover, by adding an undercut \n96\n to the mandrel \n90\n, the packer element \n36\n is able to set over the cone \n88\n without hang-up.', 'This increased cross-section of the packer element \n36\n allows the packer OD to be reduced, and the bypass area of the packer to be increased.', 'The mandrel undercut \n96\n may adopt various shapes and configurations without departing from the scope of the present disclosure.', 'Referring now to \nFIGS.', '7\n and \n8\n, comparative results of forces experienced by the liner top packer system during setting of the liner top packer are shown.', 'Specifically, \nFIG.', '7\n shows the resulting forces experienced by a liner top packer system without a mandrel undercut, and \nFIG.', '8\n shows the resulting forces experienced by a liner top packer system having a mandrel undercut, according to one or more embodiments of the present disclosure.', 'As shown in \nFIG. \n7\n, without the mandrel undercut, there are excessively high forces for the packer element to pass over the edge of the nose cone, as evidenced by the peak load (circled), for example.', 'However, as a result of adding the mandrel undercut in accordance with one or more embodiments of the present disclosure, the peak load shown in \nFIG.', '7\n is eliminated in \nFIG.', '8\n.', 'Elimination of excessive load forces during setting of the liner top packer in this way is especially useful when there is a shear event to initiate the setting of the liner top packer, according to one or more embodiments of the present disclosure.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A system for use in a well, comprising:\na well string having a packer mounted along the well string, the packer comprising: a center structure having an outer surface sloping in a radially outward direction with respect to a longitudinal axis of the packer; a packer element structure having a sealing element mounted about an expandable base positioned along the outer surface of the center structure; an actuator member connected to a portion of the expandable base of the packer element structure via a shear member; and a plurality of slips located on the actuator member, wherein linear movement of the actuator member causes movement of the packer element structure in an axial direction along the outer surface such that the outer surface forces the expandable base and the sealing element to expand radially outward until the shear member is sheared, wherein further linear movement of the actuator member causes subsequent expansion of the plurality of slips in a radially outward direction.', '2.', 'The system as recited in claim 1, wherein the center structure comprises a mandrel having an internal passage therethrough, and wherein the outer surface of the center structure is a cone positioned about the mandrel.', '3.', 'The system as recited in claim 2, wherein the mandrel comprises an undercut.', '4.', 'The system as recited in claim 3, wherein the undercut on the mandrel is under a nose of the cone.', '5.', 'The system as recited in claim 2, wherein the packer element structure is partially off the cone in an unset position.', '6.', 'The system as recited in claim 1, wherein the sealing element of the packer element structure is elastomeric.', '7.', 'The system as recited in claim 6, wherein the expandable base of the packer element structure is formed of ductile metal.\n\n\n\n\n\n\n8.', 'The system as recited in claim 7, wherein the packer element structure comprises a plurality of deflecting ribs to facilitate self-energization of the sealing element.', '9.', 'The system as recited in claim 1, wherein the actuator member comprises a push collet.', '10.', 'The system as recited in claim 1, wherein the shear member comprises at least one shear tab extending from the expandable base into a recess of the actuator member.', '11.', 'The system as recited in claim 1, wherein the plurality of slips is positioned along a sloped surface of the expandable base, the sloped surface creating a secondary ramp which forces the plurality of slips in the radially outward direction during setting of the packer.', '12.', 'The system as recited in claim 1, further comprising a seal positioned between the packer element structure and the outer surface.', '13.', 'The system as recited in claim 1, wherein shearing of the shear member causes a jarring effect which helps set the plurality of slips.']

['FIG.', '1 is a schematic illustration of an example of a packer positioned along a well string located in a borehole, according to an embodiment of the disclosure;; FIG.', '2 is a cutaway view of another example of a packer positioned along a well string, according to an embodiment of the disclosure;; FIG.', '3 is a cross-sectional illustration of a portion of the packer illustrated in FIG.', '2, according to an embodiment of the disclosure;; FIG. 4 is a cross-sectional illustration showing features of an example of a packer element structure, according to an embodiment of the disclosure;; FIG.', '5 is an illustration demonstrating actuation of the packer illustrated in FIGS.', '2 and 3, according to an embodiment of the disclosure;', '; FIG.', '6 shows a liner top packer system according to one or more embodiments of the present disclosure; and; FIGS.', '7-8 show comparative results of forces experienced by the liner top packer system during setting of the liner top packer.']

US11920415

Indexing mechanisms

Apr 30, 2020

Josiah Dale Shearon, Juraj Irsa, Patrick Virene

SCHLUMBERGER TECHNOLOGY CORPORATION

International Preliminary Report on Patentability issued in International Patent application PCT/US2020/030813, dated Nov. 18, 2021, 9 pages.; International Search Report and Written Opinion issued in International Patent application PCT/US2020/030813 dated Aug. 11, 2020, 13 pages.

8863843; October 21, 2014; Wu et al.; 9598922; March 21, 2017; Beynon; 20040007356; January 15, 2004; Myron; 20100243253; September 30, 2010; Surjaatmadja; 20130025882; January 31, 2013; Streich; 20140318806; October 30, 2014; Machocki; 20160090815; March 31, 2016; Kennedy

2424417; July 2011; RU; 2478776; April 2013; RU; 174801; November 2017; RU

['An indexing mechanism includes a piston.', 'An indexing sleeve encases a portion of the piston.', 'The indexing mechanism is longitudinally fixed to the piston, and is rotatable relative to the piston.', 'The indexing sleeve includes an indexing track.', 'An indexing ring surrounds less than an entirety of the indexing sleeve.', 'The indexing ring is rotatable relative to the piston.', 'The indexing ring includes an indexing pin that extends into the indexing track.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is the U.S. national phase of International Patent Application No.', 'PCT/US2020/030813, filed Apr. 30, 2020, and entitled “Indexing Mechanisms,” which claims the benefit of, and priority to, U.S. Patent Application No. 62/842,562 filed on May 3, 2019, which is incorporated herein by this reference in its entirety.', 'BACKGROUND OF THE DISCLOSURE\n \nA wellbore may include sections uphole from the wellbore bottom that may need to be expanded, or structures that may need to be removed after installed.', 'These sections and structures may include plugs, casings, drill pipe, formation, and so forth.', 'A downhole tool may include radially expandable cutting structures that may remove material from a wellbore wall.', 'The radially expandable cutting structures may be actuated after the downhole tool has been tripped to a desired hole depth.', 'The radially expandable cutting structures may be hydraulically actuated by changing the hydraulic pressure or a fluid flow rate from the surface.', 'SUMMARY', 'In some embodiments, an indexing mechanism includes a piston.', 'An indexing sleeve encases a portion of the piston.', 'The indexing mechanism is longitudinally fixed to the piston, and is rotatable relative to the piston.', 'The indexing sleeve includes an indexing track.', 'An indexing ring surrounds less than an entirety of the indexing sleeve.', 'The indexing ring is rotatable relative to the piston.', 'The indexing ring includes one or more indexing pins that extend into the indexing track.', 'In other embodiments, an indexing mechanism includes a piston.', 'An indexing sleeve encases a portion of the piston.', 'An indexing ring surrounds a portion of the indexing sleeve.', 'The indexing ring includes a ring stop and one or more indexing pins.', 'The indexing pin or pins extend into the indexing track.', 'The indexing ring is rotatable relative to the piston.', 'In yet other embodiments, a method for operating an indexing mechanism includes moving a piston from a first longitudinal piston position to a second longitudinal piston position.', 'The method includes rotating at least one of an indexing sleeve or an indexing ring relative to the piston into a first indexing alignment.', 'The indexing ring encases less than an entirety of the piston.', 'The indexing ring surrounds a portion of the indexing sleeve.', 'The first indexing alignment aligns a ring stop on the indexing ring with a first sleeve stop on the indexing sleeve such that the first sleeve stop contacts the ring stop in the second longitudinal piston position.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Additional features and advantages of embodiments of the disclosure will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by the practice of such embodiments.', 'The features and advantages of such embodiments may be realized and obtained by means of the instruments and combinations particularly pointed out in the appended claims.', 'These and other features will become more fully apparent from the following description and appended claims, or may be learned by the practice of such embodiments as set forth hereinafter.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'In order to describe the manner in which the above-recited and other features of the disclosure can be obtained, a more particular description will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings.', 'For better understanding, the like elements have been designated by like reference numbers throughout the various accompanying figures.', 'While some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale.', 'Understanding that the drawings depict some example embodiments, the embodiments will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:\n \nFIG.', '1\n is a partial cut-away view of a drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n1\n is a perspective view of an indexing mechanism, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n2\n is a cross-sectional view of a downhole tool including the indexing mechanism of \nFIG.', '2\n-\n1\n, according to at least one embodiment of the present disclosure;\n \nFIG.', '3\n is a cross-sectional view of an indexing mechanism, according to at least one embodiment of the present disclosure;\n \nFIG.', '4\n-\n1\n is a view of an indexing track, according to at least one embodiment of the present disclosure;\n \nFIG.', '4\n-\n2\n is another view of an indexing track, according to at least one embodiment of the present disclosure;\n \nFIG.', '5\n-\n1\n is a perspective view of an indexing mechanism, according to at least one embodiment of the present disclosure;\n \nFIG.', '5\n-\n2\n is a cross-sectional view of a downhole tool including the indexing mechanism of \nFIG.', '2\n-\n2\n, according to at least one embodiment of the present disclosure;\n \nFIG.', '6\n is a perspective view of an indexing mechanism, according to at least one embodiment of the present disclosure;\n \nFIG.', '7\n-\n1\n is a perspective view of another indexing mechanism, according to at least one embodiment of the present disclosure;\n \nFIG.', '7\n-\n2\n is a cross sectional view of a downhole tool including the indexing mechanism of \nFIG.', '7\n-\n1\n, according to at least one embodiment of the present disclosure;\n \nFIG.', '8\n is a cross-sectional view of another indexing mechanism, according to at least one embodiment of the present disclosure; and\n \nFIG.', '9\n is a method chart of a method for operating an indexing mechanism, according to at least one embodiment of the present disclosure.', 'DETAILED DESCRIPTION', 'This disclosure generally relates to devices, systems, and methods for actuating a downhole tool using an indexing mechanism. \nFIG.', '1\n shows one example of a drilling system \n100\n for drilling an earth formation \n101\n to form a wellbore \n102\n.', 'The drilling system \n100\n includes a drill rig \n103\n used to turn a drilling tool assembly \n104\n which extends downward into the wellbore \n102\n.', 'The drilling tool assembly \n104\n may include a drill string \n105\n, a bottom hole assembly (“BHA”) \n106\n, and a bit \n110\n, attached to the downhole end of drill string \n105\n.', 'The drill string \n105\n may include several joints of drill pipe \n108\n connected end-to-end through tool joints \n109\n.', 'The drill string \n105\n transmits drilling fluid through a central bore and transmits rotational power from the drill rig \n103\n to the BHA \n106\n.', 'In some embodiments, the drill string \n105\n may further include additional components such as subs, pup joints, etc.', 'The drill pipe \n108\n provides a hydraulic passage through which drilling fluid is pumped from the surface.', 'The drilling fluid discharges through selected-size nozzles, jets, or other orifices in the bit \n110\n for the purposes of cooling the bit \n110\n and cutting structures thereon, and for lifting cuttings out of the wellbore \n102\n as it is being drilled.', 'The BHA \n106\n may include the bit \n110\n or other components.', 'An example BHA \n106\n may include additional or other components (e.g., coupled between to the drill string \n105\n and the bit \n110\n).', 'Examples of additional BHA components include drill collars, stabilizers, measurement-while-drilling (“MWD”) tools, logging-while-drilling (“LWD”) tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'In general, the drilling system \n100\n may include other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves).', 'Additional components included in the drilling system \n100\n may be considered a part of the drilling tool assembly \n104\n, the drill string \n105\n, or a part of the BHA \n106\n depending on their locations in the drilling system \n100\n.', 'The bit \n110\n in the BHA \n106\n may be any type of bit suitable for degrading downhole materials.', 'For instance, the bit \n110\n may be a drill bit suitable for drilling the earth formation \n101\n.', 'Example types of drill bits used for drilling earth formations are fixed-cutter or drag bits.', 'In other embodiments, the bit \n110\n may be a mill used for removing metal, composite, elastomer, other materials downhole, or combinations thereof.', 'For instance, the bit \n110\n may be used with a whipstock to mill into casing \n107\n lining the wellbore \n102\n.', 'The bit \n110\n may also be a junk mill used to mill away tools, plugs, cement, other materials within the wellbore \n102\n, or combinations thereof.', 'Swarf or other cuttings formed by use of a mill may be lifted to surface, or may be allowed to fall downhole.', 'FIG.', '2\n-\n1\n is a perspective view of a representation of a indexing mechanism \n212\n, according to at least one embodiment of the present disclosure.', 'The indexing mechanism \n212\n may include a piston \n214\n.', 'An indexing sleeve \n216\n may encase a portion of the piston \n214\n.', 'In other words, the indexing sleeve \n216\n may surround at least a portion of the piston \n214\n.', 'In some embodiments, the indexing sleeve \n216\n may encase less than an entirety of the piston \n214\n.', 'In at least one embodiment, the indexing sleeve \n216\n may be coaxial with the piston \n214\n about a longitudinal axis \n217\n.', 'The indexing sleeve \n216\n may include an indexing track \n218\n.', 'The indexing track \n218\n may include a series of walls and/or tracks on the indexing sleeve \n216\n.', 'The indexing mechanism \n212\n may include an indexing ring \n220\n.', 'The indexing ring \n220\n may surround at least a portion of the indexing sleeve \n216\n, and therefore, the indexing ring \n220\n may surround at least a portion of the piston \n214\n.', 'In at least one embodiment, the indexing ring \n220\n may surround less than an entirety of the indexing sleeve \n216\n.', 'The indexing ring \n220\n may be coaxial with the piston \n214\n and the indexing sleeve \n216\n about the longitudinal axis \n217\n.', 'The indexing ring \n220\n may include an indexing pin \n222\n.', 'The indexing pin \n222\n may be inserted into the indexing track \n218\n.', 'The indexing sleeve \n216\n may be rotatable relative to the piston \n214\n about the longitudinal axis \n217\n.', 'Furthermore, the indexing sleeve \n216\n may be rotatable relative to the piston \n214\n and the indexing ring \n220\n about the longitudinal axis \n217\n.', 'The indexing ring \n220\n may be rotatable relative to the piston \n214\n about the longitudinal axis \n217\n.', 'Furthermore, in at least one embodiment, the indexing ring \n220\n may be rotatable relative to the piston \n214\n and the indexing sleeve \n216\n about the longitudinal axis \n217\n.', 'In some embodiments, the indexing sleeve \n216\n may be longitudinally fixed to the piston \n214\n.', 'In other words, when the piston \n214\n moves along the longitudinal axis \n217\n, the indexing sleeve \n216\n may move along the longitudinal axis \n217\n with the piston \n214\n.', 'In at least one embodiment, the piston \n214\n and the indexing sleeve \n216\n may be longitudinally movable along the longitudinal axis \n217\n relative to the indexing ring \n220\n.', 'As the indexing sleeve \n216\n moves longitudinally relative to the indexing ring \n220\n, the indexing pin \n222\n may contact a wall \n224\n of the indexing track \n218\n.', 'Contacting the wall \n224\n of the indexing track \n218\n may cause the wall \n224\n to push on the indexing pin \n222\n and the indexing pin \n222\n to push on the wall \n224\n.', 'This pushing may result in a torque about the longitudinal axis \n217\n that acts on both the indexing sleeve \n216\n and the indexing ring \n220\n.', 'When the torque exceeds a breakout torque of at least one of the indexing sleeve \n216\n and/or the indexing ring \n220\n, one or both of the indexing sleeve \n216\n and/or the indexing ring \n220\n may rotate relative to the piston \n214\n about the longitudinal axis \n217\n.', 'Thus, the indexing sleeve \n216\n and the indexing ring \n220\n may rotate relative to the piston \n214\n in response to the longitudinal motion of the piston \n214\n.', 'In other words, the indexing sleeve \n216\n and the indexing ring \n220\n may rotate relative to the piston \n214\n in response to the indexing pin \n222\n engaging the wall \n224\n of the indexing track \n218\n.', 'For example, when the torque exceeds the sleeve breakout torque of the indexing sleeve \n216\n but not the ring breakout torque of the indexing ring \n220\n, the indexing sleeve \n216\n may rotate relative to the piston \n214\n and the indexing ring \n220\n.', 'In this manner, the sleeve breakout torque may be less than the ring breakout torque.', 'In other examples, when the torque exceeds the ring breakout torque but not the sleeve breakout torque, the indexing ring \n220\n may rotate relative to the piston \n214\n and the indexing sleeve \n216\n.', 'In still other examples, the torque may exceed both the ring breakout torque and the sleeve breakout torque, and both the indexing sleeve \n216\n and the indexing ring \n220\n may rotate relative to each other and the piston \n214\n.', 'The torque exerted on the indexing sleeve \n216\n may be opposite the torque exerted on the indexing ring \n220\n.', 'Thus, the torque may cause the indexing sleeve \n216\n to rotate in a first direction, and the indexing ring \n220\n to rotate in a second direction, the first direction being different than the second direction.', 'For example, in the embodiment shown in \nFIG.', '2\n-\n1\n, if the indexing sleeve \n216\n were moved along the longitudinal axis \n217\n in a downhole direction (i.e., such that an uphole end \n226\n of the indexing sleeve \n216\n moves toward the indexing ring \n220\n), the indexing pin \n222\n may engage a portion of the wall \n224\n that is curved clockwise.', 'This engagement may cause the indexing sleeve \n216\n to rotate counter-clockwise as viewed from the uphole end \n226\n, and the indexing ring \n220\n to rotate clockwise as viewed from the uphole end \n226\n.', 'In other examples, the wall \n224\n may be oriented in a different direction, thereby causing the indexing sleeve \n216\n to rotate clockwise and the indexing ring \n220\n to rotate counter-clockwise.', 'Including an indexing sleeve \n216\n and an indexing ring \n220\n that both rotate may increase the reliability of the indexing mechanism \n212\n.', 'For example, if the indexing sleeve \n216\n jams, then the indexing ring \n220\n may still be able to rotate, and the indexing mechanism \n212\n may be able to cycle.', 'Similarly, if the indexing ring \n220\n jams, then the indexing sleeve \n216\n may still be able to rotate, and the indexing mechanism \n212\n may be able to cycle.', 'Thus, the indexing mechanism \n212\n may cycle more reliably, or may have a longer operational life between servicing.', 'This may decrease the amount of times that the drill string needs to be tripped out of the hole, thereby potentially decreasing costs.', 'Furthermore, including the indexing track \n218\n on the indexing sleeve \n216\n may reduce the overall manufacturing complexity of a downhole tool.', 'For example, machining the indexing track \n218\n may be one of the last manufacturing steps taken in the fabrication of a downhole tool.', 'If a mistake is made during machining of an indexing track \n218\n located directly on a piston \n214\n, then the entire piston \n214\n must be discarded, which may represent a loss of a significant investment in materials, consumables, labor, and so forth.', 'By including the indexing track \n218\n on the indexing sleeve \n216\n, if a mistake is made during machining of the indexing track \n218\n, then only the indexing sleeve \n216\n must be discarded, which may represent significantly less of an investment in materials, consumables, labor, and so forth than the piston.', 'Thus, the indexing sleeve \n216\n reduces the complexity of the manufacturing process, and also reduces the risk of having to re-manufacture an entire piston \n214\n.', 'Furthermore, including an indexing sleeve \n216\n that is separate from the piston \n214\n may reduce the mass that is rotated when the indexing mechanism \n212\n is cycled.', 'A lower mass may reduce the amount of torque required to rotate the indexing sleeve \n216\n.', 'This may reduce the forces experienced by the indexing pin \n222\n and/or the wall \n224\n.', 'Reducing the torque and the forces on the indexing pin \n222\n and/or the wall \n224\n may reduce the chance of the indexing pin \n222\n failing by fracturing, shearing, and so forth.', 'In at least one embodiment, an indexing ring \n220\n may have a lower mass than the indexing sleeve \n216\n.', 'This means that the indexing ring \n220\n may require a lower torque to rotate than the indexing sleeve, thereby further reducing forces on the indexing pin \n222\n and/or the wall \n224\n.', 'The indexing sleeve \n216\n has a sleeve mass.', 'In some embodiments, the sleeve mass may be in a range having an upper value, a lower value, or upper and lower values including any of 1 kg, 2 kg, 3 kg, 4 kg, 5 kg, 6 kg, 7 kg, 8 kg, 9 kg, 10 kg, 15 kg, 20 kg, or any value therebetween.', 'For example, the sleeve mass may be greater than 1 kg.', 'In another example, the sleeve mass may be less than 20 kg.', 'In yet other examples, the sleeve mass may be any value in a range between 1 kg and 20 kg.', 'In some embodiments it may be critical that the sleeve mass is 8 kg or less to reduce the chance of failure of the indexing pin \n222\n.', 'The indexing ring \n218\n has a ring mass.', 'In some embodiments, the ring mass may be in a range having an upper value, a lower value, or upper and lower values including any of 0.25 kg, 0.5 kg, 0.75 kg, 1 kg, 2 kg, 3 kg, 4 kg, 5 kg, 6 kg, 7 kg, 8 kg, 9 kg, 10 kg, or any value therebetween.', 'For example, the ring mass may be greater than 0.25 kg.', 'In another example, the ring mass may be less than 10 kg.', 'In yet other examples, the ring mass may be any value in a range between 0.25 kg and 10 kg.', 'In some embodiments it may be critical that the ring mass is 2 kg or less to reduce the chance of failure of the indexing pin \n222\n.', 'The indexing sleeve \n216\n and the indexing ring \n220\n have a mass ratio that is the ratio of the ring mass to the sleeve mass.', 'In some embodiments, the mass ratio may be in a range having an upper value, a lower value, or upper and lower values including any of 1:1, 1:1.5, 1:2, 1:2.5, 1:3, 1:3.5, 1:4, 1:4.5, 1:5, 1:6, 1:7, 1:8, 1:9, 1:10, or any value therebetween.', 'For example, the mass ratio may be greater than 1:1.', 'In another example, the mass ratio may be less than 1:10.', 'In yet other examples, the mass ratio may be any value in a range between 1:1 and 1:10.', 'In some embodiments it may be critical that the mass ratio less than 1:4 to improve the reliability of the indexing mechanism \n212\n.\n \nFIG.', '2\n-\n2\n is a cross-sectional view of a downhole tool \n213\n, including a cross-sectional view of the indexing mechanism \n212\n of \nFIG.', '2\n-\n1\n.', 'The downhole tool \n213\n includes a housing \n228\n.', 'A piston \n214\n may be located inside a central bore \n230\n of the housing \n228\n.', 'An indexing sleeve \n216\n may encompass less than an entirety of the piston \n214\n.', 'In other words, an inner surface \n232\n of the indexing sleeve \n216\n may abut an outer surface \n234\n of the piston \n214\n.', 'An indexing ring \n220\n may surround at least a portion of the indexing sleeve \n216\n.', 'For example, the indexing ring \n220\n has an indexing ring width \n236\n and the indexing sleeve \n216\n has an indexing sleeve width \n238\n.', 'The indexing ring width \n236\n and the indexing sleeve width \n238\n affect the mass of the indexing ring \n220\n and the indexing sleeve \n216\n, respectively.', 'For example, a larger indexing ring width \n236\n results in a heavier indexing ring \n220\n, and a smaller indexing ring width \n236\n results in a lighter indexing ring \n220\n.', 'As described herein, the indexing ring may surround less than an entirety of the indexing sleeve.', 'For example, the indexing ring width \n236\n is a ring percentage of the indexing sleeve width \n238\n.', 'In some embodiments, the ring percentage may be in a range having an upper value, a lower value, or upper and lower values including any of 5%, 10%, 12%, 14%, 15%, 16%, 18%, 20%, 25%, 30%, 35%, 40%, 45%, 50%, or any value therebetween.', 'For example, the ring percentage may be greater than 5%.', 'In another example, the ring percentage may be less than 50%.', 'In yet other examples, the ring percentage may be any value in a range between 5% and 50%.', 'In some embodiments it may be critical that the ring percentage is less than 10% to improve the reliability of the indexing mechanism \n212\n.', 'The housing \n228\n may include a fluid path \n240\n.', 'The fluid path \n240\n may be sealed by a sealing member \n241\n between the fluid path \n240\n and the piston \n214\n.', 'The piston \n214\n may pass through a channel wall \n242\n such that the channel wall \n242\n separates the central bore \n230\n from the fluid path \n240\n.', 'The channel wall \n242\n may include a channel opening \n243\n.', 'In the position shown in \nFIG.', '2\n-\n2\n, the channel opening \n243\n is sealed from the central bore \n230\n by the piston \n214\n.', 'A fluid flow \n244\n may pass through the central bore \n230\n with a volumetric flow rate that is related to a fluid pressure.', 'The fluid pressure may push on an uphole end \n246\n of the piston \n214\n.', 'As the volumetric flow rate increases, the fluid pressure may urge the uphole end \n246\n of the piston \n214\n downhole.', 'A biasing member (not shown) located past a downhole end \n248\n of the indexing mechanism \n212\n may urge the piston \n214\n uphole.', 'The biasing member may be any biasing member, such as a coil spring, a Bellville washer, a leaf spring, a wave spring, a hydraulic or pneumatic piston, or other biasing member.', 'When the fluid pressure exerts a force on the piston \n214\n that is greater than the opposing force from the biasing member, the piston \n214\n may move downhole.', 'In at least one embodiment, the piston \n214\n may move downhole enough that the fluid flow \n244\n may pass into the fluid path \n240\n.', 'The fluid path \n240\n may be directed to hydraulically actuate a downhole tool, including an expandable tool such as a reamer, a section mill, other expandable tool, an expandable stabilizer, an anchor, a bypass valve, a packing element, another downhole tool, or combinations of the foregoing.', 'In the embodiment shown in \nFIG.', '2\n-\n2', ', the indexing mechanism \n212\n is in a low-flow state.', 'In other words, the fluid pressure from the fluid flow \n244\n is insufficient to overcome the opposing force from the biasing member.', 'In this state, the fluid path \n240\n is blocked, and the downhole tool is not actuated.', 'As the fluid flow \n244\n increases, the piston \n214\n moves downhole, the indexing sleeve \n216\n may move downhole with the piston \n214\n.', 'An indexing pin \n222\n may be inserted into a track \n250\n of an indexing track \n218\n.', 'When the indexing pin \n222\n engages a wall \n224\n of the indexing track \n218\n, one or both of the indexing sleeve \n216\n and the indexing ring \n220\n may rotate to allow the piston \n214\n and the indexing sleeve \n216\n to continue to move longitudinally downhole as the fluid flow is increased.\n \nFIG.', '3\n is a close-up cross-sectional view of an indexing mechanism \n312\n, according to at least one embodiment of the present disclosure.', 'The indexing mechanism \n312\n may include a housing \n328\n.', 'A piston \n314\n may be located in a central bore \n330\n of the housing \n328\n.', 'An indexing sleeve \n316\n may encompass at least less than an entirety of the piston \n314\n.', 'In other words, the indexing sleeve \n316\n may surround a portion of the piston \n314\n.', 'The indexing sleeve may be longitudinally fixed to the piston \n314\n by an upper sleeve block \n352\n-\n1\n and a lower sleeve block \n352\n-\n2\n.', 'The upper sleeve block \n352\n-\n1\n and the lower sleeve block \n352\n-\n2\n may prevent the indexing sleeve \n316\n from moving longitudinally relative to the piston \n314\n.', 'For example, when the piston \n314\n moves downhole (i.e., toward the lower sleeve block \n352\n-\n2\n), the indexing sleeve \n316\n may push against the upper sleeve block \n352\n-\n1\n.', 'Similarly, when the piston \n314\n moves uphole (i.e., toward the upper sleeve block \n352\n-\n1\n), the indexing sleeve \n316\n may push against the lower sleeve block \n352\n-\n2\n.', 'The indexing sleeve \n316\n may be rotatable relative to the piston \n314\n.', 'In at least one embodiment, the indexing sleeve \n316\n may rotate directly against the piston \n314\n, without any bearings.', 'In other embodiments, the indexing sleeve \n316\n may rotate against a radial bearing \n354\n between the indexing sleeve \n316\n and the piston \n314\n.', 'In at least one embodiment, including a radial bearing \n354\n may decrease the torque required to rotate the indexing sleeve \n316\n.', 'Furthermore, in the same or other embodiments, the radial bearings \n354\n may help to centralize the indexing sleeve \n316\n with respect to the piston \n314\n.', 'Rotating against the piston \n314\n without any bearings may reduce the cost and complexity of the indexing mechanism \n312\n.', 'The indexing mechanism \n312\n may include an indexing ring \n320\n.', 'The indexing ring \n320\n may include an indexing pin \n322\n fixed to the indexing ring \n320\n.', 'The indexing pin \n322\n may be located in a ring stop \n356\n located in the indexing ring \n320\n.', 'For example, the indexing pin \n322\n may be inserted into a bore in the ring stop \n356\n.', 'In some embodiments, the indexing pin \n322\n may be connected to the ring stop \n356\n with a mechanical connection, such as a threaded connection, a press-fit, an interference fit, a snap ring, a locking pin, a cotter pin, a shear pin, or other mechanical connection.', 'In other embodiments, the indexing pin \n322\n may be connected to the ring stop \n356\n with a weld, braze, or other joining process.', 'In some embodiments, the indexing pin \n322\n and the ring stop \n356\n may be formed of a single unitary piece.', 'For example, a blank may be machined to form the ring stop \n356\n and the indexing pin.', 'Including the indexing pin \n322\n in the ring stop \n356\n may strengthen the indexing pin \n322\n for the contact between the indexing pin \n322\n and a wall \n324\n of the indexing track \n318\n.', 'Furthermore, including the indexing pin \n322\n with the ring stop \n356\n may shorten the indexing mechanism \n312\n and allow a sleeve stop \n362\n on the indexing sleeve \n316\n to be located uphole of the indexing ring \n320\n and the ring stop \n356\n.', 'In some embodiments, the indexing pin \n322\n may be rotatable relative to the ring stop \n356\n.', 'For example, as the indexing pin \n322\n engages the wall \n324\n and one or both of the indexing sleeve \n316\n and the indexing ring \n320\n rotate, the indexing pin \n322\n may slide along the wall \n324\n.', 'A rotating indexing pin \n322\n may roll along the wall \n324\n rather than slide along the wall.', 'This may reduce wear on the wall \n324\n and/or the indexing pin \n322\n during repeated cycling of the indexing mechanism \n312\n.', 'In some embodiments, the indexing ring \n320\n may include a plurality of indexing pins \n322\n connected to a plurality of ring stops \n356\n.', 'For example, the indexing ring \n320\n may include two, three, four, or more indexing pins \n322\n and ring stops \n356\n.', 'The indexing pin may extend into a track \n350\n of an indexing track \n318\n of the indexing sleeve \n316\n.', 'The indexing ring \n320\n may be secured to the housing \n328\n with a ring support \n358\n.', 'The ring support \n358\n may be longitudinally and rotationally fixed to the housing \n328\n with any type of connection, such as a threaded connection, a bolted connection, a weld, braze, or any other type of connection.', 'The indexing ring \n320\n may rotate relative to the ring support \n358\n.', 'In at least one embodiment, the indexing ring \n320\n may rotate directly against the ring support \n358\n, or without any bearings.', 'In other embodiments, the indexing ring \n320\n may rotate against the ring support \n358\n against a bearing, such as an axial or a radial bearing.', 'In some embodiments, the indexing ring \n320\n may be directly secured to the housing \n328\n.', 'For example, the indexing ring \n320\n may be inserted into a annular channel machined or cast into the inner wall of the housing \n328\n.', 'As the piston \n314\n and the indexing sleeve \n316\n move longitudinally downhole, a wall \n324\n of the indexing track \n318\n may engage the indexing pin \n322\n.', 'Thus, the indexing pin \n322\n may be inserted far enough into the indexing track \n318\n and the track \n350\n to contact the wall \n324\n.', 'In at least one embodiment, the indexing pin \n322\n may contact a bottom surface \n360\n of the track \n350\n.', 'When the indexing pin \n322\n contacts the wall \n324\n, the indexing sleeve \n316\n may be pushed toward the upper sleeve block \n352\n-\n1\n.', 'Uphole movement of the indexing sleeve \n316\n may be stopped by the upper sleeve block \n352\n-\n1\n, and a torque may be applied to the indexing sleeve \n316\n and the indexing ring \n320\n.', 'The torque may be greater than a sleeve breakout torque of the indexing sleeve \n316\n, and the indexing sleeve \n316\n may rotate relative to the piston \n314\n.', 'In at least one embodiment, the upper sleeve block \n352\n-\n1\n may be rotationally fixed to the piston \n314\n, and the indexing sleeve \n316\n may rotate directly against the upper sleeve block \n352\n-\n1\n, without any bearings.', 'In other embodiments, the upper sleeve block \n352\n-\n1\n may be a bearing, such as a thrust bearing or a ball bearing.', 'As the piston \n314\n and the indexing sleeve \n316\n move further downhole, a sleeve stop \n362\n on the indexing sleeve \n316\n may contact or engage the ring stop \n356\n.', 'This may cause the piston \n314\n and the indexing sleeve \n316\n to stop moving downhole.', 'In some embodiments, the sleeve stop \n362\n may directly engage the ring stop \n356\n.', 'The ring stop \n356\n may be sized to stop the motion of the piston \n314\n and the indexing sleeve \n316\n without damage.', 'In other embodiments, the sleeve stop \n362\n may engage the indexing pin \n322\n, and the indexing pin \n322\n may be sized to stop the motion of the piston \n314\n and the indexing sleeve \n316\n without damage.', 'Thus, in some embodiments, the sleeve stop \n362\n may be located uphole of the ring stop \n356\n.', 'Locating the sleeve stop \n362\n uphole of the ring stop \n356\n may reduce the number of parts of the system, which may reduce the manufacturing cost.', 'Furthermore, locating the indexing pin \n322\n in the indexing ring \n320\n may shorten the length of the indexing sleeve \n316\n, which may reduce manufacturing costs and reduce the length the indexing sleeve \n316\n has to move to cycle the indexing mechanism \n312\n.\n \nFIG.', '4\n-\n1\n is a representation of an indexing track \n418\n, according to at least one embodiment of the present disclosure.', 'The indexing track \n418\n may include a track \n450\n located between walls \n424\n in the indexing track \n418\n.', 'An indexing pin \n422\n may be installed in a ring stop (e.g., the ring stop \n356\n of \nFIG.', '3\n) of an indexing ring (e.g., indexing ring \n220\n of \nFIG.', '2\n-\n1\n).', 'The indexing pin may extend into the track \n450\n at a first longitudinal piston position \n464\n-\n1\n (e.g., the position shown in \nFIG.', '2\n-\n1\n and \nFIG.', '2\n-\n2\n).', 'As an indexing sleeve (e.g., the indexing sleeve \n216\n of \nFIG.', '2\n-\n1\n), in which the indexing track \n418\n is located, is moved downhole, the indexing pin \n422\n may follow a first indexing pin path \n466\n-\n1\n.', 'The walls \n424\n may direct the indexing pin \n422\n until the piston (e.g., piston \n214\n of \nFIG.', '2\n-\n2\n) and the indexing sleeve are stopped a second longitudinal piston position \n464\n-\n2\n.', 'This may occur, for instance, when the fluid flow (e.g., the fluid flow \n244\n of \nFIG.', '2\n-\n2\n) is increased to a high flow state.', 'A first sleeve stop \n462\n-\n1\n may engage a ring stop and stop downhole movement of the piston and the indexing sleeve at the second longitudinal piston position \n464\n-\n2\n.', 'In the second longitudinal piston position \n464\n-\n2\n, fluid flow to a fluid path (e.g., fluid path \n240\n of \nFIG.', '2\n-\n2\n) may be blocked by the piston.', 'When the fluid flow is decreased to a low flow state, then the piston and the indexing sleeve may move uphole, and the walls \n424\n may direct the indexing pin \n422\n until the piston and the indexing sleeve are back to the first longitudinal piston position.', 'In this manner, the cycling of the indexing mechanism may be repeated indefinitely without allowing fluid flow into the fluid path.', 'In other words, the cycling of the indexing mechanism may be repeated indefinitely without actuating a downhole tool.', 'In the second longitudinal piston position \n464\n-\n2\n, the indexing ring and the indexing sleeve may be in a first indexing alignment.', 'In the first indexing alignment, the indexing ring may be in one of a first lower straight section \n465\n-\n1\n of the indexing track \n418\n and a first upper straight section \n467\n-\n1\n of the indexing track \n218\n, the first lower straight section \n465\n-\n1\n and the first upper straight section \n467\n-\n1\n being in line in the indexing track \n418\n.', 'For instance, the first lower straight section \n465\n-\n1\n and the first upper straight section \n467\n-\n1\n may be in the same circumferential position on the indexing sleeve.', 'Furthermore, in the first indexing alignment, the ring stop may be aligned to contact a first sleeve stop \n462\n-\n1\n on the indexing sleeve such that the first sleeve stop \n462\n-\n1\n contacts the ring stop in the second longitudinal piston position \n464\n-\n2\n.\n \nFIG.', '4\n-\n2\n is a representation of the indexing track \n418\n of \nFIG.', '4\n-\n1\n, according to at least one embodiment of the present disclosure.', 'The indexing track \n418\n may include a track \n450\n located between walls \n424\n in the indexing track \n418\n.', 'An indexing pin \n422\n may extend into the track \n450\n at a first longitudinal piston position \n464\n-\n1\n.', 'As the flow is increased from the low flow state to the high flow state, the piston and the indexing sleeve are moved downhole, the indexing pin \n422\n may follow a second indexing pin path \n466\n-\n2\n.', 'The second indexing pin path \n466\n-\n2\n may follow the same initial path as the first indexing pin path \n466\n-\n1\n shown in \nFIG.', '4\n-\n1\n until the piston and the indexing sleeve are in the second longitudinal piston position \n464\n-\n2\n.', 'To actuate a downhole tool, fluid flow may be reduced to an indexing flow between the high flow state and the low flow state.', 'At the indexing flow, the piston and indexing sleeve may be moved to a third longitudinal piston position \n464\n-\n3\n.', 'The third longitudinal piston position \n464\n-\n3\n may be between the first longitudinal piston position \n464\n-\n1\n and the second longitudinal piston position \n464\n-\n2\n.', 'In the third longitudinal piston position \n464\n-\n3\n, the indexing ring and the indexing sleeve may be in a second indexing alignment.', 'In the second indexing alignment, the indexing pin \n422\n may be in middle section \n468\n of the indexing track, and not aligned with the first lower straight section \n465\n-\n1\n, a second lower straight section \n465\n-\n2\n, a first upper straight section \n467\n-\n1\n, or a second upper straight section \n475\n-\n2\n.', 'Thus, the ring stop may not be aligned with either the first sleeve stop \n462\n-\n1\n or the second sleeve stop \n462\n-\n2\n.', 'The fluid flow may then be increased from the indexing flow to the high flow.', 'This may cause the indexing pin \n422\n to direct the piston and the indexing sleeve to a fourth longitudinal piston position \n464\n-\n4\n.', 'In at least one embodiment, the first sleeve stop \n462\n-\n1\n may engage a ring support in the fourth longitudinal piston position and halt downhole movement of the piston and the indexing sleeve.', 'The ring support may include a surface downhole of the indexing ring against which the first sleeve stop \n462\n-\n1\n may contact, thereby preventing further longitudinal movement of the piston and the indexing sleeve.', 'In the same or other embodiments, a second sleeve stop \n462\n-\n2\n may engage the ring stop and halt downhole movement of the piston and the indexing sleeve.', 'In some embodiments, the indexing sleeve may both contact the ring stop and the second sleeve stop \n462\n-\n2\n may engage the ring stop in the fourth longitudinal piston position.', 'In the fourth longitudinal piston position \n464\n-\n4\n, the indexing ring and the indexing sleeve may be in a third indexing alignment.', 'In the third indexing alignment, the indexing ring may be in one of the second lower straight section \n465\n-\n2\n and the second upper straight section \n467\n-\n2\n, the second lower straight section \n465\n-\n2\n and the second upper straight section \n467\n-\n2\n being in line in the indexing track \n418\n.', 'For instance, the second lower straight section \n465\n-\n2\n and the second upper straight section \n467\n-\n2\n may be in the same circumferential position on the indexing sleeve.', 'Furthermore, in the third indexing alignment, the first sleeve stop \n462\n-\n1\n may be aligned to contact the ring support between two ring stops, and/or the ring stop may be aligned to contact the second sleeve stop \n462\n-\n2\n on the indexing sleeve such that the first sleeve stop \n462\n-\n1\n contacts the ring support and/or the second sleeve stop \n462\n-\n2\n contacts the ring stop in the fourth longitudinal piston position \n464\n-\n4\n.', 'In other words, in the third indexing alignment, the ring stop may be longitudinally offset from the first sleeve stop \n462\n-\n1\n in the fourth longitudinal piston position and the third indexing alignment.', 'In the fourth longitudinal piston position \n464\n-\n4\n, the fluid path may be open to the fluid flow.', 'In this manner, the fluid flow may actuate a downhole tool.', 'When the fluid flow is reduced to the low flow state, then the indexing pin \n422\n may direct the piston and the indexing sleeve back to the first longitudinal piston position \n464\n-\n1\n.', 'When the fluid flow is increased back to the high flow state, then the indexing pin \n422\n may direct the piston and the indexing sleeve back to the fourth longitudinal piston position \n464\n-\n4\n.', 'In this manner, the downhole tool may be indefinitely cycled between actuating a downhole tool and deactivating a downhole tool by changing the fluid flow from the low flow state to the high flow state and back again.', 'FIG.', '5\n-\n1\n is a representation of an indexing mechanism \n512\n, according to at least one embodiment of the present disclosure.', 'The indexing mechanism \n512\n may be in the second longitudinal piston position (e.g., second longitudinal piston position \n464\n-\n2\n of \nFIG.', '4\n-\n1\n).', 'As a piston \n514\n and an indexing sleeve \n516\n are moved into the second longitudinal position, one or both of the indexing sleeve \n516\n and an indexing ring \n520\n may be rotated to place the indexing sleeve \n516\n and the indexing ring \n520\n in a first indexing alignment.', 'In the first indexing alignment (and the second longitudinal piston position) a first sleeve stop \n562\n-\n1\n may be aligned to contact a ring stop \n536\n on the indexing ring \n520\n.', 'An indexing pin inserted into a track \n550\n of an indexing track \n518\n.', 'Thus, the first sleeve stop \n562\n-\n1\n may be located uphole of the ring stop \n536\n.', 'In some embodiments, the first sleeve stop \n562\n-\n1\n may be fixed to the indexing sleeve \n516\n.', 'For example, the first sleeve stop \n562\n-\n1\n may be rotationally and longitudinally fixed to the indexing sleeve \n516\n.', 'The first sleeve stop \n562\n-\n1\n may be integrally formed with the indexing sleeve \n516\n.', 'For example, the first sleeve stop \n562\n-\n1\n may be machined, cast, chemically etched, or otherwise formed from a single unitary piece of the indexing sleeve \n516\n.', 'In other embodiments, the first sleeve stop \n562\n-\n1\n may be attached to the indexing sleeve \n516\n.', 'For example, the first sleeve stop \n562\n-\n1\n may be welded, brazed, attached with a mechanical fastener, press-fit, interference fit, or otherwise attached to the indexing sleeve \n516\n.', 'In still other embodiments, the first sleeve stop \n562\n-\n1\n may be attached to the piston \n514\n and overlap the indexing sleeve \n516\n.\n \nFIG.', '5\n-\n2\n is a cross-sectional view of a downhole tool \n513\n, including a cross-sectional view of the indexing mechanism \n512\n of \nFIG.', '5\n-\n1\n.', 'In the embodiment shown, the indexing mechanism \n512\n is in the second longitudinal piston position and the first indexing alignment.', 'Thus, the ring stop \n536\n may be contacting the first sleeve stop \n562\n-\n1\n, thereby blocking downhole movement of the piston \n514\n and the indexing sleeve \n516\n.', 'While the fluid flow \n544\n is in a high flow state, the piston \n514\n may be blocking a channel opening \n543\n to a fluid path \n540\n.', 'This may prevent the downhole tool \n513\n from actuating (i.e., prevent an expandable member from expanding.)\n \nFIG.', '6\n is a perspective view of an indexing mechanism \n612\n in a third longitudinal piston position, according to at least one embodiment of the present disclosure.', 'As a piston \n614\n and an indexing sleeve \n616\n are moved into the third longitudinal piston position, the indexing ring \n620\n and the indexing sleeve \n616\n are rotated into a second indexing alignment.', 'An indexing pin \n622\n connected to a ring stop \n636\n on the indexing ring \n620\n may be inserted into a track \n650\n of an indexing track \n618\n.', 'In the second indexing alignment, the ring stop \n650\n may be misaligned with either a first sleeve stop \n662\n-\n1\n or a second sleeve stop \n662\n-\n2\n.', 'In some embodiments, the second sleeve stop \n662\n-\n2\n may be fixed to the indexing sleeve \n616\n.', 'For example, the second sleeve stop \n662\n-\n2\n may be rotationally and longitudinally fixed to the indexing sleeve \n616\n.', 'The second sleeve stop \n662\n-\n2\n may be integrally formed with the indexing sleeve \n616\n.', 'For example, the second sleeve stop \n662\n-\n2\n may be machined, cast, chemically etched, or otherwise formed from a single unitary piece of the indexing sleeve \n616\n.', 'In other embodiments, the second sleeve stop \n662\n-\n2\n may be attached to the indexing sleeve \n616\n.', 'For example, the second sleeve stop \n662\n-\n2\n may be welded, brazed, attached with a mechanical fastener, press-fit, interference fit, or otherwise attached to the indexing sleeve \n616\n.', 'In still other embodiments, the second sleeve stop \n662\n-\n2\n may be attached to the piston \n614\n and overlap the indexing sleeve \n16\n.', 'In some embodiments, the first sleeve stop \n662\n-\n1\n and the second sleeve stop \n662\n-\n2\n may be integrally formed.', 'In other embodiments, the first sleeve stop \n662\n-\n1\n and the second sleeve stop \n662\n-\n2\n may be separate pieces, and individually attached to or formed with the indexing sleeve \n616\n.\n \nFIG.', '7\n-\n1\n is a perspective view of an indexing mechanism \n712\n in a fourth longitudinal piston position, according to at least one embodiment of the present disclosure.', 'As a piston \n714\n and an indexing sleeve \n716\n are moved into the fourth longitudinal piston position, at least one of an indexing ring \n720\n and/or the indexing sleeve are rotated into a third indexing alignment.', 'An indexing pin \n722\n connected to a ring stop \n736\n on the indexing ring \n720\n may be inserted into a track \n750\n of an indexing track \n718\n.', 'In the fourth longitudinal piston position and the third indexing alignment, the first ring stop (e.g., first ring stop \n562\n-\n1\n of \nFIG.', '5\n-\n2\n) may engage a ring support between two ring stops \n736\n on the indexing ring.', 'In the same or other embodiments, a second sleeve stop \n762\n-\n2\n may engage the ring stop \n736\n.', 'The ring stop \n736\n may prevent further downhole movement of the piston \n714\n and the indexing sleeve \n716\n.\n \nFIG.', '7\n-\n2\n is a cross-sectional view of a downhole tool \n713\n, including a cross-sectional view of the indexing mechanism \n712\n of \nFIG.', '7\n-\n1\n, according to at least one embodiment of the present disclosure.', 'In the embodiment shown, the piston \n714\n and the indexing sleeve \n716\n are in the fourth longitudinal piston position.', 'As may be seen, the piston \n714\n has uncovered the channel opening \n743\n, thereby allowing a portion \n770\n of fluid from the fluid flow \n744\n to enter the fluid path \n740\n.', 'The portion \n770\n of fluid may be directed to actuate a downhole tool, such as an expandable tool.', 'In the fourth longitudinal piston position, the first ring stop may engage a ring support between two ring stops \n736\n on the indexing ring.', 'In the same or other embodiments, a ring stop \n736\n on the indexing ring \n720\n may engage the second sleeve stop \n762\n-\n2\n on the indexing sleeve \n716\n, thereby preventing further downhole movement of the piston \n714\n and the indexing sleeve \n716\n.\n \nFIG.', '8\n is a cross-sectional view of a downhole tool \n813\n, according to at least one embodiment of the present disclosure.', 'The downhole tool \n813\n may include an indexing mechanism \n812\n.', 'The indexing mechanism \n812\n may include a piston \n814\n.', 'An indexing ring \n820\n may surround at least a portion of the piston \n814\n and be rotatable relative to the piston \n814\n.', 'The indexing ring \n820\n may be secured to a ring support \n858\n secured to the piston \n814\n.', 'The ring support \n858\n may be longitudinally secured to the piston \n814\n such that as the piston \n814\n moves longitudinally, the indexing ring \n820\n may move longitudinally.', 'Thus, the indexing ring \n820\n may be longitudinally fixed to the piston \n814\n.', 'An indexing sleeve \n816\n may be located radially outward from the indexing ring \n820\n and the piston \n814\n.', 'The indexing sleeve \n816\n may abut a housing \n828\n of the downhole tool \n813\n.', 'The indexing sleeve \n816\n may be rotatable relative to the housing \n828\n.', 'The indexing sleeve may be longitudinally fixed to the housing \n828\n with an upper sleeve block \n852\n-\n1\n and a lower sleeve block \n852\n-\n2\n.', 'As the piston \n814\n moves longitudinally relative to the indexing sleeve \n816\n, the indexing ring \n820\n may move longitudinally along the indexing sleeve \n816\n.', 'The indexing pin \n822\n may engage a wall \n824\n of an indexing track \n818\n of the indexing sleeve \n816\n.', 'This may cause one or both of the indexing sleeve \n816\n and the indexing ring \n820\n to rotate relative to each other and the piston \n814\n.', 'In this manner, the indexing track \n818\n may be located in an inner surface of the indexing sleeve.', 'FIG.', '9\n is a method chart of a method \n976\n for operating an indexing mechanism.', 'The method \n976\n may include moving a piston from a first longitudinal piston position to a second longitudinal piston position at \n978\n.', 'Moving the piston may include moving an indexing sleeve from the first longitudinal piston position to the second longitudinal piston position, the indexing sleeve encasing at least a portion of the piston.', 'Moving the piston may include increasing a fluid flow from a first flow rate to a second flow rate, the second flow rate being higher than the first flow rate.', 'The method \n976\n may include rotating at least one of an indexing sleeve and/or an indexing ring relative to the piston at \n980\n to an alignment.', 'Rotating the indexing sleeve and/or the indexing ring may be in response to the longitudinal movement of the piston and/or the indexing sleeve.', 'For example, moving the piston and the indexing sleeve longitudinally may cause an indexing pin located in a ring stop of the indexing ring to engage an indexing track of the indexing piston.', 'This may apply a torque to the indexing ring and the indexing sleeve, thereby causing one or both of the indexing ring and the indexing sleeve to rotate.', 'The indexing track of the indexing piston may be shaped such that at least one of the indexing sleeve and/or the indexing track may rotate to self-align or automatically align stopping or positioning features on the indexing mechanism.', 'For example, the indexing sleeve may include a sleeve stop and the indexing ring may include a ring stop, and the indexing track may be shaped to align the sleeve stop with the ring stop such that the sleeve stop may contact the ring stop.', 'In other examples, the indexing sleeve may include the sleeve stop and the indexing ring may include a gap between two ring stops, and the sleeve stop may be aligned to pass through the gap between the ring stops and contact a ring support, the ring support holding the indexing ring in place.', 'In at least one embodiment, rotating at least one of the indexing sleeve and/or the indexing ring may include rotating the indexing sleeve and the indexing ring relative to each other.', 'In the same or other embodiments, rotating at least one of the indexing sleeve and/or the indexing ring may include rotating the indexing sleeve in a first direction and the indexing ring in a second direction, the first direction being different from the second direction.', 'Rotating at least one of the indexing sleeve and/or the indexing ring may include aligning the indexing sleeve and the indexing piston into a first indexing alignment, the first indexing alignment aligning a ring stop on the indexing ring with a first sleeve stop on the indexing sleeve such that a first sleeve stop on the indexing sleeve contacts a ring stop on the indexing ring in the second longitudinal piston position.', 'The method \n976\n may include engaging the aligned stopping or positioning features at \n982\n, which may result in the indexing sleeve being stopped in a terminal longitudinal piston position.', 'In other words, the method \n976\n may include engaging the sleeve stop with the ring stop or the ring support.', 'For example, the sleeve stop of the indexing sleeve may be aligned to engage or contact the ring stop of the indexing ring, thereby stopping the indexing sleeve in a terminal longitudinal piston position, or the second longitudinal piston position.', 'In another example, the sleeve stop of the indexing sleeve may be aligned to engage or contact the ring support that supports the indexing ring, thereby stopping the indexing sleeve in a terminal longitudinal position, or the fourth longitudinal piston position.', 'The method \n976\n may further include moving the piston from the second longitudinal piston position to a third longitudinal piston position, the third longitudinal piston position being between the first longitudinal piston position and the second longitudinal position.', 'Moving the piston may include changing the fluid flow from the second flow rate to a third flow rate, the third flow rate being between the first flow rate and the second flow rate.', 'Moving the piston to the third longitudinal position may include rotating at least one of the indexing sleeve and/or the indexing ring relative to the piston to a second indexing alignment.', 'The method \n976\n may further include moving the piston from the third longitudinal piston position to a fourth longitudinal piston position, the fourth longitudinal piston position being further from the first longitudinal piston position than the second longitudinal piston position.', 'Moving the piston may include rotating at least one of the indexing sleeve and/or the indexing ring relative to the piston to a third indexing alignment.', 'The third indexing alignment may align the ring stop with a second sleeve stop such that the second sleeve stop contacts the ring stop in the fourth longitudinal piston position.', 'In some embodiments, a downhole tool includes a piston, an indexing sleeve encasing a portion of the piston, and an indexing ring surrounding less than an entirety of the indexing sleeve.', 'The indexing sleeve is rotatable relative to the piston.', 'The indexing ring includes an indexing pin extending into the indexing track.', 'The indexing ring may be rotatable relative to the indexing sleeve.', 'The indexing sleeve may be longitudinally fixed to the piston.', 'The indexing sleeve and the indexing ring may rotate relative to the piston in response to a longitudinal motion of the piston.', 'The indexing sleeve and the indexing ring may rotate relative to the piston in response to the indexing pin engaging the indexing track.', 'The indexing ring may have a mass of 2 kg or less, and the indexing sleeve may have a mass of 8 kg or less.', 'The indexing ring and the indexing sleeve may have a mass ratio of less than 1:4.', 'The indexing track may include a first sleeve stop and a second sleeve stop.', 'The first sleeve stop may engage a ring stop in a first longitudinal piston position, and may engage a ring support in a second longitudinal piston position.', 'The second longitudinal piston position may be further uphole than the first longitudinal piston position.', 'In some embodiments, a downhole tool includes a piston, an indexing sleeve with an indexing track, and an indexing ring surrounding a portion of the indexing sleeve.', 'The indexing sleeve encases a portion of the piston.', 'The indexing ring includes a ring stop and an indexing pin extending into the indexing track.', 'The indexing ring is rotatable relative to the piston.', 'The indexing pin may be located in the ring stop.', 'The indexing sleeve may include a sleeve stop located uphole of the ring stop.', 'The sleeve stop may engage the ring stop in a high flow state.', 'The indexing ring may extend less than 10% of length of the piston.', 'In some embodiments, a method for operating an indexing mechanism includes moving a piston from a first longitudinal piston position to a second longitudinal piston position, and rotating at least one of an indexing sleeve or an indexing ring relative to the piston to a first indexing alignment.', 'The indexing sleeve encases less than an entirety of the piston and the indexing ring surrounds a portion of the indexing sleeve.', 'The first indexing alignment aligns a ring stop on the indexing ring with a first sleeve stop on the indexing sleeve such that the first sleeve stop engages the ring stop in the second longitudinal piston position.', 'The method may include moving the piston from the second longitudinal piston position to a third longitudinal piston position that is between the first longitudinal piston position and the second longitudinal piston position.', 'The method may include rotating at least one of the indexing sleeve or the indexing ring relative to the piston to a second indexing alignment.', 'The method may also include moving the piston from the third longitudinal piston position to a fourth longitudinal piston position that is further from the first longitudinal piston position than the second longitudinal piston position.', 'The method may include rotating at least one of the indexing sleeve or the indexing ring relative to the piston to a third indexing alignment, the third indexing alignment aligns the ring stop with a second sleeve stop such that the second sleeve stop contacts the ring stop in the fourth longitudinal piston position.', 'The method may include rotating at least one of the indexing sleeve or the indexing ring by rotating the indexing ring relative to the indexing sleeve.', 'The method may include rotating at least one of the indexing sleeve or the indexing ring by rotating the indexing sleeve in a first direction and rotating the indexing ring in a second direction that is different than the first direction.', 'The embodiments of the indexing mechanism have been primarily described with reference to wellbore drilling operations; the indexing mechanisms described herein may be used in applications other than the drilling of a wellbore.', 'In other embodiments, indexing mechanisms according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources.', 'For instance, indexing mechanisms of the present disclosure may be used in a borehole used for placement of utility lines.', 'Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.', 'One or more specific embodiments of the present disclosure are described herein.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'The articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements in the preceding descriptions.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'The scope of the disclosure is, therefore, indicated by the appended claims rather than by the foregoing description.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.']

['1.', 'A downhole tool, comprising:\na piston;\nan indexing sleeve encasing a portion of the piston, the indexing sleeve being rotatable relative to the piston, the indexing sleeve including an indexing track; and\nan indexing ring surrounding less than an entirety of the indexing sleeve, the indexing ring being rotatable relative to the piston in operation of the downhole tool, the indexing ring including an indexing pin, the indexing pin extending into the indexing track.', '2.', 'The downhole tool of claim 1, the indexing ring being rotatable relative to the indexing sleeve.', '3.', 'The downhole tool of claim 1, the indexing sleeve being longitudinally movable relative to the indexing ring.', '4.', 'The downhole tool of claim 1, the indexing sleeve being longitudinally fixed to the piston.', '5.', 'The downhole tool of claim 1, the indexing sleeve and the indexing ring rotating relative to the piston in response to a longitudinal motion of the piston.', '6.', 'The downhole tool of claim 1, the indexing sleeve and the indexing ring rotating relative to the piston in response to the indexing pin engaging the indexing track.', '7.', 'The downhole tool of claim 1, the indexing ring having a mass of 2 kg or less and the indexing sleeve having a mass of 8 kg or less.', '8.', 'The downhole tool of claim 1, the indexing ring and the indexing sleeve having a mass ratio of less than 1:4.\n\n\n\n\n\n\n9.', 'The downhole tool of claim 1, the indexing track including a first sleeve stop and a second sleeve stop.', '10.', 'The downhole tool of claim 9, the first sleeve stop engaging a ring stop in first longitudinal piston position and the first sleeve stop engaging a ring support in a second longitudinal piston position, the second longitudinal piston position being further uphole than the first longitudinal piston position.', '11.', 'A method for operating an indexing mechanism, comprising:\nmoving a piston from a first longitudinal piston position to a second longitudinal piston position; and\nrotating at least one of an indexing sleeve or an indexing ring relative to the piston to a first indexing alignment, the indexing sleeve encasing less than an entirety of the piston and the indexing ring surrounding a portion of the indexing sleeve, the first indexing alignment aligning a ring stop on the indexing ring with a first sleeve stop on the indexing sleeve such that the first sleeve stop engages the ring stop in the second longitudinal piston position.', '12.', 'The method of claim 11, further comprising:\nmoving the piston from the second longitudinal piston position to a third longitudinal piston position, the third longitudinal piston position being between the first longitudinal piston position and the second longitudinal piston position; and\nrotating at least one of the indexing sleeve or the indexing ring relative to the piston to a second indexing alignment.', '13.', 'The method of claim 12, further comprising:\nmoving the piston from the third longitudinal piston position to a fourth longitudinal piston position, the fourth longitudinal piston position being further from the first longitudinal piston position than the second longitudinal piston position; and\nrotating at least one of the indexing sleeve or the indexing ring relative to the piston to a third indexing alignment, the third indexing alignment aligning the ring stop with a second sleeve stop such that the second sleeve stop contacts the ring stop in the fourth longitudinal piston position.\n\n\n\n\n\n\n14.', 'The method of claim 11, wherein rotating at least one of the indexing sleeve or the indexing ring includes rotating the indexing ring relative to the indexing sleeve.', '15.', 'The method of claim 11, wherein rotating at least one of the indexing sleeve or the indexing ring includes rotating the indexing sleeve in a first direction and rotating the indexing ring in a second direction, the first direction being different than the second direction.', '16.', 'A downhole tool, comprising:\na piston;\nan indexing sleeve encasing a portion of the piston, the indexing sleeve being rotatable relative to the piston, the indexing sleeve including an indexing track; and\nan indexing ring surrounding less than an entirety of the indexing sleeve, the indexing ring being rotatable relative to the piston, the indexing ring including an indexing pin, the indexing pin extending into the indexing track;\nwherein the indexing sleeve and the indexing ring rotating relative to the piston in response to a longitudinal motion of the piston.\n\n\n\n\n\n\n17.', 'The downhole tool of claim 16, the indexing ring being rotatable relative to the indexing sleeve.', '18.', 'The downhole tool of claim 16, the indexing sleeve being longitudinally movable relative to the indexing ring.', '19.', 'The downhole tool of claim 15, the indexing sleeve being longitudinally fixed to the piston.', '20.', 'The downhole tool of claim 16, the indexing ring and the indexing sleeve having a mass ratio of less than 1:4.']

['FIG.', '1 is a partial cut-away view of a drilling system, according to at least one embodiment of the present disclosure;; FIG.', '2-1 is a perspective view of an indexing mechanism, according to at least one embodiment of the present disclosure;; FIG.', '2-2 is a cross-sectional view of a downhole tool including the indexing mechanism of FIG.', '2-1, according to at least one embodiment of the present disclosure;; FIG. 3 is a cross-sectional view of an indexing mechanism, according to at least one embodiment of the present disclosure;; FIG.', '4-1 is a view of an indexing track, according to at least one embodiment of the present disclosure;; FIG.', '4-2 is another view of an indexing track, according to at least one embodiment of the present disclosure;; FIG.', '5-1 is a perspective view of an indexing mechanism, according to at least one embodiment of the present disclosure;; FIG.', '5-2 is a cross-sectional view of a downhole tool including the indexing mechanism of FIG.', '2-2, according to at least one embodiment of the present disclosure;; FIG.', '6 is a perspective view of an indexing mechanism, according to at least one embodiment of the present disclosure;; FIG.', '7-1 is a perspective view of another indexing mechanism, according to at least one embodiment of the present disclosure;; FIG.', '7-2 is a cross sectional view of a downhole tool including the indexing mechanism of FIG.', '7-1, according to at least one embodiment of the present disclosure;; FIG. 8 is a cross-sectional view of another indexing mechanism, according to at least one embodiment of the present disclosure; and; FIG.', '9 is a method chart of a method for operating an indexing mechanism, according to at least one embodiment of the present disclosure.; FIG.', '2-1 is a perspective view of a representation of a indexing mechanism 212, according to at least one embodiment of the present disclosure.', 'The indexing mechanism 212 may include a piston 214.', 'An indexing sleeve 216 may encase a portion of the piston 214.', 'In other words, the indexing sleeve 216 may surround at least a portion of the piston 214.', 'In some embodiments, the indexing sleeve 216 may encase less than an entirety of the piston 214.', 'In at least one embodiment, the indexing sleeve 216 may be coaxial with the piston 214 about a longitudinal axis 217.', 'The indexing sleeve 216 may include an indexing track 218.', 'The indexing track 218 may include a series of walls and/or tracks on the indexing sleeve 216.; FIG.', '2-2 is a cross-sectional view of a downhole tool 213, including a cross-sectional view of the indexing mechanism 212 of FIG.', '2-1.', 'The downhole tool 213 includes a housing 228.', 'A piston 214 may be located inside a central bore 230 of the housing 228.', 'An indexing sleeve 216 may encompass less than an entirety of the piston 214.', 'In other words, an inner surface 232 of the indexing sleeve 216 may abut an outer surface 234 of the piston 214.; FIG.', '3 is a close-up cross-sectional view of an indexing mechanism 312, according to at least one embodiment of the present disclosure.', 'The indexing mechanism 312 may include a housing 328.', 'A piston 314 may be located in a central bore 330 of the housing 328.', 'An indexing sleeve 316 may encompass at least less than an entirety of the piston 314.', 'In other words, the indexing sleeve 316 may surround a portion of the piston 314.', 'The indexing sleeve may be longitudinally fixed to the piston 314 by an upper sleeve block 352-1 and a lower sleeve block 352-2.', 'The upper sleeve block 352-1 and the lower sleeve block 352-2 may prevent the indexing sleeve 316 from moving longitudinally relative to the piston 314.', 'For example, when the piston 314 moves downhole (i.e., toward the lower sleeve block 352-2), the indexing sleeve 316 may push against the upper sleeve block 352-1.', 'Similarly, when the piston 314 moves uphole (i.e., toward the upper sleeve block 352-1), the indexing sleeve 316 may push against the lower sleeve block 352-2.; FIG.', '4-1 is a representation of an indexing track 418, according to at least one embodiment of the present disclosure.', 'The indexing track 418 may include a track 450 located between walls 424 in the indexing track 418.', 'An indexing pin 422 may be installed in a ring stop (e.g., the ring stop 356 of FIG.', '3) of an indexing ring (e.g., indexing ring 220 of FIG.', '2-1).', 'The indexing pin may extend into the track 450 at a first longitudinal piston position 464-1 (e.g., the position shown in FIG.', '2-1 and FIG.', '2-2).', 'As an indexing sleeve (e.g., the indexing sleeve 216 of FIG.', '2-1), in which the indexing track 418 is located, is moved downhole, the indexing pin 422 may follow a first indexing pin path 466-1.', 'The walls 424 may direct the indexing pin 422 until the piston (e.g., piston 214 of FIG.', '2-2) and the indexing sleeve are stopped a second longitudinal piston position 464-2.', 'This may occur, for instance, when the fluid flow (e.g., the fluid flow 244 of FIG.', '2-2) is increased to a high flow state.', 'A first sleeve stop 462-1 may engage a ring stop and stop downhole movement of the piston and the indexing sleeve at the second longitudinal piston position 464-2.; FIG.', '4-2 is a representation of the indexing track 418 of FIG.', '4-1, according to at least one embodiment of the present disclosure.', 'The indexing track 418 may include a track 450 located between walls 424 in the indexing track 418.', 'An indexing pin 422 may extend into the track 450 at a first longitudinal piston position 464-1.', 'As the flow is increased from the low flow state to the high flow state, the piston and the indexing sleeve are moved downhole, the indexing pin 422 may follow a second indexing pin path 466-2.', 'The second indexing pin path 466-2 may follow the same initial path as the first indexing pin path 466-1 shown in FIG.', '4-1 until the piston and the indexing sleeve are in the second longitudinal piston position 464-2.; FIG.', '5-1 is a representation of an indexing mechanism 512, according to at least one embodiment of the present disclosure.', 'The indexing mechanism 512 may be in the second longitudinal piston position (e.g., second longitudinal piston position 464-2 of FIG.', '4-1).', 'As a piston 514 and an indexing sleeve 516 are moved into the second longitudinal position, one or both of the indexing sleeve 516 and an indexing ring 520 may be rotated to place the indexing sleeve 516 and the indexing ring 520 in a first indexing alignment.', 'In the first indexing alignment (and the second longitudinal piston position) a first sleeve stop 562-1 may be aligned to contact a ring stop 536 on the indexing ring 520.', 'An indexing pin inserted into a track 550 of an indexing track 518.', 'Thus, the first sleeve stop 562-1 may be located uphole of the ring stop 536.; FIG.', '5-2 is a cross-sectional view of a downhole tool 513, including a cross-sectional view of the indexing mechanism 512 of FIG.', '5-1.', 'In the embodiment shown, the indexing mechanism 512 is in the second longitudinal piston position and the first indexing alignment.', 'Thus, the ring stop 536 may be contacting the first sleeve stop 562-1, thereby blocking downhole movement of the piston 514 and the indexing sleeve 516.', 'While the fluid flow 544 is in a high flow state, the piston 514 may be blocking a channel opening 543 to a fluid path 540.', 'This may prevent the downhole tool 513 from actuating (i.e., prevent an expandable member from expanding.)', '; FIG.', '6 is a perspective view of an indexing mechanism 612 in a third longitudinal piston position, according to at least one embodiment of the present disclosure.', 'As a piston 614 and an indexing sleeve 616 are moved into the third longitudinal piston position, the indexing ring 620 and the indexing sleeve 616 are rotated into a second indexing alignment.', 'An indexing pin 622 connected to a ring stop 636 on the indexing ring 620 may be inserted into a track 650 of an indexing track 618.', 'In the second indexing alignment, the ring stop 650 may be misaligned with either a first sleeve stop 662-1 or a second sleeve stop 662-2.; FIG.', '7-1 is a perspective view of an indexing mechanism 712 in a fourth longitudinal piston position, according to at least one embodiment of the present disclosure.', 'As a piston 714 and an indexing sleeve 716 are moved into the fourth longitudinal piston position, at least one of an indexing ring 720 and/or the indexing sleeve are rotated into a third indexing alignment.', 'An indexing pin 722 connected to a ring stop 736 on the indexing ring 720 may be inserted into a track 750 of an indexing track 718.', 'In the fourth longitudinal piston position and the third indexing alignment, the first ring stop (e.g., first ring stop 562-1 of FIG.', '5-2) may engage a ring support between two ring stops 736 on the indexing ring.', 'In the same or other embodiments, a second sleeve stop 762-2 may engage the ring stop 736.', 'The ring stop 736 may prevent further downhole movement of the piston 714 and the indexing sleeve 716.; FIG.', '7-2 is a cross-sectional view of a downhole tool 713, including a cross-sectional view of the indexing mechanism 712 of FIG.', '7-1, according to at least one embodiment of the present disclosure.', 'In the embodiment shown, the piston 714 and the indexing sleeve 716 are in the fourth longitudinal piston position.', 'As may be seen, the piston 714 has uncovered the channel opening 743, thereby allowing a portion 770 of fluid from the fluid flow 744 to enter the fluid path 740.', 'The portion 770 of fluid may be directed to actuate a downhole tool, such as an expandable tool.', 'In the fourth longitudinal piston position, the first ring stop may engage a ring support between two ring stops 736 on the indexing ring.', 'In the same or other embodiments, a ring stop 736 on the indexing ring 720 may engage the second sleeve stop 762-2 on the indexing sleeve 716, thereby preventing further downhole movement of the piston 714 and the indexing sleeve 716.; FIG. 8 is a cross-sectional view of a downhole tool 813, according to at least one embodiment of the present disclosure.', 'The downhole tool 813 may include an indexing mechanism 812.', 'The indexing mechanism 812 may include a piston 814.', 'An indexing ring 820 may surround at least a portion of the piston 814 and be rotatable relative to the piston 814.', 'The indexing ring 820 may be secured to a ring support 858 secured to the piston 814.', 'The ring support 858 may be longitudinally secured to the piston 814 such that as the piston 814 moves longitudinally, the indexing ring 820 may move longitudinally.', 'Thus, the indexing ring 820 may be longitudinally fixed to the piston 814.; FIG.', '9 is a method chart of a method 976 for operating an indexing mechanism.', 'The method 976 may include moving a piston from a first longitudinal piston position to a second longitudinal piston position at 978.', 'Moving the piston may include moving an indexing sleeve from the first longitudinal piston position to the second longitudinal piston position, the indexing sleeve encasing at least a portion of the piston.', 'Moving the piston may include increasing a fluid flow from a first flow rate to a second flow rate, the second flow rate being higher than the first flow rate.']

US11933155

Systems and methods for processing produced oilfield brine

Aug 3, 2021

Dean Willberg

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent Application No. PCT/US2021/044269 dated Nov. 8, 2021; 10 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2021/044269 dated Feb. 16, 2023, 7 pages.

9140109; September 22, 2015; Suarez-Rivera; 10451075; October 22, 2019; Mann; 20080047326; February 28, 2008; McCann; 20080237141; October 2, 2008; Kerfoot; 20080299635; December 4, 2008; Pfeiffer; 20160180475; June 23, 2016; Phillips; 20160244349; August 25, 2016; St. John; 20160339354; November 24, 2016; Govindan; 20170057843; March 2, 2017; Cioanta; 20170114271; April 27, 2017; Hudgens; 20190300410; October 3, 2019; Katz

2010077895; July 2010; WO

['A method of receiving a plurality of oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation is provided.', 'The method includes detecting, using one or more sensors, one or more properties of the plurality of oilfield brine feedstocks, selecting two or more oilfield brine feedstocks from the plurality based at least in part on the one or more properties of the plurality of oilfield brine feedstocks, blending the two or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating and crystallizing a portion of the blended oilfield brine, desalinating and crystallizing the portion of the blended oilfield brine to produce desalinated water and a salt slurry suspension, selecting one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells, and reinjecting the salt slurry suspension into the one or more candidate wells.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCES TO RELATED APPLICATIONS', 'This patent application is a National Stage Entry of International Application No. PCT/US2021/044269, filed Aug. 3, 2021, which (i) claims priority to and the benefit of U.S. Provisional Patent Application Ser.', 'No. 63/060,500, entitled “Systems and Methods for Stress Diversion,” filed Aug. 3, 2020, and (ii) claims priority to and the benefit of U.S. Provisional Patent Application Ser.', 'No. 63/073,263, entitled “Systems And Methods For Facilitating High-Efficiency Saltwater Disposal Wells,” filed Sep. 1, 2020, both of which are hereby incorporated by reference in their entireties for all purposes.', 'BACKGROUND\n \nThe present disclosure generally relates to various methods for processing produced oilfield brine.', 'This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present techniques, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as an admission of any kind.', 'Large volumes of saline and hypersaline brine are co-produced with oil from most formations around the world.', 'The volume of brine produced in fact exceeds that of oil—often by large margins—for most active onshore fields.', 'This brine is usually too saline for either surface discharge or surface reuse without relatively complex treatment and desalination operations that remove residual organics, dissolved salts, hydrogen sulfide and residual production chemicals.', 'Fortunately, in most conventional oil fields, this brine can be processed and reinjected back into the producing formation from whence it came for pressure maintenance, water flooding, or enhanced oil recovery (EOR) operations.', 'However, if reuse is not an option, then disposal of this water into ancillary formations through saltwater disposal (SWD) wells is the common practice.', 'SUMMARY\n \nA summary of certain embodiments described herein is set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'Certain embodiments of the present disclosure include a method that includes receiving one or more oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation.', 'The method also includes desalinating and at least partially crystallizing a portion of the one or more oilfield brine feedstocks to produce desalinated water and a salt slurry suspension.', 'The method further includes selecting, using a process control system, one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'In addition, the method includes reinjecting the salt slurry suspension into the one or more candidate wells.', 'In addition, certain embodiments of the present disclosure include an oilfield brine processing system that includes a desalination/crystallization system configured to receive one or more oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation, and to desalinate and at least partially crystallize a portion of the one or more oilfield brine feedstocks to produce desalinated water and a salt slurry suspension.', 'The oilfield brine processing system also includes a salt slurry suspension preparation system configured to prepare the salt slurry suspension, and to provide the salt slurry suspension to one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'In addition, certain embodiments of the present disclosure include an oilfield brine processing system that includes a desalination/crystallization system configured to receive one or more oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation, and to desalinate and at least partially crystallize a portion of the one or more oilfield brine feedstocks to produce desalinated water and a salt slurry suspension.', 'The oilfield brine processing system also includes a salt slurry suspension preparation system configured to prepare the salt slurry suspension, and to provide the salt slurry suspension to one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'The oilfield brine processing system further includes a process control system configured to select the one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'In addition, certain embodiments of the present disclosure include a method that includes receiving one or more oilfield brine feedstocks from one or more hydrocarbon-producing wells.', 'The method also includes pumping at least a portion of the one or more oilfield brine feedstocks through a desalination system using pressure generated by a pumping system.', 'The method further includes desalinating the at least a portion of the one or more oilfield brine feedstocks using the desalination system to produce desalinated water and saltwater.', 'In addition, the method includes injecting the saltwater into one or more saltwater disposal (SWD) wells using the pressure generated by the pumping system.', 'In addition, certain embodiments of the present disclosure include a water handling and disposal (WHD) system that includes one or more SWD wells configured to inject saltwater into a subterranean SWD formation.', 'The WHD system also includes a desalination system configured to desalinate at least a portion of the one or more oilfield brine feedstocks received from one or more hydrocarbon-producing wells to produce desalinated water and saltwater.', 'The WHD system further includes a pumping system configured to generate pressure to pump the at least a portion of the one or more oilfield brine feedstocks through the desalination system and to inject the saltwater produced by the desalination system into the one or more SWD wells.', 'In addition, the WHD system includes a process control system configured to control a composition of the saltwater injected into the one or more SWD wells based at least in part on one or more properties of the one or more oilfield brine feedstocks detected by one or more sensors.', 'In addition, certain embodiments of the present disclosure include a method that includes receiving one or more oilfield brine feedstocks from one or more hydrocarbon-producing wells.', 'The method also includes using a pumping system to inject at least a portion of the one or more oilfield brine feedstocks into one or more SWD wells.', 'The method further includes actively controlling, using a process control system, a composition of the at least a portion of the one or more oilfield brine feedstocks injected into the one or more SWD wells based at least in part on one or more properties of the one or more oilfield brine feedstocks detected by one or more sensors.', 'Various refinements of the features noted above may be undertaken in relation to various aspects of the present disclosure.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'The brief summary presented above is intended to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings, in which:\n \nFIG.', '1\n illustrates a well site having a drilling rig positioned above a subterranean formation that includes one or more oil and/or gas reservoirs, in accordance with embodiments of the present disclosure;\n \nFIG.', '2\n illustrates a water handling and disposal (WHD) system whereby produced water from a plurality of well sites are disposed and handled by the WHD system, in accordance with embodiments of the present disclosure;\n \nFIG.', '3\n illustrates an example well site having a plurality of wells, which may utilize an oilfield brine processing system, in accordance with embodiments of the present disclosure;\n \nFIG.', '4\n is a schematic diagram of the oilfield brine processing system of \nFIG.', '3\n, in accordance with embodiments of the present disclosure;\n \nFIG.', '5\n is a schematic diagram of a process control system of the oilfield brine processing system of \nFIG.', '4\n, in accordance with embodiments of the present disclosure;\n \nFIG.', '6\n is a schematic diagram of a treatment selection/design system of the oilfield brine processing system of \nFIG.', '4\n, in accordance with embodiments of the present disclosure;\n \nFIG.', '7\n is a block diagram of a method of processing oilfield brine, in accordance with embodiments of the present disclosure;\n \nFIG.', '8\n is a schematic diagram of the oilfield brine processing system of \nFIG.', '4\n having three-way valves for selectively directing oilfield brine feedstocks, in accordance with embodiments of the present disclosure;\n \nFIG.', '9\n illustrates three distinct operations of a WHD system, which may be performed independently or jointly, in accordance with embodiments of the present disclosure;\n \nFIG.', '10\n illustrates a WHD system configured to receive oilfield brine from hydrocarbon-producing wells and to process and dispose of portions of the oilfield brine using the operations illustrated in \nFIG.', '9\n, in accordance with embodiments of the present disclosure;\n \nFIG.', '11\n is a schematic diagram of the WHD system of \nFIG.', '10\n, which includes the coupling of high-pressure desalination technologies, such as reverse osmosis (RO), with SWD operations, in accordance with embodiments of the present disclosure;\n \nFIG.', '12\n is a schematic diagram of the WHD system of \nFIG.', '10\n, which includes at least a portion of a desalination system disposed within one or more wellbores of one or more SWD wells, in accordance with embodiments of the present disclosure;\n \nFIG.', '13\n is a schematic diagram of the WHD system of \nFIG.', '11\n with the addition of active management of SWD water composition at the rock face through dual stream (e.g., split-stream) injection into one or more SWD wells, in accordance with embodiments of the present disclosure;\n \nFIG.', '14\n is a schematic diagram of the WHD system of \nFIG.', '13\n with the addition of coupled SWD injection, flow assurance, and stimulation to minimize formation damage and injection pressures, in accordance with embodiments of the present disclosure;\n \nFIG.', '15\n is a schematic diagram of a process control system of the WHD system of \nFIGS.', '11\n-\n14\n, in accordance with embodiments of the present disclosure; and\n \nFIG.', '16\n is a block diagram of a method of processing oilfield brine using the WHD system of \nFIGS.', '11\n-\n14\n, in accordance with embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'One or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'As used herein, the terms “connect,” “connection,” “connected,” “in connection with,” and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element.”', 'Further, the terms “couple,” “coupling,” “coupled,” “coupled together,” and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements.”', 'As used herein, the terms “up” and “down,” “uphole” and “downhole”, “upper” and “lower,” “top” and “bottom,” and other like terms indicating relative positions to a given point or element are utilized to more clearly describe some elements.', 'Commonly, these terms relate to a reference point as the surface from which drilling operations are initiated as being the top (e.g., uphole or upper) point and the total depth along the drilling axis being the lowest (e.g., downhole or lower) point, whether the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.', 'As used herein, a fracture shall be understood as one or more cracks or surfaces of breakage within rock.', 'In general, fractures may have higher permeability than the surrounding rock, especially when they are filled with sand or ceramic proppants to withstand closure under formation stress; therefore fractures can be induced mechanically (e.g., hydraulically) in some reservoirs in order to boost hydrocarbon flow.', 'When fractures are created in a formation by pressurized fluid that is used to carry and place solid state material into the fracture, and that material remains in the fracture, the additional material causes additional stress in the formation.', 'Certain fractures may also be referred to as natural fractures to distinguish them from fractures induced as part of a reservoir stimulation.', 'Fractures can also be grouped into fracture clusters (or “perf clusters”) where the fractures of a given fracture cluster (perf cluster) connect to the wellbore through a single perforated zone.', 'As used herein, the term “fracturing” or “hydraulic fracturing” refers to the process and methods of breaking down a geological formation and creating a fracture (i.e., the rock formation around a wellbore) by pumping fluid at relatively high pressures (e.g., pressure above the determined closure pressure of the formation) in order to increase production rates from a hydrocarbon reservoir.', 'In addition, as used herein, the terms “real time”, “real-time”, or “substantially real time” may be used interchangeably and are intended to described operations (e.g., computing operations) that are performed without any human-perceivable interruption between operations.', 'For example, as used herein, data relating to the systems described herein may be collected, transmitted, and/or used in control computations in “substantially real time” such that data readings, data transfers, and/or data processing steps occur once every second, once every 0.1 second, once every 0.01 second, or even more frequent, during operations of the systems (e.g., while the systems are operating).', 'In addition, as used herein, the terms “automatic” and “automated” are intended to describe operations that are performed are caused to be performed, for example, by a process control system (i.e., solely by the process control system, without human intervention).', 'It is generally the case that most oil and gas wells produce water (e.g., formation water, and returned hydraulic fracturing fluid) along with hydrocarbons at some time during their productive life.', 'Both the produced water and the returned injected hydraulic fracturing fluid or “flowback” (e.g., usually 15-50% of the initial volume returns, typically, gradually amalgamating with formation water) are deemed oilfield wastes and are, therefore, subject to regulatory constraints on handling and disposal.', 'For example, \nFIG.', '1\n illustrates a well site \n10\n having a drilling rig \n12\n positioned above a subterranean hydrocarbon-producing formation \n14\n that includes one or more hydrocarbon reservoirs \n16\n.', 'During operation of the illustrated well, a derrick and a hoisting apparatus of the drilling rig \n12\n may raise and lower a drilling string \n18\n into and out of a wellbore \n20\n of a well \n22\n to drill the wellbore \n20\n into the subterranean hydrocarbon-producing formation \n14\n, as well as to position downhole well tools within the wellbore \n20\n to facilitate completion and production operations of the well.', 'The drilling rig \n12\n is also used to place steel casing strings that line the wellbore \n20\n, and also to facilitate cementing and perforating operations.', 'For example, subsequent to drilling and casing operations, in certain circumstances, a hydraulic fracturing fluid may be introduced into the well \n22\n through the casing, as illustrated by arrow \n24\n, which may be used to create fractures \n26\n in the subterranean hydrocarbon-producing formation \n14\n to facilitate production of oil and/or gas resources from the well.', 'As described in greater detail herein, the produced water and the returned injected hydraulic fracturing fluid may be returned to the surface \n28\n of the well site \n10\n (e.g., through the casing of the wellbore \n20\n), as illustrated by arrow \n30\n.', 'Subsequent to drilling, well construction, and hydraulic fracturing operations, both water and hydrocarbons are produced to the surface \n28\n through production tubing, pumps, and completions hardware installed in the wellbore \n20\n.', 'As described in greater detail herein, for certain hydrocarbon-producing wells \n22\n, the produced water may be referred to as oilfield brine insofar as the produced water contains relatively high levels of dissolved salts.', 'The dissolved salts in oilfield brine contain many different cationic (e.g., sodium, potassium, magnesium, calcium, strontium, barium, iron, and so forth) and anionic (e.g., chloride, fluoride, sulfate, carbonate, bicarbonate, silicate, and so forth) species.', 'The concentrations of the different species may be highly variable, depending on the formation \n14\n from whence they were produced, and on the construction, fracturing, and production history of the well \n22\n, but concentrations of the various salts may range from very low, all the way to fully saturated.', 'However, managing oilfield brine may be problematic in the certain regions (e.g., the Delaware basin of west Texas and southeast New Mexico) due to exceedingly large volumes of fluids produced, and their large aerial extent.', 'In \n2019\n, for example, it has been estimated that approximately 9 billion barrels of brine was produced in the Delaware basin.', 'Although the Delaware basin is used as an example, the embodiments described herein are applicable to any applications worldwide wherever large volumes of produced brines are managed.', 'Due at least in part to the relatively high volumes produced, there are relatively few options for managing produced oilfield brine in the Delaware basin.', 'For example, certain unconventional formations are too impermeable for conventional water flooding and pressure maintenance operations.', 'The timescale for water injection into these formations—at pressures below the fracturing gradient (i.e., the pressure required to induce fractures in rock at a given depth, for example, the pressure gradient at which a specific formation interval breaks down and accepts fluid) and at any meaningful flow rates—would be much for too long.', 'Furthermore, very few collocated conventional oilfield operations exist in the Delaware basin that could accept any meaningful additional volumes of produced water for their own waterflooding and pressure maintenance operations.', '“Recycling” the produced water as fracturing fluids is a third option that, while important, can only absorb a portion of the total produced water, and its capacity depends on drilling and fracturing activity.', 'In such situations, operators often contract for disposal and handling of the oilfield brine with a midstream specialist firm focused on water handling and disposal (WHD).', 'For example, \nFIG.', '2\n illustrates a WHD system \n32\n whereby oilfield brine from a plurality of well sites \n10\n are disposed and handled by the WHD system \n32\n.', 'As illustrated, in certain embodiments, handling of the oilfield brine is done via a relatively capital expenditure-intensive and usually proprietary network of pipelines \n34\n, pumping stations \n36\n, treatment facilities \n38\n, storage tanks \n40\n, trucks \n42\n, and so forth.', "The WHD firm's existing physical infrastructure network exists to accept, convey, treat, and disperse/dispose of oilfield brine.", 'Disposal of oilfield brine is often via reinjection into a salt-water disposal (SWD) well \n44\n, often after treatment to remove potentially harmful scaling ions and/or solids as the SWD owner dictates (e.g., to preserve injectivity to maintain the SWD well \n44\n).', 'Depending on circumstances, owners of the WHDs may also own SWD wells \n44\n or may simply pay a per-barrel fee to an SWD owner for disposal.', 'Regardless, operators of the wells at the well sites \n10\n must plan for cost-efficient disposal of all oilfield brine for each project and each well.', 'Currently, SWD wells are the preponderant reliable option to manage produced water in the Delaware Basin.', 'The receiving geological formation at the end of an SWD well \n44\n provides only one environmental service—it is a container that functions as the last receptacle for the waste brine.', 'Unfortunately, these SWD wells \n44\n and their associated disposal formations have two serious limitations.', 'First, they can only accept a limited volume of fluid, and they can only accept it at a limited rate—otherwise their formation pressures may exceed safe operating levels.', 'Currently, it is not known whether the SWD capacity in the Delaware basin is enough to accept all of the projected produced water at a reasonable price.', 'Second, SWD wells \n44\n and their receiving formations may be strained to the point of potential catastrophic consequences if overused.', 'Since brine has extremely low compressibility, the pore pressures in the receiving geological formations rise with the volume of brine injected over time.', 'This elevated pore pressure could potentially cause breakouts on new wells as they are drilled through formations near the SWD wells \n44\n.', 'Alternative “disposal”, or better stated “re-use”, technologies that divert significant volumes of produced brine away from, and reduce the reliance on, SWD wells \n44\n could have significant economic value.', 'This value is amplified if these new technologies provide additional value-added services beyond environmental containment of the produced brine.', 'Embodiments of the present disclosure describe systems and methods wherein the produced brine is deconstructed into two parts, and both parts are used to provide useful services for oilfield operations in addition to the environmental containment of the salt.', 'Returning now to \nFIG.', '1\n, the first part is a stream of desalinated water (e.g., either in the liquid or vapor phase, as described in greater detail herein) pure enough for beneficial use on the surface \n28\n, or for surface discharge.', 'Second, a salt slurry—composed of solid salts and saturated brine—is created that may be reinjected into the producing formation \n14\n from whence it came.', 'Reinjected into its home formation \n14\n, the salt slurry may be placed to provide stress diversion services that assist in infill drilling and long-term field development.', 'For example, in certain embodiments, the salt slurry may be reinjected into its home formation \n14\n to create stresses and strains in the formation \n14\n that help stimulate the formation \n14\n.', 'The present disclosure generally relates to processing produced oilfield brine.', 'In particular, the embodiments described herein include two main categories of embodiments.', 'For example, the embodiments illustrated and described with reference to \nFIGS.', '3\n-\n8\n generally relate to processing produced oilfield brine by deconstructing it into two useful components: (1) desalinated water and (2) a suspension of solid-state salt (e.g., crystallized salt) slurried in a salt-saturated brine for reinjection back into a formation from which it was originally produced.', 'In addition, the embodiments illustrated and described with reference to \nFIGS.', '9\n-\n16\n generally relate to processing oilfield brine received from hydrocarbon-producing wells by: (1) coupling high-pressure desalination technologies with SWD operations, (2) active management of SWD water composition at the rock face through dual stream (e.g., split-stream) injection, and/or (3) coupled SWD injection, flow assurance, and stimulation to minimize SWD formation damage and injection pressures.', 'It will be appreciated that the embodiments illustrated and described with reference to \nFIGS.', '3\n-\n8\n may be combined with the embodiments illustrated and described with reference to \nFIGS.', '9\n-\n16\n in certain scenarios.', 'The embodiments described herein include systems and methods for processing produced oilfield brine by deconstructing it into two useful components, and subsequently using those two components independently for beneficial purposes.', 'By converting the produced water waste stream into these two useful components, the need for SWD wells \n44\n may be reduced and possibly even eliminated.', 'The first component produced in this process is desalinated water that is either used or disposed of on the surface \n28\n.', 'The value of purified water is obvious, especially in arid regions where sourcing and transporting water is relatively expensive.', 'As used herein, the term “desalinated water” is intended to mean water that has been desalinated, and that exists in a liquid phase, a vapor phase (e.g., water evaporated from the salt suspension), or some combination thereof.', 'The second component is a suspension of solid-state salt (e.g., crystallized salt) slurried in a salt-saturated brine, which may be used to beneficially stimulate the reservoir \n16\n, as described in greater detail herein.', 'In certain embodiments, the salt suspension may be formulated and injected into hydrocarbon-producing formations \n14\n above hydraulic fracturing pressure to intentionally create regions of localized high stress within the respective formations \n14\n.', 'In particular, in certain embodiments, the salt suspension may be reinjected back into the formation \n14\n from which it was originally produced.', 'One beneficial purpose of the intentionally stressed regions in the reservoir is to prevent adverse hydraulic fracture growth from daughter wells \n22\n into previously depleted zones during infill drilling programs.', 'As used herein, the term “parent wells” are intended to mean wells \n22\n that are drilled into a reservoir \n16\n earlier in time, and “daughter wells” are intended to mean wells \n22\n that are drilled into a reservoir \n16\n later in time (i.e., after associated “parent wells”).', 'FIG.', '3\n illustrates an example well site \n10\n having a plurality of wells \n22\n, which may utilize an oilfield brine processing system \n46\n, as described in greater detail herein.', 'As illustrated in \nFIG.', '3\n, in certain embodiments, a well site \n10\n may include a plurality of hydrocarbon-producing wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE and a plurality of non-producing wells \n22\nF, \n22\nG, \n22\nH. In certain embodiments, oilfield brine \n48\n produced by one or more of the producing wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE may be conveyed (e.g., via pipelines \n34\n) to the oilfield brine processing system \n46\n for processing into relatively clean water \n50\n and a salt slurry suspension \n52\n, which may then be conveyed (e.g., via pipelines \n34\n) to one or more of the wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE, \n22\nF, \n22\nG, \n22\nH for reinjection back into the formation(s) \n14\n underneath the well site \n10\n, as described in greater detail herein.', 'Although described herein as often reinjecting the salt slurry suspension back into the formation(s) \n14\n underneath the well site \n10\n via one or more non-producing wells \n22\nF, \n22\nG, \n22\nH, in other embodiments, the salt slurry suspension may instead be reinjected back into the formation(s) \n14\n via one or more producing wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE.', 'For example, in certain embodiments, the salt slurry suspension may instead be reinjected back into one or more non-producing regions of one or more producing wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE.', 'In addition, in certain embodiments, the salt slurry suspension may instead be reinjected into one or more new wells \n22\n to improve fracturing of the one or more new wells \n22\n.\n \nFIG.', '4\n is a schematic diagram of the oilfield brine processing system \n46\n of \nFIG.', '3\n.', 'As illustrated, in certain embodiments, the oilfield brine processing system \n46\n may receive a plurality of oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE (e.g., from a plurality of respective producing wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE via pipelines \n34\n, as illustrated in \nFIG. \n3\n) and may select one or more of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE produced in the field for processing.', 'For example, in certain embodiments, a process control system \n54\n may use corresponding sensors \n56\nA, \n56\nB, \n56\nC, \n56\nD, \n56\nE to detect certain properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE and, based at least in part on the detected properties, may actuate (e.g., send control signals to open/close) corresponding valves \n58\nA, \n58\nB, \n58\nC, \n58\nD, \n58\nE to control blending of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE for delivery to a desalination/crystallization system \n60\n, which may be used to transform the blended oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE into relatively clean water \n50\n and a salt slurry suspension \n52\n for reinjection, as described in greater detail herein.', 'The desalination/crystallization system \n60\n may utilize any desalination/crystallization processes, such as salt crystallization and zero liquid discharge (ZLD) technologies (or even evaporation ponds).', 'In addition, although a plurality of valves \n58\nA, \n58\nB, \n58\nC, \n58\nD, \n58\nE are illustrated in \nFIG.', '4\n as controlling the blending of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE, in other embodiments, other processing equipment, such as pumps, heating elements, and so forth, may be actuated to at least partially control the blending of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE.\n \nOnce the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE have been selected for processing by the process control system \n54\n and blended based on the control of the corresponding valves \n58\nA, \n58\nB, \n58\nC, \n58\nD, \n58\nE (or other processing equipment), the resulting blended oilfield brine delivered to the desalination/crystallization system \n60\n may be desalinated and at least partially crystallized into the relatively clean water \n50\n and the salt slurry suspension \n52\n for reinjection, as described in greater detail herein.', 'In certain embodiments, once the salt slurry suspension \n52\n has been produced by the desalination/crystallization system \n60\n, the salt slurry suspension \n52\n may be further prepared for reinjection using a salt slurry suspension preparation system \n62\n, as described in greater detail herein.', 'In certain embodiments, delivery of the flow of the salt slurry suspension \n52\n from the desalination/crystallization system \n60\n to the salt slurry suspension preparation system \n62\n may be controlled by the process control system \n54\n by actuating (e.g., sending control signals to open/close) a valve \n64\n disposed between the desalination/crystallization system \n60\n and the salt slurry suspension preparation system \n62\n.', 'Although illustrated in \nFIG. \n4\n as including a process whereby the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE are separated into relatively clean water \n50\n and a salt slurry suspension \n52\n by a desalination/crystallization system \n60\n, then the salt slurry suspension \n52\n is further prepared for reinjection using a salt slurry suspension preparation system \n62\n, other processing techniques may be used in other embodiments.', 'For example, in certain embodiments, salt crystals may first be removed from the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE (e.g., using a dehydration system), and then ground into the right particle size and mixed into a salt slurry suspension \n52\n.', 'In certain embodiments, a treatment selection/design system \n65\n may select one or more wells \n22\n from a pool of one or more candidates wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE, \n22\nF, \n22\nG, \n22\nH (e.g., based on stress requirements for future field development, local rock mechanics and stress conditions, general hydraulic fracturing concepts, and so forth) for reinjection of the resulting prepared salt slurry suspension \n52\n from the salt slurry suspension preparation system \n62\n, as described in greater detail herein.', 'For example, in certain embodiments, the treatment selection/design system \n65\n may analyze the formation(s) \n14\n and/or associated reservoir(s) \n16\n underneath the well site \n10\n that includes the wells \n22\n for potential stress diversion treatments for which the resulting prepared salt slurry suspension \n52\n may be used.', 'In addition, in certain embodiments, the treatment selection/design system \n65\n may analyze the water quality at or near the well site \n10\n, among other parameters, to determine potential stress diversion treatments for which the resulting prepared salt slurry suspension \n52\n may be used.', 'In certain embodiments, based at least in part on determined stress diversion treatments, the process control system \n54\n may adjust the blending of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE to modify the prepared salt slurry suspension \n52\n produced by the desalination/crystallization system \n60\n and the salt slurry suspension preparation system \n62\n for the purpose of further engineering the prepared salt slurry suspension \n52\n for the determined stress diversion treatments, as described in greater detail herein.', 'Finally, the prepared salt slurry suspension \n52\n may be conveyed (e.g., via pipelines \n34\n, as illustrated in \nFIG.', '3\n, or by truck) to a selected candidate wells \n22\n (i.e., wells \n22\n that are candidates to receive the salt slurry suspension \n52\n) for reinjection into the formation(s) \n14\n underneath the well site \n10\n including the wells \n22\n.', 'As illustrated in \nFIG.', '4\n, in certain embodiments, one or more pumps \n66\n may be used to pump the prepared salt slurry suspension \n52\n to the selected candidate wells \n22\n.', 'The embodiments described herein provide useful advantages over conventional systems.', 'In general, the “salt” and other harmful constituents in the produced water (e.g., the oilfield brine \n48\n) is sequestered back into the formation \n14\n from whence it came.', 'This is beneficial for both functional and regulatory reasons.', 'Functionally, the primary responsibility of oilfield brine management is to protect the environment and people by preventing contamination of the surface environment and groundwater with oilfield brine, oil, naturally occurring radioactive material (NORM), H\n2\nS and other hazardous materials.', 'The embodiments described herein provide a process by which salts and other constituents of oilfield brine \n48\n are effectively isolated from the surface environment where they can cause harm to the environment, agricultural resources, and human health.', 'From a regulatory perspective, the embodiments described herein create a new cyclical “cradle-to-cradle” method for managing salts and other harmful dissolved and solid species in oilfield brine \n48\n, and provide a logically consistent methodology for engaging with environmental, social and guidance (ESG) stakeholders.', 'Although potentially requiring changes in current regulations relating to the handling of oilfield waste, the embodiments described herein present a new way of thinking about brine management, and provide new systems and methods for better, safer, and more satisfactory means of fulfilling obligations to the environment and to the public.', 'In addition, the embodiments described herein divert produced brine away from SWD formations (e.g., such as the SWD wells \n44\n illustrated in \nFIG. \n2\n).', 'In particular, oilfield brine \n48\n processed by the oilfield brine processing system \n46\n will not be pumped into SWD formations.', 'Rather, in contrast, the embodiments described herein create a new, separate means of disposing/re-using produced water (e.g., the oilfield brine \n48\n) that does not stress existing SWD formations.', 'In addition, the embodiments described herein facilitate stress diversion stimulation of hydrocarbon-producing formations \n14\n.', 'Stress diversion (e.g., stress-shadowing) of hydraulic fractures is an understood and characterized phenomenon observed during oilfield completions and reservoir management operations.', 'Although stress shadowing is often viewed as a problem to be overcome, it has been recognized that creative utilization of this phenomenon may produce beneficial results, such as actively directing (e.g., manipulating) the direction of hydraulic fracture growth during subsequent completion operations in either the same well \n22\n, or in adjacent wells \n22\n in the altered stress region.', 'See, e.g., U.S. Pat.', 'No. 9,140,109 to Suarez-Rivera et al., which is incorporated herein by reference in its entirety.', 'The embodiments described herein reconfigure the salt slurry from being a hazardous waste into a useful component of a new service by reinjecting it into hydrocarbon-producing formations \n14\n.', 'In particular, the reinjected salt slurry suspension \n52\n may provide localized stress diversion that assists in rational field development, and in the placement of infill wells \n22\n for improved total hydrocarbon recovery.', 'In addition, injection of the salt slurry suspension \n52\n above the fracturing gradient may restress the formation \n14\n in the vicinity of a depleted well \n22\n or in a depleted region of a long horizontal well \n22\n by the creation of a stress shadow.', 'The embodiments described herein may also be used to prevent adverse fracture growth issues from nearby in-fill drilled wells \n22\n.', 'In addition, the embodiments described herein produce relatively clean (e.g., desalinated) water \n50\n, which may be used for oilfield or non-oilfield applications at the surface \n28\n of a well site \n10\n or may be safely disposed of in the environment.\n \nFIG.', '5\n is a schematic diagram of a process control system \n54\n of the oilfield brine processing system \n46\n of \nFIG.', '4\n.', 'As illustrated in \nFIG.', '5\n, in certain embodiments, the process control system \n54\n of the oilfield brine processing system \n46\n described herein may include one or more process control modules \n68\n (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, a process control module \n68\n executes on one or more processors \n70\n of the process control system \n54\n, which may be connected to one or more storage media \n72\n of the process control system \n54\n.', 'Indeed, in certain embodiments, the one or more process control modules \n68\n may be stored in the one or more storage media \n72\n of the process control system \n54\n.', 'In certain embodiments, the one or more processors \n70\n of the process control system \n54\n may include a microprocessor, a microcontroller, a processor module or subsystem, a programmable integrated circuit, a programmable gate array, a digital signal processor (DSP), or another control or computing device.', 'In certain embodiments, the one or more storage media \n72\n of the process control system \n54\n may be implemented as one or more non-transitory computer-readable or machine-readable storage media.', 'In certain embodiments, the one or more storage media \n72\n of the process control system \n54\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories; magnetic disks such as fixed, floppy and removable disks; other magnetic media including tape; optical media such as compact disks (CDs) or digital video disks (DVDs); or other types of storage devices.', 'Note that the computer-executable instructions and associated data of the process control module(s) \n68\n may be provided on one computer-readable or machine-readable storage medium of the storage media \n72\n of the process control system \n54\n, or alternatively, may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media are considered to be part of an article (or article of manufacture), which may refer to any manufactured single component or multiple components.', 'In certain embodiments, the one or more storage media \n72\n of the process control system \n54\n may be located either in the machine running the machine-readable instructions, or may be located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In certain embodiments, the processor(s) \n70\n of the process control system \n54\n may be connected to communication circuitry \n74\n of the process control system \n54\n to allow the process control system \n54\n to communicate with the desalination/crystallization system \n60\n and the salt slurry suspension preparation system \n62\n, as well as the various sensors \n56\n, valves \n58\n, \n64\n, pumps \n66\n of the oilfield brine processing system \n46\n, other processing equipment, and so forth, for the purpose of controlling operation of the oilfield brine processing system \n46\n, as described in greater detail herein.', 'In certain embodiments, the communication circuitry \n74\n of the process control system \n54\n may be, include, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'In certain embodiments, the communication circuitry \n74\n of the process control system \n54\n may also include a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).\n \nFIG.', '6\n is a schematic diagram of a treatment selection/design system \n65\n of the oilfield brine processing system \n46\n of \nFIG.', '4\n.', 'As illustrated in \nFIG.', '6\n, in certain embodiments, the treatment selection/design system \n65\n of the oilfield brine processing system \n46\n described herein may include one or more treatment selection/design modules \n75\n (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, a treatment selection/design module \n75\n executes on one or more processors \n70\n of the treatment selection/design system \n65\n, which may be connected to one or more storage media \n72\n of the treatment selection/design system \n65\n.', 'Indeed, in certain embodiments, the one or more treatment selection/design modules \n75\n may be stored in the one or more storage media \n72\n.', 'In certain embodiments, the one or more processors \n70\n of the treatment selection/design system \n65\n may include a microprocessor, a microcontroller, a processor module or subsystem, a programmable integrated circuit, a programmable gate array, a digital signal processor (DSP), or another control or computing device.', 'In certain embodiments, the one or more storage media \n72\n of the treatment selection/design system \n65\n may be implemented as one or more non-transitory computer-readable or machine-readable storage media.', 'In certain embodiments, the one or more storage media \n72\n of the treatment selection/design system \n65\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories; magnetic disks such as fixed, floppy and removable disks; other magnetic media including tape; optical media such as compact disks (CDs) or digital video disks (DVDs); or other types of storage devices.', 'Note that the computer-executable instructions and associated data of the treatment selection/design module(s) \n75\n may be provided on one computer-readable or machine-readable storage medium of the storage media \n72\n of the treatment selection/design system \n65\n, or alternatively, may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media are considered to be part of an article (or article of manufacture), which may refer to any manufactured single component or multiple components.', 'In certain embodiments, the one or more storage media \n72\n of the treatment selection/design system \n65\n may be located either in the machine running the machine-readable instructions, or may be located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In certain embodiments, the processor(s) \n70\n of the treatment selection/design system may be connected to communication circuitry \n74\n of the treatment selection/design system \n65\n to allow the treatment selection/design system \n65\n to communicate with the process control system \n54\n for the purpose of synchronizing operation of the oilfield brine processing system \n46\n (e.g., controlled by the process control system \n54\n) with the selection of candidate wells \n22\n (i.e., wells \n22\n that are candidates to receive the salt slurry suspension \n52\n) and designing of stress diversion treatments (e.g., performed by the treatment selection/design system \n65\n), as described in greater detail herein.', 'In certain embodiments, the communication circuitry \n74\n of the treatment selection/design system \n65\n may be, include, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'In certain embodiments, the communication circuitry \n74\n of the treatment selection/design system \n65\n may also include a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).', 'As described in greater detail herein, the tailoring of one of the products (e.g., the salt slurry suspension \n52\n) of the desalination/crystallization process for subsequent reservoir stimulation by stress diversion provides benefits over conventional oilfield systems.', 'In particular, the embodiments described herein turn both a waste product (e.g., brine and salts), as well as the subterranean stresses created by this waste product, into useful components of a new service for improved hydrocarbon recovery.', 'In addition, the embodiments described herein place the salts and a portion of the water produced during production from a given formation \n14\n back into the same formation \n14\n from whence they came.', 'In addition, using the embodiments described herein may help balance out reservoir pressures and stresses in the formations \n14\n of interest and prevent over-pressuring of SWD formations (e.g., the SWD wells \n44\n illustrated in \nFIG. \n2\n).', 'Furthermore, the cyclical “cradle-to-cradle” approach of the present embodiments provides a logically consistent methodology for engaging with ESG stakeholders.\n \nFIG.', '7\n is a block diagram of a method \n78\n of processing oilfield brine \n48\n, as described in greater detail herein.', 'As illustrated in \nFIG.', '7\n, in certain embodiments, the method \n78\n may include selection and blending of one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE received from one or more corresponding hydrocarbon-producing wells \n22\nA, \n22\nB, \n22\nC, \n22\nD, \n22\nE of a well site \n10\n (block \n80\n).', 'As used herein, the term “salt” is used in its generic sense and refers to all of the total dissolved solid (TDS) inorganic species that are typically found in produced water brines.', 'Sodium chloride is usually the predominant constituent, but many other cations (e.g., calcium, magnesium, potassium, barium, and so forth) and anions (e.g., sulfate, bicarbonate, fluoride, and so forth) may be found dissolved in oilfield brines \n48\n as well, and may precipitate out as many different solid-state species.', 'Oilfield brines \n48\n are highly variable in the concentration of the TDS, and brine concentrations within certain regions may range from practically fresh water, all the way up to fully saturated brines.', 'In many oilfields, brines with concentrations ranging from 35,000 parts per million (ppm) to 150,000 ppm or more are common, depending on location and on the specific formation \n14\n.', 'In general, relatively higher concentration oilfield brines \n48\n may minimize the total energy requirements for desalination in the desalination/crystallization system of the oilfield brine processing system \n46\n.', 'Indeed, in certain embodiments, relatively lower concentration oilfield brines \n48\n may be directed for recycling as hydraulic fracturing fluids, as opposed to being processed by the desalination/crystallization system \n60\n and the salt slurry suspension preparation system \n62\n of the oilfield brine processing system \n46\n.', 'For example, as illustrated in \nFIG. \n8\n, in certain embodiments, the process control system \n54\n may determine that TDS concentrations of certain oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE are below a predetermined threshold (e.g., below 50,000 ppm, below 40,000 ppm, below 30,000 ppm, below ppm, below 10,000 ppm, or even lower) based at least in part on feedback from corresponding sensors \n56\nA, \n56\nB, \n56\nC, \n56\nD, \n56\nE, and may actuate (e.g., send control signals to open/close) corresponding three-way valves \n76\nA, \n76\nB, \n76\nC, \n76\nD, \n76\nE to direct those particular oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE for use as hydraulic fracturing fluids, as opposed to delivering those particular oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE to the desalination/crystallization system \n60\n of the oilfield brine processing system \n46\n.', 'Returning now to \nFIG.', '7\n, in certain embodiments, the method \n78\n may also include desalination and crystallization of a selected portion of the incoming oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE to produce relatively clean (e.g., desalinated) water \n50\n and a salt slurry suspension \n52\n (block \n82\n) using the desalination/crystallization system \n60\n of the oilfield brine processing system \n46\n to produce relatively clean water \n50\n and a salt slurry suspension \n52\n.', 'To avoid problems associated with the disposal of solid waste streams, conventional SWD practices avoid the precipitation of salts into the solid state.', 'In contrast, the embodiments described herein counter these conventional techniques by creating a use for the solid rock salt as a stress diverting agent.', 'The desalination/crystallization system \n60\n may utilize many different types of technologies suitable for desalination of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE, and for the subsequent crystallization of salts.', 'For example, in certain embodiments, the desalination/crystallization system \n60\n may utilize solar energy or evaporation ponds to keep energy costs relatively low.', 'In addition, in certain embodiments, the method \n78\n may include further preparation of the salt slurry suspension \n52\n produced by the desalination/crystallization system \n60\n (block \n84\n) using the salt slurry suspension preparation system \n62\n of the oilfield brine processing system \n46\n prior to reinjection.', 'The design and engineering of the salt slurry suspension \n52\n will follow steps similar to those used in designing conventional hydraulic fracturing operations (or drill-cuttings disposal operations), and many of the phenomena managed during fracturing operations will also be managed using the embodiments described herein.', 'However, additional considerations will also be managed using the embodiments described herein.', 'For example, solid-state rock salts are used (e.g., instead of sand or ceramic proppant) in the salt slurry suspension \n52\n.', 'In addition, the liquid phase will be a salt solution that in general “reacts” with the solid-state suspended rock salts.', 'Nominally, if a liquid phase solution exists with a suspension of rock salts for some time, then it will be either in an equilibrium or quasi-equilibrium condition with those solids.', 'However, this condition may be disturbed during pumping, and reactions between components of the liquid phase and the solids may possibly react as the salt slurry suspension \n52\n travels through different pressure and temperature regimes.', 'In addition, the salt slurry suspension \n52\n may possibly react with different formation rocks and, especially, in-situ reservoir brine when reinjected.', 'For example, since the salt slurry suspension \n52\n will be at saturated conditions, it could absorb water from the formation \n14\n due to osmotic pressure.', 'This could conceivably lead to an increase in fluid volume in the fracture (whereas, in normal fracturing operations, fluid volume within the fracture is lost due to leak-off into the porous rock) at some point in the fracturing or post-fracturing process, depending on the balance of applied hydraulic pressure and difference of chemical potentials in the pumped and in situ brines.', 'Certain practices and procedures may be followed using the embodiments described herein.', 'In the later stages of one embodiment of this invention, the salt slurry suspension \n52\n may be pumped downhole at pressures sufficiently high enough to create hydraulic fractures in the rock (i.e., that is at fracturing pressures in excess of the fracturing gradient).', 'In this embodiment, the operation resembles a conventional hydraulic fracturing operation, but instead of carrying sand or proppant, the fluid, a saturated salt solution, carries suspended solid state salt crystals.', 'One method of minimizing the operating cost of this embodiment would be to maximize the solids volume fraction of salt crystals in the salt slurry suspension \n52\n that is being pumped downhole.', 'However, when the solids volume fraction is too high for the given pumping and formation conditions, the risk of screen outs (extensive particle-particle-fracture well bridging) exists.', 'Screen outs can lead to excessive pressures and premature termination of the operation.', 'The variables involved in maximizing the solid volume fraction of a treatment include: 1) the particle size distribution of the solids, 2) the concentration of the solids, 3) the rheological properties of the fluid, 4) the pumping rate, and 5) the mechanical properties of the formation, and 5) the permeabilities of the formations being hydraulically fractured.', 'There is significant industrial knowledge, engineering methodologies, and software (such as the Kinetix suite of fracture design software) available for designing the solids volume fraction program for a conventional hydraulic fracturing fluid that can be safely pumped.', 'This knowledge from hydraulic fracturing may be used by the process control system \n54\n to set the material specifications for the salt slurry suspension \n52\n.', 'For example, the salt slurry suspension \n52\n may be specified by the process control system \n54\n to be comprised of very fine (e.g., less than 100 mesh, in certain embodiments) salt crystals.', 'Another method may be to specify a multimodal particle size distribution, which remains fluid at very high solids volume fraction.', 'The specifications for the salt slurry suspension \n52\n may then be used by the process control system \n54\n to set the equipment and operating requirements for the salt slurry suspension preparation system \n62\n of the oilfield brine processing system \n46\n.', 'In certain embodiments, a composition, concentration, viscosity, salinity, and/or density of dissolved salts in the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE and the resulting salt slurry suspension \n52\n may be monitored by the process control system \n54\n throughout the processing of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE by the oilfield brine processing system \n46\n to properly calculate, for example, appropriate bottom hole pressures during reinjection of the salt slurry suspension \n52\n.', 'To that end, as illustrated in \nFIGS.', '4\n and \n8\n, in certain embodiments, the desalination/crystallization system \n60\n and the salt slurry suspension preparation system \n62\n may include sensors \n56\n similar to the sensors \n56\nA, \n56\nB, \n56\nC, \n56\nD, \n56\nE that detect certain properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of corresponding oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE to detect similar properties of the salt slurry suspension \n52\n during processing via the desalination/crystallization system \n60\n and the salt slurry suspension preparation system \n62\n.', 'In general, it is relatively important that the solid state salts and the liquid phase of the salt slurry suspension \n52\n are either: 1) close to chemical equilibrium during the pumping operation, or 2) that any dissolution or precipitation reactions that occur do not cause a lock-up of the salt slurry suspension \n52\n during pumping (i.e., that they do not set up the salt slurry suspension \n52\n like a cement).', 'In certain embodiments, the reactive behavior of the salt slurry suspension \n52\n may be modeled by the process control system \n54\n using tools like OLI StreamAnalyzer (e.g., for predicting chemical composition and phase behavior, and so forth) coupled with reservoir and fracturing simulator inputs of temperature and pressure transients during operations.', 'Once the composition and phase behaviors of the salt slurry suspension \n52\n are modeled and predicted by the process control system \n54\n, the salt slurry suspension \n52\n may be tuned by adding chemical additives (e.g., acids and bases to adjust the pH, scale inhibitors to control the rate of precipitation reactions, and so forth) to the salt slurry suspension \n52\n within the salt slurry suspension preparation system \n62\n based on control signals from the process control system \n54\n to ensure that the salt slurry suspension \n52\n behaves well during operations.', 'Returning now to \nFIG.', '7\n, in certain embodiments, the method \n78\n may also include selection of candidate wells \n22\n for stress diversion treatments using the salt slurry suspension \n52\n (block \n86\n), which may be engineered by the process control system \n54\n of the oilfield brine processing system \n46\n.', 'The problem of “frac-hits” between daughter and parent wells \n22\n, whereby hydraulic fractures in daughter wells \n22\n grow into the depleted pressure region of parent wells \n22\n, has relatively recently become a problem for infill drilling campaigns and field development in general.', 'In such situations, not only is the production from the parent well \n22\n negatively impacted, but fresh rock is often bypassed, and not stimulated.', 'Using the embodiments described herein, the depleted wells \n22\n, or regions of the depleted wells \n22\n, may be re-fractured with the salt slurry suspension \n52\n produced by the oilfield brine processing system \n46\n.', 'Since the salt slurry suspension \n52\n will fill the hydraulic fractures with solid salt when reinjected, the resultant fractures will create a stress shadow in the same manner as conventional fractures.', 'Furthermore, the liquid that leaks off in these operations will increase the local pore pressure as well.', 'Engineering workflows, tools, and software may be used by the process control system \n54\n for optimizing the engineering of stress diversion programs.', 'For example, tools such as Petrel, Visage, and the Kinetix series of hydraulic fracturing simulators may be used by the process control system \n54\n for recognition of candidate wells \n22\n and stress diversion treatment design.', 'As such, in certain embodiments, the process control system \n54\n may select one or more candidate wells \n22\n for reinjection of the salt slurry suspension \n52\n by determining one or more stress diversion treatments configured to create stress shadowing in the formation \n14\n to increase production (and/or to create favorable hydraulic fracturing conditions) from one or more producing wells \n22\n (or a future well to be drilled at the well site \n10\n).', 'Finally, in certain embodiments, the method \n78\n may include reinjection of the salt slurry suspension \n52\n into a formation \n14\n via a selected candidate well \n22\n (block \n88\n).', 'In certain embodiments, the salt slurry suspension \n52\n may be formulated and injected into hydrocarbon-producing formations \n14\n above hydraulic fracturing pressure to intentionally create regions of localized high stress.', 'The embodiments described herein may utilize stress diversion in many advantageous ways including, but not limited to, creating intentionally stressed regions in a reservoir \n16\n to prevent adverse hydraulic fracture growth from daughter wells \n22\n during infill drilling programs.', 'In addition, the embodiments described herein also provide techniques that reconcile two conflicting requirements for efficient SWD operation: (1) judicious use of reservoir volume in the SWD asset, and (2) preserving injectivity of the SWD wells \n44\n.', 'First, from a chemistry perspective, SWD wells \n44\n exist to sequester the hazardous salts and chemicals that are dissolved in produced oilfield brine.', 'The water molecules themselves, H\n2\nO, are not a problem for either the surface environment or human health.', 'However, pumping dilute brines into SWD wells \n44\n with excess water not only wastes the storage space inside the receiving formation, but also wastes energy and may exacerbate reservoir pressures and stresses that degrade drilling conditions and induce seismicity.', 'Therefore, from a reservoir storage perspective, it is best to pump concentrated brines into SWD wells \n44\n.', 'As such, desalination technologies that effectively strip excess water from the brine before disposal may help preserve the lifespan of an SWD asset and mitigate the catastrophic consequences of over-pressuring the receiving formation.', "One additional benefit is that the desalinated water stripped from the produced brine by the embodiments described herein may be routed to beneficial uses at the earth's surface.", 'Since the water is desalinated, and since the harmful components are concentrated for sequestration in the SWD asset, this stripped water may be made safe for surface use or discharge.', 'The desalinated water, or “fresh” water produced by these embodiments may be used for multiple beneficial purposes, including industrial, agricultural, and environmental restoration.', 'This beneficial use of desalinated water at the surface is naturally coupled with the beneficial reduction of fluid volumes destined for a SWD asset, thereby increasing the economic value created by these embodiments.', 'However, a second key issue for maintaining SWD asset value is to preserve well injectivity and prevent reservoir damage—especially in the region immediately surrounding the wellbore.', 'In contrast to the storage perspective described above, this requirement proscribes a conservative approach towards managing total dissolved solid (TDS) composition and concentrations.', 'Injecting brines at TDSs near or exceeding their saturation point may easily lead to scale formation and the precipitation of suspended solids—both of which may damage the rock face permeability.', 'Furthermore, produced oilfield brines are expected to be highly variable in composition, therefore TDS concentration spikes, and upsets may be expected when the oilfield brines for the SWD well are sourced from many different hydrocarbon-producing wells \n22\n.', 'From this perspective, it is much better to inject more dilute brines into the SWD formation that are less susceptible to salt precipitation under highly variable conditions.', 'The embodiments described herein provide techniques that reconcile the above two conflicting requirements.', 'Furthermore, the embodiments described herein enable energy efficiency by coupling desalination with SWD operations.', 'In particular, as is illustrated in \nFIG.', '9\n, the embodiments described herein include three distinct operations \n90\n, \n92\n, \n94\n that may be operated independently or jointly.', 'All three operations \n90\n, \n92\n, \n94\n offer operational and economic benefits when practiced individually, but they are synergetic and may offer substantial gains in efficiency when practiced jointly.', 'Efficiency may be measured in three ways: (1) a reduction of the total energy required for both desalination and SWD operations, (2) a reduction in the total volume of water being injected into the targeted SWD formations while creating a desalinated stream of water for beneficial reuse, and (3) reduced permeability damage and, hence, reduced rock face pressures, within the SWD wells \n44\n while operating at relatively high TDS concentrations.', 'The first operation \n90\n of the three operations described herein is the coupling of high-pressure desalination technologies, such as membrane-based desalination technologies including, for example, reverse osmosis (RO), with SWD operations.', 'Although primarily described herein as utilizing RO-based technologies, in other embodiments, other types of desalination technologies may be utilized.', 'In general, relatively high pressures are required for both SWD well operations and for desalinating brine across RO membranes.', 'SWD operations normally operate at pressures above the formation hydrostatic pressure, and below the fracturing pressure of the SWD formation.', 'The pressures required for RO depend on the salinity (or, more correctly, the chemical potential of the water) being treated.', 'Much of the energy costs for both desalination and SWD operations are tied to the energy required to operate these pumps.', 'The embodiments described herein use the same pumps to generate pressures for both RO operations and SWD injection.', 'In certain embodiments, the RO membranes may be located between the pumping system and the SWD wellhead, upstream of the pumping system and the SWD wellhead, within a pumping system, within wellbores of SWD wells, or some combination thereof, where the RO membranes may skim off a stream of desalinated water (also useful for surface beneficial reuse) and, thereby, reduce the total volume of water being injected into the targeted disposal formation.', 'As used herein, the term “desalinated water” is intended to mean water from which a significant fraction of the salts has been removed, and that exists in a liquid phase, a vapor phase (e.g., water evaporated from the salt suspension), or some combination thereof.', 'One advantage of this is that it enables a fast response of the SWD system to rapidly changing source water salinities.', 'For example, if a high concentration slug of water enters the facility, it may be shuttled directly to the SWD well \n44\n and bypass the desalination unit.', 'Furthermore, in certain embodiments, reserved desalinated water from previous operations could be injected into the line to help prevent scale precipitation.', 'Alternatively, in certain embodiments, the RO facility may take more of the load when the feedstock produced water is dilute.', 'Under these conditions, desalinated water for beneficial reuse may be produced under energetically favorable conditions.', 'In certain embodiments, RO membranes may be located downhole to take advantage of the hydrostatic pressure in the wellbore.', 'The second operation \n92\n of the three operations described herein is active management of the SWD water composition at the rock face through dual stream (e.g., split-stream) injection.', 'In certain embodiments, two streams of water may be injected into the wellbore and/or formation.', 'The first stream, the bulk of the water, would be the high concentration stream, which is operated at a concentration close to, or in some cases in excess of, the precipitation concentration of the dissolved species.', 'The second stream (e.g., the control stream) would be a small flow rate of desalinated water (e.g., skimmed from the RO stream) to precisely control the composition of the water entering the rock face.', 'This dual stream configuration may be operated to maximize the amount of salt being disposed of in the formation, while minimizing the total volume of water needing disposal.', 'The third operation \n94\n of the three operations described herein is coupled SWD injection, flow assurance, and stimulation to minimize formation damage and injection pressures.', 'This operation is similar to the second operation \n92\n described above, but adds in chemical stimulation and scale prevention to: (1) improve control on the wellhead pressure of the injector well, and (2) minimize the impact of near-wellbore damage to the SWD formation immediately surrounding the SWD wellbore, so that any damage occurs further out in the SWD formation.', 'This operation may be performed either continuously or intermittently.', 'These three operations \n90\n, \n92\n, \n94\n reduce the total volume of fluids injected into SWD wells \n44\n, thereby prolonging the value of an SWD well asset.', 'Furthermore, the operations \n90\n, \n92\n, \n94\n provide a stream of desalinated water useful for surface operations.', 'In certain embodiments, these operations \n90\n, \n92\n, \n94\n may be predicated on detailed knowledge of the composition of water in the disposal stream, as described herein.', 'The overall energy efficiency of produced water management operations described herein may be improved by coupling RO desalination processes to SWD well injection, since both energy intensive processes require raising the working fluid to an elevated pressure.', 'Rather than dissipating much of the energy expended during desalination, the energy may be reused immediately to drive brine injection into an SWD well \n44\n.', 'The brine being injected into an SWD wellhead needs to be raised to an elevated pressure in order to overcome both the inherent reservoir pressure in the target SWD formation, and the rate-dependent opposing friction pressure generated by the fluid traveling down the wellbore of the SWD well \n44\n.', 'In RO desalination systems, a feed brine is effectively deconstructed into: 1) a low salinity or “fresh” desalinated water (or permeate), and 2) a high salinity “waste” brine (that is at a higher salinity than the feed brine.', 'The feed brine needs to be raised to an elevated pressure to overcome the chemical potential of water in the brine when driving a portion of the fluid across the semi-permeable membrane.', 'However, the high salinity “waste” brine also remains at an elevated high pressure and still contains the mechanical potential energy put into it when it was pressurized.', 'Since, in oilfield operations, this waste brine is eventually destined for injection into SWD wells \n44\n, it is economically beneficial not to waste this stored energy, but to use it to drive the brine down the SWD wellbore.', 'However, coupling RO desalination and SWD well operations is not trivial because the performance characteristics, and the pressure requirements, of both systems are highly dependent on feed brine composition, and the overall volumetric flow rates through the system.', 'This input into the system (see, e.g., \nFIG.', '11\n) is dynamic, and highly time-dependent and variable flowrates and composition of the brines coming from many wells \n22\n (\nFIG.', '10\n).', 'Furthermore, the ideal operating pressures (e.g., feed pressure, internal pressures, and output pressures) required for desalination and SWD injection are independent of each other.', 'For example, the wellhead pressure of an SWD well \n44\n generally depends on both the desired rate of injection, and on the composition and density of the brine being injected because of friction pressure in the wellbore of the SWD well \n44\n.', 'Likewise, the pressure required for RO operations depends in part on the quality (e.g., TDS, density, and so forth) of the feed brine.', 'The embodiments described herein balance SWD well operation and desalination operation requirements in substantially real time by the active control of 1) composition, 2) flow rates, and 3) pressures of the brine as it passes through the system (see, e.g., \nFIG. \n11\n).', 'A number of control operations manage the compositions, flow rates, and pressures of the brines at different points in the process.', 'One control operation selects and blends the composition of the feed brine for the desalination operation.', 'This operation selects produced brines from a plurality of hydrocarbon-producing wells, and blends the best possible composition for the desalination operation.', 'In certain embodiments, the produced brines from the plurality of hydrocarbon-producing wells may be pre-treated (e.g., removal of oil and grease, dissolved organics, chemical scale treatment, the addition of biocides, and so forth), either individually or in aggregate.', 'These pre-treatment steps may also be managed by the control operation.', 'The control operation also selects the brines that will bypass the desalination operation and be directly routed to an SWD well \n44\n.', 'A second control operation involves balancing flow rates and pressure requirements of the desalination system with the required flow rates and injection pressures at the SWD wellhead of an SWD well \n44\n.', 'The pressure system may use multiple components, and may involve pumps upstream of the desalination system, booster pumps between the desalination system and the wellhead, energy harvesting systems, and so forth.', 'Various chokes, check valves, pressure release values, backpressure regulators, and other flow control devices may also be used to manage the pressures at various points along the pressure system.', 'FIG.', '10\n illustrates a WHD system \n32\n configured to receive oilfield brine \n48\n from a plurality of hydrocarbon-producing wells \n22\n and to process and dispose of portions of the oilfield brine \n48\n using the operations \n90\n, \n92\n, \n94\n illustrated in \nFIG.', '9\n.', 'The oilfield brine \n48\n produced by the hydrocarbon-producing wells \n22\n may be conveyed (e.g., via pipelines \n34\n, in certain embodiments) to the WHD system \n32\n for processing and disposal (e.g., injection into one or more SWD wells \n44\n of the WHD system \n32\n), as described in greater detail herein.', 'In addition, as also described in greater detail herein, in certain embodiments, the oilfield brine \n48\n may be processed by the WHD system \n32\n to produce desalinated water \n96\n, which may be beneficially reused.', 'FIG.', '11\n is a schematic diagram of the WHD system \n32\n of \nFIG.', '10\n.', 'As illustrated, in certain embodiments, the WHD system \n32\n may receive a plurality of oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE (e.g., from a plurality of respective hydrocarbon-producing wells \n22\n via pipelines \n34\n, as illustrated in \nFIG. \n10\n) and may select one or more of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE produced in the field for processing.', 'For example, in certain embodiments, a process control system \n98\n may use corresponding sensors \n100\nA, \n100\nB, \n100\nC, \n100\nD, \n100\nE to detect certain properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE and, based at least in part on the detected properties, may actuate (e.g., send control signals to open/close) corresponding valves \n102\nA, \n102\nB, \n102\nC, \n102\nD, \n102\nE to control blending of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE for delivery to a desalination system \n104\n, which may be used to transform the blended oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE into desalinated water \n96\n and saltwater \n106\n for injection into one or more SWD wells \n44\n, as described in greater detail herein.', 'As used herein, the term “saltwater” is intended to mean any of the water sources described herein, such as the oilfield brines and other brines, which have an elevated salinity as compared to the desalinated water \n96\n.', 'The desalination system \n104\n may utilize high-pressure membrane-based desalination technologies, such as reverse osmosis (RO) in certain embodiments.', 'However, in other embodiments, the desalination system \n104\n may utilize other desalination processes, such as salt crystallization and zero liquid discharge (ZLD) technologies (or even evaporation ponds).', 'In addition, although a plurality of valves \n102\nA, \n102\nB, \n102\nC, \n102\nD, \n102\nE are illustrated in \nFIG.', '11\n as controlling the blending of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE, in other embodiments, other processing equipment, such as pumps, heating elements, and so forth, may be actuated by the process control system \n98\n to at least partially control the blending of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD,', '48\nE.\n \nOnce the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE have been selected for processing by the process control system \n98\n and blended based on the control of the corresponding valves \n102\nA, \n102\nB, \n102\nC, \n102\nD, \n102\nE (or other processing equipment), the resulting blended oilfield brine delivered to the desalination system \n104\n may be desalinated to produce the desalinated water \n96\n (e.g., for surface reuse) and the saltwater \n106\n (e.g., for injection into one or more SWD wells \n44\n), as described in greater detail herein.', 'In certain embodiments, delivery of the flow of the saltwater \n106\n from the desalination system \n104\n to the one or more SWD wells \n44\n may be controlled by the process control system \n98\n by actuating (e.g., sending control signals to) the pumping system \n108\n.', 'In the embodiment illustrated in \nFIG. \n11\n, the pumping system \n108\n includes one or more primary pumps \n108\nA located upstream of the desalination system \n104\n and the one or more SWD wells \n44\n and one or more booster pumps \n108\nB located downstream of the desalination system \n104\n but upstream of the one or more SWD wells \n44\n.', 'However, other embodiments of the pumping system \n108\n may include various other equipment including, but not limited to, energy harvesting systems, various chokes, check valves, pressure release values, backpressure regulators, and other flow control devices.', 'In addition, although illustrated in \nFIG. \n11\n as including a pumping system \n108\n that is separate from a desalination system \n104\n, in other embodiments, the pumping system \n108\n and the desalination system \n104\n may be at least partially integrated with each other.', 'Indeed, all of the equipment of the WHD system \n32\n illustrated in \nFIG.', '11\n may be integrated with (or separate from) each other in different combinations than illustrated, for all of the embodiments described herein.', 'For example, in certain embodiments, the valves \n102\n may be integrated into the pumping system \n108\n and/or the desalination system \n104\n.', 'It will be appreciated that the embodiment of the WHD system \n32\n illustrated in \nFIG.', '11\n illustrates the first operation \n90\n of the three operations described with respect to \nFIG.', '9\n, which includes the coupling of high-pressure desalination technologies, such as reverse osmosis (RO), with SWD operations.', 'As described above, in general, relatively high pressures are required to pump oilfield brines into SWD wells \n44\n.', 'In particular, SWD operations normally operate at pressures above the formation hydrostatic pressure, and below the fracturing pressure of the SWD formation.', 'In addition, relatively high pressures are also generally required for desalinating oilfield brines across RO membranes.', 'In general, the pressures required for RO depend on the salinity (or, more correctly, the chemical potential of the water) being treated.', 'Accordingly, much of the energy costs for both desalination and SWD operations are tied to the energy required to operate these pumps.', 'The embodiments described herein use the same pumping system \n108\n to generate pressures for both RO operations via the desalination system \n104\n and SWD injection into one or more SWD wells \n44\n, thereby reducing the total energy required for the combined desalination and SWD operations.', 'As illustrated in \nFIG.', '11\n, the desalination system \n104\n may skim off a stream of desalinated water \n96\n (e.g., useful for surface beneficial reuse) from the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE and, thereby, reduce the total volume of water being injected into the targeted SWD formation while also creating a desalinated stream of water \n96\n for beneficial reuse.', 'Accordingly, the WHD system \n32\n illustrated in \nFIG.', '11\n is capable of quickly responding to rapidly changing salinities of the oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE.', 'For example, in certain embodiments, if a particular oilfield brine feedstock \n48\n is received by the WHD system \n32\n, it may be delivered directly to an SWD well \n44\n for injection and bypass the desalination system \n104\n.', 'Furthermore, as illustrated in \nFIG.', '11\n, in certain embodiments, reserved desalinated water \n96\n from previous operations may be injected into the stream of saltwater \n106\n, as illustrated by arrow \n110\n, prior to injection of the saltwater \n106\n into one or more SWD wells \n44\n to help prevent scale precipitation.', 'In addition, although illustrated in \nFIG. \n11\n as being located upstream of the SWD well(s) \n44\n (e.g., at a surface location), in other embodiments, RO membranes (e.g., the desalination system \n104\n) may be located downhole within the SWD well(s) \n44\n to take advantage of the hydrostatic pressure in the wellbores of the SWD well(s) \n44\n.', 'For example, \nFIG.', '12\n is a schematic diagram of the WHD system \n32\n of \nFIG.', '10\n, which includes at least a portion of a desalination system \n104\n located within one or more wellbores of one or more SWD wells \n44\n.', 'In addition, in certain embodiments, at least a portion of the desalination system \n104\n may be located both at a surface location as well as within one or more wellbores of one or more SWD wells \n44\n.\n \nFIG.', '13\n is a schematic diagram of the WHD system \n32\n of \nFIG.', '11\n with the addition of the second operation \n92\n of the three operations described with respect to \nFIG.', '9\n, which includes active management of the SWD water composition at the rock face through dual stream (e.g., split-stream) injection into one or more SWD wells \n44\n.', 'In particular, as illustrated in \nFIG.', '13\n, in certain embodiments, two streams of water \n112\n, \n114\n may be injected into the wellbore(s) of one or more SWD wells \n44\n.', 'The first stream \n112\n (e.g., the saltwater \n106\n from the desalination system \n104\n), the bulk of the water, has a relatively high concentration of TDSs, which is operated at a concentration close to or, in some instances, in excess of, the precipitation concentration of the dissolved species.', 'The second stream \n114\n (e.g., the control stream) may be a small flow rate of desalinated water \n96\n (e.g., skimmed from the first stream by the desalination system \n104\n) to precisely control the compositions of the water \n112\n, \n114\n entering the rock face of the one or more SWD wells \n44\n.', 'The dual stream configuration illustrated in \nFIG.', '13\n may be operated by the process control system \n98\n to maximize the amount of salt being located in the formation(s) of one or more SWD wells \n44\n, while minimizing the total volume of water needing disposal.', 'For example, the process control system \n98\n may control alternating injection of the first and second streams \n112\n, \n114\n and/or metered (e.g., simultaneous) injection of the first and second streams \n112\n, \n114\n based on a ratio of the first and second streams \n112\n, \n114\n that is determined by the process control system \n98\n based at least in part on one or more properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE detected by one or more sensors \n100\n.', 'As illustrated in \nFIG.', '13\n, in certain embodiments, respective valves \n116\n, \n118\n may be controlled by the process control system \n98\n, for example, based on feedback relating to properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of the received oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE and/or the saltwater \n106\n produced by the desalination system \n104\n (e.g., as detected by the sensors \n100\nA, \n100\nB, \n100\nC, \n100\nD, \n100\nE and/or \n100\n, respectively).', 'In addition, in certain embodiments, one or more desalinated water pumps \n120\n may be controlled by the process control system \n98\n to pump desalinated water \n96\n (i.e., the second stream \n114\n) into the wellbore(s) of one or more SWD wells \n44\n, for example, alternatingly between injections of saltwater \n106\n (i.e., the first stream \n112\n) into the wellbore(s) of the one or more SWD wells \n44\n and/or in a metered fashion during injection of the saltwater \n106\n (i.e., the first stream \n112\n) into the wellbore(s) of the one or more SWD wells \n44\n.', 'As such, the composition, flow rates, and pressures of the two streams of water \n112\n, \n114\n may be actively controlled by the process control system \n98\n, for example, based at least in part on feedback relating to properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of the received oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE and/or the saltwater \n106\n produced by the desalination system \n104\n (e.g., as detected by the sensors \n100\nA, \n100\nB, \n100\nC, \n100\nD, \n100\nE and/or \n100\n, respectively).', 'As described herein, although illustrated in \nFIG.', '13\n as combining the first and second operations \n90\n, \n92\n of the three operations described with respect to \nFIG.', '9\n, in other embodiments, the dual stream configuration illustrated in \nFIG.', '13\n may be performed independently of the embodiment in \nFIG.', '11\n.', 'For example, in such an embodiment, one or more received oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE and desalinated water \n96\n from any water source may be controlled by the process control system \n98\n as the two streams of water \n112\n, \n114\n.', 'In other words, in certain embodiments, the active management of the two streams of water \n112\n, \n114\n illustrated in \nFIG.', '13\n may be performed with or without a desalination system \n104\n.\n \nFIG.', '14\n is a schematic diagram of the WHD system \n32\n of \nFIG.', '13\n with the addition of the third operation \n94\n of the three operations described with respect to \nFIG.', '9\n, which includes coupled SWD injection, flow assurance, and stimulation to minimize formation damage and injection pressures.', 'This operation is similar to the second operation \n92\n described herein, but adds in chemical stimulation and scale prevention processes \n122\n with respect to the SWD well(s) \n44\n, which may be controlled by the process control system \n98\n, to: (1) improve control on the wellhead pressure of the SWD well(s) \n44\n, and (2) minimize the impact of near-wellbore damage to the SWD formation immediately surrounding the SWD wellbore, so that any damage occurs further out in the SWD formation.', 'In certain embodiments, the chemical stimulation and scale prevention processes \n122\n may be performed either continuously or intermittently, for example, relative to the injection of saltwater \n106\n into the SWD well(s) \n44\n.', 'As described herein, although illustrated in \nFIG. \n14\n as combining the first, second, and third operations \n90\n, \n92\n, \n94\n of the three operations described with respect to \nFIG. \n9\n, in other embodiments, the chemical stimulation and scale prevention processes \n122\n illustrated in \nFIG.', '14\n may be performed independently of the embodiments in \nFIGS.', '11\n and \n13\n.', 'For example, in such an embodiment, the chemical stimulation and scale prevention processes \n122\n may be performed with respect to conventional saltwater injection into one or more SWD wells \n44\n.\n \nFIG.', '15\n is a schematic diagram of a process control system \n98\n of the WHD system \n32\n of \nFIGS.', '11\n-\n14\n.', 'As illustrated in \nFIG.', '15\n, in certain embodiments, the process control system \n98\n of the WHD system \n32\n described herein may include one or more process control modules \n124\n (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, a process control module \n124\n executes on one or more processors \n126\n of the process control system \n98\n, which may be connected to one or more storage media \n128\n of the process control system \n98\n.', 'Indeed, in certain embodiments, the one or more process control modules \n124\n may be stored in the one or more storage media \n128\n of the process control system \n98\n.', 'In certain embodiments, the one or more processors \n126\n of the process control system \n98\n may include a microprocessor, a microcontroller, a processor module or subsystem, a programmable integrated circuit, a programmable gate array, a digital signal processor (DSP), or another control or computing device.', 'In certain embodiments, the one or more storage media \n128\n of the process control system \n98\n may be implemented as one or more non-transitory computer-readable or machine-readable storage media.', 'In certain embodiments, the one or more storage media \n128\n of the process control system \n98\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories; magnetic disks such as fixed, floppy and removable disks; other magnetic media including tape; optical media such as compact disks (CDs) or digital video disks (DVDs); or other types of storage devices.', 'Note that the computer-executable instructions and associated data of the process control module(s) \n124\n may be provided on one computer-readable or machine-readable storage medium of the storage media \n128\n of the process control system \n98\n, or alternatively, may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media are considered to be part of an article (or article of manufacture), which may refer to any manufactured single component or multiple components.', 'In certain embodiments, the one or more storage media \n128\n of the process control system \n98\n may be located either in the machine running the machine-readable instructions, or may be located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In certain embodiments, the processor(s) \n126\n of the process control system \n98\n may be connected to communication circuitry \n130\n of the process control system \n98\n to allow the process control system \n98\n to communicate with the desalination system \n104\n, as well as the various sensors \n100\n, valves \n102\n, \n116\n, \n118\n, equipment of the pumping system \n108\n, the desalinated water pumps \n120\n, and other processing equipment of the WHD system \n32\n, and so forth, for the purpose of controlling operation of the WHD system \n32\n, as described in greater detail herein.', 'In certain embodiments, the communication circuitry \n130\n of the process control system \n98\n may be, include, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'In certain embodiments, the communication circuitry \n130\n of the process control system \n98\n may also include a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).', 'The one or more process control modules \n124\n, when executed by the one or more processors \n126\n of the process control system \n98\n, may cause the process control system \n98\n to perform various functions of the embodiments described herein.', 'For example, in certain embodiments, the process control system \n98\n may be configured to actuate (e.g., send control signals to) the desalination system \n104\n, as well as the various valves \n102\n, \n116\n, \n118\n, equipment of the pumping system \n108\n, the desalinated water pumps \n120\n, and other processing equipment of the WHD system \n32\n, and so forth, to control the composition of the saltwater \n106\n (and/or desalinated water \n96\n) injected into one or more SWD wells \n44\n based at least in part on one or more properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE detected by one or more sensors \n100\n, as described in greater detail herein.', 'In addition, in certain embodiments, the process control system \n98\n may be configured to select one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE from a plurality of oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE received from a plurality of hydrocarbon-producing wells \n22\n based at least in part on one or more properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of the one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE detected by one or more sensors \n100\n, as described in greater detail herein, and to actuate (e.g., send control signals to)', 'the valves \n102\n of the WHD system \n32\n to control blending of the one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE into a blended oilfield brine prior to desalinating the blended oilfield brine using the desalination system \n104\n to produce the desalinated water \n96\n and the saltwater \n106\n, as described in greater detail herein.', 'In addition, in certain embodiments, the process control system \n98\n may be configured to determine a ratio of the saltwater \n106\n produced by the desalination system \n104\n and previously-produced desalinated water \n96\n to be alternatingly injected (or, simultaneously injected in a metered, dual stream fashion) into one or more SWD wells \n44\n based at least in part on one or more properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE detected by one or more sensors \n100\n, and to actuate (e.g., send control signals to) the desalination system \n104\n, as well as the various valves \n102\n, \n116\n, \n118\n, equipment of the pumping system \n108\n, the desalinated water pumps \n120\n, and other processing equipment of the WHD system \n32\n, and so forth, to control the metered or alternating injection of the saltwater \n106\n and the previously-produced desalinated water \n96\n into the one or more SWD wells \n44\n based at least in part on the determined ratio, as described in greater detail herein.', 'In addition, in certain embodiments, the process control system \n98\n may be configured to control injection of chemicals and/or scale prevention additives into one or more SWD wells \n44\n based at least in part on one or more properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE detected by one or more sensors \n100\n, as described in greater detail herein.', 'FIG.', '16\n is a block diagram of a method \n132\n of processing oilfield brine \n48\n using the WHD system \n32\n, as described in greater detail herein.', 'As illustrated in \nFIG.', '16\n, in certain embodiments, the method \n132\n includes receiving (and, in certain embodiments, pre-treating) one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE from one or more hydrocarbon-producing wells \n22\n (block \n134\n).', 'In addition, in certain embodiments, the method \n132\n includes pumping the one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE through a desalination system \n104\n using pressure generated by the pumping system \n108\n (block \n136\n).', 'In addition, in certain embodiments, the method \n132\n includes desalinating the one or more oilfield brine feedstocks \n48\nA, \n48\nB, \n48\nC, \n48\nD, \n48\nE using the desalination system \n104\n to produce desalinated water \n96\n and saltwater \n106\n (block \n138\n).', 'In addition, in certain embodiments, the method \n132\n includes injecting the saltwater \n106\n into one or more SWD wells \n44\n using the pressure generated by the pumping system \n108\n (block \n140\n).', 'In addition, in certain embodiments, the method \n132\n optionally includes controlling dual stream injection of the saltwater \n106\n and previously-produced desalinated water \n96\n (e.g., via alternating injection and/or simultaneous metered injection) into the one or more SWD wells \n44\n using pressure generated by one or more desalinated water pumps \n120\n (block \n142\n).', 'In addition, in certain embodiments, the method \n132\n optionally includes injecting chemicals and/or scale prevention additives into the one or more SWD wells \n44\n (block \n144\n).', 'As described above, certain embodiments of the present disclosure include a method that includes receiving one or more oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation.', 'The method also includes desalinating and at least partially crystallizing a portion of the one or more oilfield brine feedstocks to produce desalinated water and a salt slurry suspension.', 'The method further includes selecting, using a process control system, one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'In addition, the method includes reinjecting the salt slurry suspension into the one or more candidate wells.', 'In certain embodiments, the method also includes selecting, using a process control system, the one or more oilfield brine feedstocks from a plurality of oilfield brine feedstocks received from a plurality of producing wells producing hydrocarbons from the subterranean formation; and blending the one or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating and at least partially crystallizing the blended oilfield brine to produce the desalinated water and the salt slurry suspension.', 'In addition, in certain embodiments, the method also includes detecting, using one or more sensors, one or more properties of the one or more oilfield brine feedstocks; and selecting, using the process control system, the one or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the one or more properties of the one or more oilfield brine feedstocks include composition, concentration, salinity, viscosity, and/or density of dissolved salts in the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the method also includes preparing the salt slurry suspension prior to reinjection into the one or more candidate wells.', 'In addition, in certain embodiments, preparing the salt slurry suspension includes adjusting a size of salt particles in the salt slurry suspension, adding one or more chemical additives to the salt slurry suspension, or some combination thereof, based at least in part on control signals received from a process control system.', 'In addition, in certain embodiments, desalinating and at least partially crystallizing the portion of the one or more oilfield brine feedstocks includes utilizing solar energy, evaporation ponds, zero liquid discharge technologies, or some combination thereof.', 'In addition, in certain embodiments, the method also includes reinjecting the salt slurry suspension into the one or more candidate wells above a fracturing gradient of the subterranean formation to create a hydraulic fracture in the subterranean formation that contains solid state salt crystals.', 'In addition, as described above, certain embodiments of the present disclosure include an oilfield brine processing system that includes a desalination/crystallization system configured to receive one or more oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation, and to desalinate and at least partially crystallize a portion of the one or more oilfield brine feedstocks to produce desalinated water and a salt slurry suspension.', 'The oilfield brine processing system also includes a salt slurry suspension preparation system configured to prepare the salt slurry suspension, and to provide the salt slurry suspension to one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'In certain embodiments, the oilfield brine processing system also includes a treatment selection/design system configured to select the one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'In addition, in certain embodiments, the salt slurry suspension preparation system is configured to adjust a size of salt particles in the salt slurry suspension, add one or more chemical additives to the salt slurry suspension, or some combination thereof, based at least in part on control signals received from a process control system.', 'In addition, in certain embodiments, the desalination/crystallization system utilizes solar energy, evaporation ponds, zero liquid discharge technologies, or some combination thereof.', 'In addition, in certain embodiments, the oilfield brine processing system also includes a process control system configured to select the one or more oilfield brine feedstocks from a plurality of oilfield brine feedstocks received from a plurality of producing wells producing hydrocarbons from the subterranean formation, and to send one or more control signals to blend the one or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating and at least partially crystallizing the blended oilfield brine using the desalination/crystallization system to produce the desalinated water and the salt slurry suspension.', 'In certain embodiments, the oilfield brine processing system also includes one or more sensors corresponding to the one or more oilfield brine feedstocks and configured to detect one or more properties of the one or more oilfield brine feedstocks, wherein the process control system is configured to select the one or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In certain embodiments, the one or more properties of the one or more oilfield brine feedstocks include composition, concentration, viscosity, and/or density of dissolved salts in the one or more oilfield brine feedstocks.', 'In addition, as described above, certain embodiments of the present disclosure include an oilfield brine processing system that includes a desalination/crystallization system configured to receive one or more oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation, and to desalinate and at least partially crystallize a portion of the one or more oilfield brine feedstocks to produce desalinated water and a salt slurry suspension.', 'The oilfield brine processing system also includes a salt slurry suspension preparation system configured to prepare the salt slurry suspension, and to provide the salt slurry suspension to one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'The oilfield brine processing system further includes a process control system configured to select the one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells.', 'In addition, in certain embodiments, the oilfield brine processing system also includes one or more sensors corresponding to the one or more oilfield brine feedstocks and configured to detect one or more properties of the one or more oilfield brine feedstocks, wherein the process control system is configured to select the one or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In certain embodiments, the one or more properties of the one or more oilfield brine feedstocks include composition, concentration, viscosity, salinity, and/or density of dissolved salts in the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the salt slurry suspension preparation system is configured to adjust a size of salt particles in the salt slurry suspension, add one or more chemical additives to the salt slurry suspension, or some combination thereof, based at least in part on control signals received from a process control system.', 'In addition, as described above, certain embodiments of the present disclosure include a method that includes receiving one or more oilfield brine feedstocks from one or more hydrocarbon-producing wells.', 'The method also includes pumping at least a portion of the one or more oilfield brine feedstocks through a desalination system using pressure generated by a pumping system.', 'The method further includes desalinating the at least a portion of the one or more oilfield brine feedstocks using the desalination system to produce desalinated water and saltwater.', 'In addition, the method includes injecting the saltwater into one or more SWD wells using the pressure generated by the pumping system.', 'In addition, in certain embodiments, at least a portion of the desalination system is located at a surface location associated with the one or more SWD wells.', 'In addition, in certain embodiments, at least a portion of the desalination system is located within one or more wellbores of the one or more SWD wells.', 'In addition, in certain embodiments, the desalination system includes one or more reverse osmosis (RO) membranes.', 'In addition, in certain embodiments, the method also includes selecting, using a process control system, the one or more oilfield brine feedstocks from a plurality of oilfield brine feedstocks received from a plurality of hydrocarbon-producing wells; and blending the at least a portion of the one or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating the blended oilfield brine using the desalination system to produce the desalinated water and the saltwater.', 'In addition, in certain embodiments, the method also includes detecting, using one or more sensors, one or more properties of the one or more oilfield brine feedstocks; and selecting, using the process control system, the one or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the one or more properties of the one or more oilfield brine feedstocks include composition, concentration, salinity, viscosity, and/or density of dissolved salts in the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the method also includes controlling dual stream injection of the saltwater and desalinated water into the one or more SWD wells.', 'In addition, in certain embodiments, the method also includes detecting, using one or more sensors, one or more properties of the one or more oilfield brine feedstocks; determining, using a process control system, a ratio of the saltwater and the desalinated water to be injected into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks; and controlling, using the process control system, the dual stream injection of the saltwater and the desalinated water into the one or more SWD wells based at least in part on the determined ratio.', 'In addition, in certain embodiments, the method also includes controlling, using the process control system, injection of chemicals and/or scale prevention additives into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the one or more properties of the one or more oilfield brine feedstocks include composition, concentration, salinity, viscosity, and/or density of dissolved salts in the one or more oilfield brine feedstocks.', 'In addition, as described above, certain embodiments of the present disclosure include a WHD system that includes one or more SWD wells configured to inject saltwater into a subterranean SWD formation.', 'The WHD system also includes a desalination system configured to desalinate at least a portion of the one or more oilfield brine feedstocks received from one or more hydrocarbon-producing wells to produce desalinated water and saltwater.', 'The WHD system further includes a pumping system configured to generate pressure to pump the at least a portion of the one or more oilfield brine feedstocks through the desalination system and to inject the saltwater produced by the desalination system into the one or more SWD wells.', 'In addition, the WHD system includes a process control system configured to control a composition of the saltwater injected into the one or more SWD wells based at least in part on one or more properties of the one or more oilfield brine feedstocks detected by one or more sensors.', 'In addition, in certain embodiments, at least a portion of the desalination system is located at a surface location associated with the one or more SWD wells.', 'In addition, in certain embodiments, at least a portion of the desalination system is located within one or more wellbores of the one or more SWD wells.', 'In addition, in certain embodiments, the WHD system also includes the desalination system includes one or more reverse osmosis (RO) membranes.', 'In addition, in certain embodiments, the one or more properties of the one or more oilfield brine feedstocks include composition, concentration, salinity, viscosity, and/or density of dissolved salts in the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the process control system is configured to select the one or more oilfield brine feedstocks from a plurality of oilfield brine feedstocks received from a plurality of hydrocarbon-producing wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks; and control one or more valves to blend at least a portion of the one or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating the blended oilfield brine using the desalination system to produce the desalinated water and the saltwater.', 'In addition, in certain embodiments, the process control system is configured to control dual stream injection of the saltwater and desalinated water into the one or more SWD wells based at least in part on one or more properties of the one or more oilfield brine feedstocks detected by one or more sensors.', 'In addition, in certain embodiments, the process control system is configured to determine a ratio of the saltwater and the desalinated water to be injected into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks; and control the dual stream injection of the saltwater and the desalinated water into the one or more SWD wells based at least in part on the determined ratio.', 'In addition, in certain embodiments, the process control system is configured to control injection of chemicals and/or scale prevention additives into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In addition, as described above, certain embodiments of the present disclosure include a method that includes receiving one or more oilfield brine feedstocks from one or more hydrocarbon-producing wells.', 'The method also includes using a pumping system to inject at least a portion of the one or more oilfield brine feedstocks into one or more SWD wells.', 'The method further includes actively controlling, using a process control system, a composition of the at least a portion of the one or more oilfield brine feedstocks injected into the one or more SWD wells based at least in part on one or more properties of the one or more oilfield brine feedstocks detected by one or more sensors.', 'In addition, in certain embodiments, actively controlling a composition of the at least a portion of the one or more oilfield brine feedstocks injected into the one or more SWD wells includes controlling, using the process control system, injection of chemicals and/or scale prevention additives into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the method also includes actively controlling a composition of the at least a portion of the one or more oilfield brine feedstocks injected into the one or more SWD wells includes controlling dual stream injection of the at least a portion of the one or more oilfield brine feedstocks and desalinated water into the one or more SWD wells.', 'In addition, in certain embodiments, the method also includes determining, using the process control system, a ratio of the at least a portion of the one or more oilfield brine feedstocks and the desalinated water to be injected into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks; and controlling, using the process control system, the dual stream injection of the at least a portion of the one or more oilfield brine feedstocks and the desalinated water into the one or more SWD wells based at least in part on the determined ratio.', 'In addition, in certain embodiments, the method also includes selecting, using the process control system, the one or more oilfield brine feedstocks from a plurality of oilfield brine feedstocks received from a plurality of hydrocarbon-producing wells; and blending the one or more oilfield brine feedstocks into a blended oilfield brine prior to injection of the blended oilfield brine into the one or more SWD wells.', 'In addition, in certain embodiments, the method also includes selecting, using the process control system, the one or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'In addition, in certain embodiments, the method also includes pumping the at least a portion of the one or more oilfield brine feedstocks through a desalination system prior to injection of the at least a portion of the one or more oilfield brine feedstocks into the one or more SWD wells; desalinating the at least a portion of the one or more oilfield brine feedstocks using the desalination system to produce desalinated water and saltwater; and actively controlling, using the process control system, the composition of the saltwater injected into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', 'The specific embodiments described above have been illustrated by way of example, and it should be understood that these embodiments may be susceptible to various modifications and alternative forms.', 'It should be further understood that the claims are not intended to be limited to the particular forms disclosed, but rather to cover all modifications, equivalents, and alternatives falling within the spirit and scope of this disclosure.']

['1.', 'A method, comprising:\nreceiving a plurality of oilfield brine feedstocks from one or more producing wells producing hydrocarbons from a subterranean formation;\ndetecting, using one or more sensors, one or more properties of the plurality of oilfield brine feedstocks;\nselecting two or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks based at least in part on the one or more properties of the plurality of oilfield brine feedstocks;\nblending the two or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating and crystallizing a portion of the blended oilfield brine;\ndesalinating and crystallizing the portion of the blended oilfield brine to produce desalinated water and a salt slurry suspension;\nselecting one or more candidate wells for reinjection of the salt slurry suspension into the one or more candidate wells; and\nreinjecting the salt slurry suspension into the one or more candidate wells.', '2.', 'The method of claim 1, wherein the one or more properties of the plurality of oilfield brine feedstocks comprise at least one of composition, concentration, salinity, viscosity, or density of dissolved salts in the plurality of oilfield brine feedstocks.', '3.', 'The method of claim 1, comprising preparing the salt slurry suspension prior to reinjection into the one or more candidate wells.\n\n\n\n\n\n\n4.', 'The method of claim 3, wherein preparing the salt slurry suspension comprises adjusting a size of salt particles in the salt slurry suspension, adding one or more chemical additives to the salt slurry suspension, or some combination thereof, based at least in part on control signals received from a process control system.', '5.', 'The method of claim 1, wherein desalinating and crystallizing the portion of the blended oilfield brine comprises utilizing solar energy, evaporation ponds, or some combination thereof.', '6.', 'The method of claim 1, comprising reinjecting the salt slurry suspension into the one or more candidate wells above a fracturing gradient of the subterranean formation to create a hydraulic fracture in the subterranean formation that contains solid state salt crystals.', '7.', 'A method, comprising:\nreceiving a plurality of oilfield brine feedstocks from one or more hydrocarbon-producing wells;\nselecting two or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks;\nblending the two or more oilfield brine feedstocks into a blended oilfield brine prior to desalinating the blended oilfield brine;\npumping a portion of the blended oilfield brine through a desalination system using pressure generated by a pumping system;\ndesalinating the portion of the blended oilfield brine to produce desalinated water and saltwater; and\ninjecting the saltwater into one or more saltwater disposal (SWD) wells using the pressure generated by the pumping system.', '8.', 'The method of claim 7, wherein at least a portion of the desalination system is located at a surface location associated with the one or more SWD wells.\n\n\n\n\n\n\n9.', 'The method of claim 7, wherein at least a portion of the desalination system is located within one or more wellbores of the one or more SWD wells.\n\n\n\n\n\n\n10.', 'The method of claim 7, wherein the desalination system comprises one or more reverse osmosis (RO) membranes.', '11.', 'The method of claim 7, comprising:\ndetecting, using one or more sensors, one or more properties of the plurality of oilfield brine feedstocks; and\nselecting the two or more oilfield brine feedstocks from the plurality of oilfield brine feedstocks based at least in part on the one or more properties of the plurality of oilfield brine feedstocks.', '12.', 'The method of claim 11, wherein the one or more properties of the plurality of oilfield brine feedstocks comprise at least one of composition, concentration, salinity, viscosity, or density of dissolved salts in the plurality of oilfield brine feedstocks.', '13.', 'The method of claim 7, comprising controlling injection of a first stream of the saltwater and a second stream of the desalinated water into the one or more SWD wells.\n\n\n\n\n\n\n14.', 'The method of claim 13, comprising:\ndetecting, using one or more sensors, one or more properties of the plurality of oilfield brine feedstocks;\ndetermining a ratio of the saltwater and the desalinated water to be injected into the one or more SWD wells based at least in part on the one or more properties of the plurality of oilfield brine feedstocks; and\ncontrolling injection of the first stream of the saltwater and the second stream of the desalinated water into the one or more SWD wells based at least in part on the determined ratio.', '15.', 'The method of claim 14, comprising controlling injection of at least one of chemicals or scale prevention additives into the one or more SWD wells based at least in part on the one or more properties of the plurality of oilfield brine feedstocks.', '16.', 'The method of claim 14, wherein the one or more properties of the plurality of oilfield brine feedstocks comprise at least one of composition, concentration, salinity, viscosity, or density of dissolved salts in the plurality of oilfield brine feedstocks.', '17.', 'A method, comprising:\nreceiving one or more oilfield brine feedstocks from one or more hydrocarbon-producing wells;\ndetecting, using one or more sensors, one or more properties of the one or more oilfield brine feedstocks;\npumping a portion of the one or more oilfield brine feedstocks through a desalination system using pressure generated by a pumping system;\ndesalinating the portion of the one or more oilfield brine feedstocks to produce desalinated water and saltwater;\ndetermining a ratio of the saltwater and the desalinated water to be injected into one or more saltwater disposal (SWD) wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks;\ninjecting a first stream of the saltwater and a second stream of the desalinated water into the one or more SWD wells using the pressure generated by the pumping system; and\ncontrolling the injection of the first stream of the saltwater and the second stream of the desalinated water into the one or more SWD wells based at least in part on the determined ratio.', '18.', 'The method of claim 17, comprising controlling injection of at least one of chemicals or scale prevention additives into the one or more SWD wells based at least in part on the one or more properties of the one or more oilfield brine feedstocks.', '19.', 'The method of claim 17, wherein the one or more properties of the one or more oilfield brine feedstocks comprise at least one of composition, concentration, salinity, viscosity, or density of dissolved salts in the one or more oilfield brine feedstocks.']

['FIG. 1 illustrates a well site having a drilling rig positioned above a subterranean formation that includes one or more oil and/or gas reservoirs, in accordance with embodiments of the present disclosure;; FIG.', '2 illustrates a water handling and disposal (WHD) system whereby produced water from a plurality of well sites are disposed and handled by the WHD system, in accordance with embodiments of the present disclosure;; FIG.', '3 illustrates an example well site having a plurality of wells, which may utilize an oilfield brine processing system, in accordance with embodiments of the present disclosure;; FIG.', '4 is a schematic diagram of the oilfield brine processing system of FIG.', '3, in accordance with embodiments of the present disclosure;; FIG. 5 is a schematic diagram of a process control system of the oilfield brine processing system of FIG.', '4, in accordance with embodiments of the present disclosure;; FIG.', '6 is a schematic diagram of a treatment selection/design system of the oilfield brine processing system of FIG.', '4, in accordance with embodiments of the present disclosure;; FIG. 7 is a block diagram of a method of processing oilfield brine, in accordance with embodiments of the present disclosure;; FIG. 8 is a schematic diagram of the oilfield brine processing system of FIG.', '4 having three-way valves for selectively directing oilfield brine feedstocks, in accordance with embodiments of the present disclosure;; FIG. 9 illustrates three distinct operations of a WHD system, which may be performed independently or jointly, in accordance with embodiments of the present disclosure;; FIG.', '10 illustrates a WHD system configured to receive oilfield brine from hydrocarbon-producing wells and to process and dispose of portions of the oilfield brine using the operations illustrated in FIG.', '9, in accordance with embodiments of the present disclosure;; FIG.', '11 is a schematic diagram of the WHD system of FIG.', '10, which includes the coupling of high-pressure desalination technologies, such as reverse osmosis (RO), with SWD operations, in accordance with embodiments of the present disclosure;; FIG.', '12 is a schematic diagram of the WHD system of FIG.', '10, which includes at least a portion of a desalination system disposed within one or more wellbores of one or more SWD wells, in accordance with embodiments of the present disclosure;; FIG. 13 is a schematic diagram of the WHD system of FIG.', '11 with the addition of active management of SWD water composition at the rock face through dual stream (e.g., split-stream) injection into one or more SWD wells, in accordance with embodiments of the present disclosure;; FIG.', '14 is a schematic diagram of the WHD system of FIG.', '13 with the addition of coupled SWD injection, flow assurance, and stimulation to minimize formation damage and injection pressures, in accordance with embodiments of the present disclosure;; FIG.', '15 is a schematic diagram of a process control system of the WHD system of FIGS.', '11-14, in accordance with embodiments of the present disclosure; and; FIG.', '16 is a block diagram of a method of processing oilfield brine using the WHD system of FIGS.', '11-14, in accordance with embodiments of the present disclosure.', '; FIG.', '3 illustrates an example well site 10 having a plurality of wells 22, which may utilize an oilfield brine processing system 46, as described in greater detail herein.', 'As illustrated in FIG.', '3, in certain embodiments, a well site 10 may include a plurality of hydrocarbon-producing wells 22A, 22B, 22C, 22D, 22E and a plurality of non-producing wells 22F, 22G, 22H.', 'In certain embodiments, oilfield brine 48 produced by one or more of the producing wells 22A, 22B, 22C, 22D, 22E may be conveyed (e.g., via pipelines 34) to the oilfield brine processing system 46 for processing into relatively clean water 50 and a salt slurry suspension 52, which may then be conveyed (e.g., via pipelines 34) to one or more of the wells 22A, 22B, 22C, 22D, 22E, 22F, 22G, 22H for reinjection back into the formation(s) 14 underneath the well site 10, as described in greater detail herein.; FIG. 4 is a schematic diagram of the oilfield brine processing system 46 of FIG.', '3.', 'As illustrated, in certain embodiments, the oilfield brine processing system 46 may receive a plurality of oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E (e.g., from a plurality of respective producing wells 22A, 22B, 22C, 22D, 22E via pipelines 34, as illustrated in FIG. 3) and may select one or more of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E produced in the field for processing.', 'For example, in certain embodiments, a process control system 54 may use corresponding sensors 56A, 56B, 56C, 56D, 56E to detect certain properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E and, based at least in part on the detected properties, may actuate (e.g., send control signals to open/close) corresponding valves 58A, 58B, 58C, 58D, 58E to control blending of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E for delivery to a desalination/crystallization system 60, which may be used to transform the blended oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E into relatively clean water 50 and a salt slurry suspension 52 for reinjection, as described in greater detail herein.', 'The desalination/crystallization system 60 may utilize any desalination/crystallization processes, such as salt crystallization and zero liquid discharge (ZLD) technologies (or even evaporation ponds).', 'In addition, although a plurality of valves 58A, 58B, 58C, 58D, 58E are illustrated in FIG.', '4 as controlling the blending of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E, in other embodiments, other processing equipment, such as pumps, heating elements, and so forth, may be actuated to at least partially control the blending of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E.; FIG.', '5 is a schematic diagram of a process control system 54 of the oilfield brine processing system 46 of FIG.', '4.', 'As illustrated in FIG.', '5, in certain embodiments, the process control system 54 of the oilfield brine processing system 46 described herein may include one or more process control modules 68 (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, a process control module 68 executes on one or more processors 70 of the process control system 54, which may be connected to one or more storage media 72 of the process control system 54.', 'Indeed, in certain embodiments, the one or more process control modules 68 may be stored in the one or more storage media 72 of the process control system 54.; FIG.', '6 is a schematic diagram of a treatment selection/design system 65 of the oilfield brine processing system 46 of FIG.', '4.', 'As illustrated in FIG.', '6, in certain embodiments, the treatment selection/design system 65 of the oilfield brine processing system 46 described herein may include one or more treatment selection/design modules 75 (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, a treatment selection/design module 75 executes on one or more processors 70 of the treatment selection/design system 65, which may be connected to one or more storage media 72 of the treatment selection/design system 65.', 'Indeed, in certain embodiments, the one or more treatment selection/design modules 75 may be stored in the one or more storage media 72.; FIG.', '7 is a block diagram of a method 78 of processing oilfield brine 48, as described in greater detail herein.', 'As illustrated in FIG. 7, in certain embodiments, the method 78 may include selection and blending of one or more oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E received from one or more corresponding hydrocarbon-producing wells 22A, 22B, 22C, 22D, 22E of a well site 10 (block 80).', 'As used herein, the term “salt” is used in its generic sense and refers to all of the total dissolved solid (TDS) inorganic species that are typically found in produced water brines.', 'Sodium chloride is usually the predominant constituent, but many other cations (e.g., calcium, magnesium, potassium, barium, and so forth) and anions (e.g., sulfate, bicarbonate, fluoride, and so forth) may be found dissolved in oilfield brines 48 as well, and may precipitate out as many different solid-state species.; FIG.', '10 illustrates a WHD system 32 configured to receive oilfield brine 48 from a plurality of hydrocarbon-producing wells 22 and to process and dispose of portions of the oilfield brine 48 using the operations 90, 92, 94 illustrated in FIG.', '9.', 'The oilfield brine 48 produced by the hydrocarbon-producing wells 22 may be conveyed (e.g., via pipelines 34, in certain embodiments) to the WHD system 32 for processing and disposal (e.g., injection into one or more SWD wells 44 of the WHD system 32), as described in greater detail herein.', 'In addition, as also described in greater detail herein, in certain embodiments, the oilfield brine 48 may be processed by the WHD system 32 to produce desalinated water 96, which may be beneficially reused.; FIG.', '11 is a schematic diagram of the WHD system 32 of FIG.', '10.', 'As illustrated, in certain embodiments, the WHD system 32 may receive a plurality of oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E (e.g., from a plurality of respective hydrocarbon-producing wells 22 via pipelines 34, as illustrated in FIG. 10) and may select one or more of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E produced in the field for processing.', 'For example, in certain embodiments, a process control system 98 may use corresponding sensors 100A, 100B, 100C, 100D, 100E to detect certain properties (e.g., composition, concentration, viscosity, salinity, and/or density of dissolved salts) of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E and, based at least in part on the detected properties, may actuate (e.g., send control signals to open/close) corresponding valves 102A, 102B, 102C, 102D, 102E to control blending of the oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E for delivery to a desalination system 104, which may be used to transform the blended oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E into desalinated water 96 and saltwater 106 for injection into one or more SWD wells 44, as described in greater detail herein.', 'As used herein, the term “saltwater” is intended to mean any of the water sources described herein, such as the oilfield brines and other brines, which have an elevated salinity as compared to the desalinated water 96.; FIG.', '13 is a schematic diagram of the WHD system 32 of FIG.', '11 with the addition of the second operation 92 of the three operations described with respect to FIG.', '9, which includes active management of the SWD water composition at the rock face through dual stream (e.g., split-stream) injection into one or more SWD wells 44.', 'In particular, as illustrated in FIG.', '13, in certain embodiments, two streams of water 112, 114 may be injected into the wellbore(s) of one or more SWD wells 44.', 'The first stream 112 (e.g., the saltwater 106 from the desalination system 104), the bulk of the water, has a relatively high concentration of TDSs, which is operated at a concentration close to or, in some instances, in excess of, the precipitation concentration of the dissolved species.', 'The second stream 114 (e.g., the control stream) may be a small flow rate of desalinated water 96 (e.g., skimmed from the first stream by the desalination system 104) to precisely control the compositions of the water 112, 114 entering the rock face of the one or more SWD wells 44.; FIG.', '14 is a schematic diagram of the WHD system 32 of FIG.', '13 with the addition of the third operation 94 of the three operations described with respect to FIG.', '9, which includes coupled SWD injection, flow assurance, and stimulation to minimize formation damage and injection pressures.', 'This operation is similar to the second operation 92 described herein, but adds in chemical stimulation and scale prevention processes 122 with respect to the SWD well(s) 44, which may be controlled by the process control system 98, to: (1) improve control on the wellhead pressure of the SWD well(s) 44, and (2) minimize the impact of near-wellbore damage to the SWD formation immediately surrounding the SWD wellbore, so that any damage occurs further out in the SWD formation.', 'In certain embodiments, the chemical stimulation and scale prevention processes 122 may be performed either continuously or intermittently, for example, relative to the injection of saltwater 106 into the SWD well(s) 44.', 'As described herein, although illustrated in FIG.', '14 as combining the first, second, and third operations 90, 92, 94 of the three operations described with respect to FIG.', '9, in other embodiments, the chemical stimulation and scale prevention processes 122 illustrated in FIG.', '14 may be performed independently of the embodiments in FIGS.', '11 and 13.', 'For example, in such an embodiment, the chemical stimulation and scale prevention processes 122 may be performed with respect to conventional saltwater injection into one or more SWD wells 44.; FIG.', '15 is a schematic diagram of a process control system 98 of the WHD system 32 of FIGS.', '11-14.', 'As illustrated in FIG.', '15, in certain embodiments, the process control system 98 of the WHD system 32 described herein may include one or more process control modules 124 (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, a process control module 124 executes on one or more processors 126 of the process control system 98, which may be connected to one or more storage media 128 of the process control system 98.', 'Indeed, in certain embodiments, the one or more process control modules 124 may be stored in the one or more storage media 128 of the process control system 98.; FIG.', '16 is a block diagram of a method 132 of processing oilfield brine 48 using the WHD system 32, as described in greater detail herein.', 'As illustrated in FIG.', '16, in certain embodiments, the method 132 includes receiving (and, in certain embodiments, pre-treating) one or more oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E from one or more hydrocarbon-producing wells 22 (block 134).', 'In addition, in certain embodiments, the method 132 includes pumping the one or more oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E through a desalination system 104 using pressure generated by the pumping system 108 (block 136).', 'In addition, in certain embodiments, the method 132 includes desalinating the one or more oilfield brine feedstocks 48A, 48B, 48C, 48D, 48E using the desalination system 104 to produce desalinated water 96 and saltwater 106 (block 138).', 'In addition, in certain embodiments, the method 132 includes injecting the saltwater 106 into one or more SWD wells 44 using the pressure generated by the pumping system 108 (block 140).', 'In addition, in certain embodiments, the method 132 optionally includes controlling dual stream injection of the saltwater 106 and previously-produced desalinated water 96 (e.g., via alternating injection and/or simultaneous metered injection) into the one or more SWD wells 44 using pressure generated by one or more desalinated water pumps 120 (block 142).', 'In addition, in certain embodiments, the method 132 optionally includes injecting chemicals and/or scale prevention additives into the one or more SWD wells 44 (block 144).']

US11898088

Cement compositions and methods

Jun 26, 2020

Yan Gao, Dominic Vincent Perroni, Anatoly Vladimirovich Medvedev, Andrey Vladimirovich Yakovlev

SCHLUMBERGER TECHNOLOGY CORPORATION

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['Cement slurries are prepared that comprise water, a hydraulic cement, particles of an oil-absorbent particles and non-swellable hydrophobic particles.', 'The particles are present in an amount sufficient to alter a property of a non-aqueous drilling fluid.', 'The cement slurry is placed in a subterranean well, whereupon the slurry contacts residual drilling fluid on casing and formation surfaces.', 'The oil-absorbent particles and hydrophobic particles in the cement slurry may reduce the mobility of the drilling fluid, thereby improving zonal isolation.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority to and the benefit of U.S. Provisional Patent Application Ser.', 'No. 62/868,024, entitled “Cement Compositions and Methods,” filed Jun. 28, 2019, which is hereby incorporated by reference in its entirety for all purposes.', 'BACKGROUND\n \nThe present disclosure relates generally to cement systems.', 'In particular, the disclosure relates to cement systems that contact drilling fluids within a subterranean well.', 'During the construction of a subterranean well it is common, during and after drilling, to place a tubular body (e.g., liner or casing) in the well, secured by cement pumped into the annulus around the outside of the liner.', 'The cement supports the tubular body and provides hydraulic isolation of the various fluid-producing zones through which the well passes.', 'This latter function is important because it prevents fluids from different layers contaminating each other.', 'For example, the cement prevents formation fluids from entering the water table and polluting drinking water, or prevents water production instead of oil or gas.', 'A complete discussion of cementing techniques may be found in the following publication.', 'Nelson E B and Guillot D (eds.):', 'Well Cementing—\n2\nnd Edition\n, Houston, Schlumberger (2006).', 'Drilling fluid removal has been a subject of interest in the well-cementing community for many years because of its effect on cement quality and zonal isolation.', 'The principal objective of a primary cement job is to provide complete and permanent isolation of the formations behind the casing.', 'To meet this objective, the drilling mud and the preflushes (if any) should be fully removed from the annulus, and the annular space must be completely filled with cement slurry.', 'Once in place, the cement must harden and develop the necessary mechanical properties to maintain a hydraulic seal throughout the life of the well.', 'Therefore, efficient mud removal and proper slurry placement promote well isolation.', 'Incomplete removal of drilling fluids within a wellbore may affect the quality of hydraulic cement placement in the wellbore annulus resulting in incomplete zonal isolation.', 'This may occur particularly in horizontal wellbores where poorly centralized casing may increase the likelihood that gelled mud channels may form.', 'Compromised zonal isolation may increase the potential for fluid flow along the casing at applied pressure gradient.', 'Later in the life of the well, such mud channels that have formed may serve as non-productive communication pathways between stages during a stimulation treatment.', 'The present disclosure provides well cementing systems that may provide additional zonal isolation by facilitating the removal or dispersion or residual non-aqueous drilling fluids within the wellbore.', 'Such residual non-aqueous drilling fluids may result from drilling the wellbore with non-aqueous drilling fluid prior to cementing.', 'Further, the cement compositions disclosed herein may interact with residual drilling fluids and alter the properties of such drilling fluids.', 'The present disclosure is particularly directed to drilling fluids, such as non-aqueous drilling fluids which range from diesel- or mineral oil-based fluids to synthetic-based systems.', 'Synthetic-based systems may contain synthetic hydrocarbons, ethers, esters or acetals.', 'The synthetic hydrocarbons may include linear paraffins, linear-α-olefins, poly-α-olefins and internal olefins.', 'The synthetic-based systems may be emulsions in which the hydrocarbon is the external phase.', 'SUMMARY', 'In an aspect, embodiments relate to methods for cementing a subterranean well.', 'A cement slurry is prepared comprising water, a hydraulic cement, particles of an oil-absorbing material, and non-swellable hydrophobic fibers, wherein the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.', 'The cement slurry is placed in the subterranean well, causing the oil-absorbent particles and hydrophobic fibers to contact the non-aqueous drilling fluid component, thereby altering the property of the non-aqueous component.', 'In a further aspect, embodiments relate to methods for establishing zonal isolation in a subterranean well.', 'A cement slurry is prepared that comprises water, a hydraulic cement, particles of an oil-absorbent particles and non-swellable hydrophobic fibers, wherein the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.', 'The cement slurry is placed in the subterranean', 'well wherein residual drilling fluid is present along casing and formation surfaces, causing the oil-absorbent particles and non-swellable hydrophobic fibers to contact the residual drilling fluid, thereby altering the property of the non-aqueous component and creating a hydraulic seal in the subterranean well.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\na \nis a cross-sectional diagram showing 100% casing centralization in a wellbore.', 'FIG.', '1\nb \nis a cross-sectional diagram showing eccentric casing centralization, which may occur in deviated or horizontal well sections.\n \nFIG.', '2\n is a cross-sectional diagram showing a drilling fluid channel arising from poor casing centralization in a wellbore.\n \nFIG.', '3\n is a diagram showing a drilling fluid channel that has been deposited in the narrow region of an eccentric annulus and affected by the cement slurry according to the present disclosure.\n \nFIG.', '4\n compares the rheological properties of diesel-based emulsion drilling fluids after exposure to cement slurries.', 'The yield point of a drilling fluid exposed to a cement slurry containing oil-absorbent particles was higher than that of a drilling fluid exposed to a comparative slurry that did not contain absorbent particles.', "The crossover points (stress) where the loss modulus was equal to the storage modulus were the fluids' yield points.", 'FIG.', '5\n shows pressure test results for a conventional cement slurry and a cement slurry containing oil-absorbing particles.\n \nFIG.', '6\n shows the viscosities of oils containing various oil-absorbent polymers.\n \nFIG.', '7\n shows the permeability effects of adding swellable particles and non-swellable hydrophobic fibers to a cement slurry.', "DETAILED DESCRIPTION\n \nAt the outset, it should be noted that in the development of any such actual embodiment, numerous implementations—specific decisions must be made to achieve the developer's specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort might be complex and time consuming but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'In addition, the composition used/disclosed herein can also comprise some components other than those cited.', 'In the summary of the disclosure and this detailed description, each numerical value should be read once as modified by the term “about” (unless already expressly so modified), and then read again as not so modified unless otherwise indicated in context.', 'Also, in the summary of the disclosure and this detailed description, it should be understood that a concentration range listed or described as being useful, suitable, or the like, is intended that any and every concentration within the range, including the end points, is to be considered as having been stated.', 'For example, “a range of from 1 to 10” is to be read as indicating each and every possible number along the continuum between about 1 and about 10.', 'Thus, even if specific data points within the range, or even no data points within the range, are explicitly identified or refer to only a few specific points, it is to be understood that inventors appreciate and understand that any and all data points within the range are to be considered to have been specified, and that inventors possessed knowledge of the entire range and all points within the range.', 'As discussed earlier, one indication of successful cement placement is complete drilling fluid removal.', 'Complete removal of non-aqueous drilling fluids may be challenging because they may leave casing and formation surfaces oil wet, which may negatively affect cement sheath bond quality.', 'It is known in the art that such drilling fluids may further contain clays, weighting agents or both.', 'During most cementing operations, casing \n1\n is present inside a wellbore having a wall \n2\n.', 'An annulus \n3\n is therefore present between the casing and the wellbore wall.', 'Optimal drilling-fluid removal may occur when the casing is fully centralized in the wellbore (\nFIG.', '1\na\n).', '100% casing centralization maximizes circulation efficiency because there are no narrow regions that may be resistant to fluid flow.', 'However, achieving 100% casing centralization may not be achievable in deviated or horizontal well sections (\nFIG.', '1\nb\n).', 'Due to gravity, the casing has a tendency to migrate toward a borehole wall.', 'As a result, during the cement placement process, when cement slurry \n4\n is pumped to fill the annulus, the eccentric casing position may lead to poor drilling-fluid displacement in the narrow portion of the casing/wellbore annulus, leaving a drilling-fluid channel \n5\n (\nFIG.', '2\n).', 'The present disclosure presents methods for altering drilling-fluid properties as well as achieving zonal isolation.', 'Embodiments may combat drilling fluid channels by interacting with the drilling fluid channels and altering properties of the drilling fluid channels.', 'In an embodiment, an oil-absorbing material and hydrophobic particles may be added to the cement slurry.', 'The cement slurry may have a density between about 10 lbm/gal and 24 lbm/gal.', 'The oil-absorbing material may begin interacting with drilling fluid first at the interface between the drilling fluid and cement.', 'Not being bound to any theory, the oil absorbing material may promote oil diffusion into the set cement material.', 'Once oil from oil-based drilling fluid is absorbed or diffused into the cement, the rheological properties of the drilling fluid may change.', 'Consequently, the drilling fluid may be converted from a fluid-like material to a paste-like structure.', 'Such conversion inside the drilling-fluid channel may prevent fluid flow inside the channel and serve to provide zonal isolation.', 'In addition, oil-absorbing particles in the cement sheath may increase in size, physically blocking small channels or compressing a paste-like mud structure.', 'The non-swellable hydrophobic fibers may further strengthen the paste-like structure.', 'The oil-absorbent particles may comprise rubber, ground rubber, polypropylene, polyethylene, acrylonitrile butadiene, styrene butadiene, styrene isoprene, 2,1 bicycloheptene, alkylstyrene, or crosslinked substituted vinyl acetate copolymer, or combinations thereof.', 'The oil-absorbent particles may be present in the cement slurry at a concentration between 1% and 40% by weight of cement.', 'In an embodiment, a process contributing to achieving zonal isolation may include dynamic removal of the mud channel during cement slurry displacement.', 'The oil-absorbing particles \n6\n and fibers \n7\n flowing near the drilling fluid channel may physically remove a portion of the drilling fluid \n5\n and transport the portion away from the drilling fluid channel.', 'Thus, the particles may significantly reduce the size of the drilling fluid channel or even remove it (\nFIG. \n3\n).', 'In an embodiment, a material that viscosifies oil may be added to the cement slurry.', 'Oil-viscosifying particles may interact and diffuse into oil-based drilling fluid during placement or after the cement setting process, and viscosify the residual oil-based mud to an extent that zonal isolation is achieved.', 'Such cement compositions may contain a sufficient concentration of oil-viscosifying particles to increase the yield point (Ty) to a level higher than that of cement compositions that do not contain the oil-viscosifying particles.', 'The yield point increase may take place within three days of exposure, and the ultimate yield point measured by oscillatory rheometry may be at least 100 Pa.', 'In some cases, the yield point may rise to 4600 Pa (see Example 3).', 'Or the yield point may be between 500 Pa and 3000 Pa.', 'Or the yield point may be between 1000 Pa and 2000 Pa.', 'The higher the yield point, the better the zonal isolation may be.', 'For all embodiments, the cement slurry may comprise portland cement, high alumina cement, fly ash, blast furnace slag, microcement, geopolymers, chemically bonded phosphate ceramics, plaster or resins or combinations thereof.', 'The cement slurry further comprises polymers, random copolymers and block polymers comprising alternating sections of one chemical compound separated by sections of a different chemical compound, or a coupling group of low molecular weight.', 'For example, block polymers may have the structure (A-b-B-b-A), wherein A represents a block that is glassy or semi-crystalline and B is a block that is elastomeric.', 'In principle, A can be any polymer that is normally regarded as thermoplastic (e.g., polystyrene, polymethylmethacrylate, isotactic polypropylene, polyurethane, etc.), and B can be any polymer that is normally regarded as elastomeric (e.g., polyisoprene, polybutadiene, polyethers, polyesters, etc.).', 'Example thermoplastic block polymers include styrene-isoprene-styrene (SIS), styrene-butadiene-styrene (SBS) and mixtures thereof.', 'The block-polymer-additive may be in one or more shapes, including (but not limited to) spherical, ovoid, fibrous, ribbon-like and in the form of a mesh.', 'The tensile strength of the block polymer may vary between, but not be limited to, about 1.5 MPa and 40 MPa, or between 3.4 to 34 MPa, or between 2 MPa and 3.45 MPa or between 28 MPa and 34 MPa.', 'The thermoplastic block polymers may be present in the cement slurry at a concentration between about 1 lbm/bbl and 50 lbm/bbl.', 'Or the block polymer may be present in the cement slurry at a concentration 5 lbm/bbl and 15 lbm/bbl.', 'The particle size of the block polymer particles may be between about 1 μm and 1000 μm, or between 300 μm and 800 μm.', 'The thermoplastic block-particles may be further associated with one or more compounds from the list comprising an emulsion of polymer comprising a betaine group, poly-2,2,1-bicyclo heptene (polynorbornene), alkylstyrene, crosslinked substituted vinyl acrylate copolymers, diatomaceous earth, natural rubber, vulcanized rubber, polyisoprene rubber, vinyl acetate rubber, polychloroprene rubber, acrylonitrile butadiene rubber, hydrogenated acrylonitrile butadiene rubber, ethylene propylene diene monomer, ethylene propylene monomer rubber, styrene-butadiene rubber, styrene isoprene, styrene/propylene/diene monomer, brominated poly(isobutylene-co-4-methylstyrene), butyl rubber, chlorosulfonated polyethylenes, polyacrylate rubber, polyurethane, silicone rubber, brominated butyl rubber, chlorinated butyl rubber, chlorinated polyethylene, epichlorohydrin ethylene oxide copolymer, ethylene acrylate rubber, ethylene propylene diene terpolymer rubber, sulfonated polyethylene, fluoro silicone rubbers, fluoroelastomers, substituted styrene acrylate copolymers and bivalent cationic compounds.', 'The hydrophobic non-swellable fibers may comprise polyethylene, polyolefins, polystyrene, polyvinylchloride, polytetrafluoroethylene, polydimethylsiloxane, epoxies, polyacrylics or polyurethanes or combinations thereof.', 'The fibers may interact and form a interconnected network in the subterranean well, further strengthening the drilling fluid channel.', 'The hydrophobic non-swellable fibers may be present at a concentration between 0.1 wt % and 30 wt %, or between 5.0% and 10 wt %.', 'The hydrophobic non-swellable fibers may have a length between 500 μm and 20 mm, or between 1 μm and 6 mm, and a diameter between 100 nm and 1 mm, or 500 nm and 0.5 mm.', 'In addition to the aforementioned particles and fibers, the cement slurries may also comprise customary additives such as retarders, accelerators, extenders, fluid-loss-control additives, lost-circulation additives, gas-migration additives, gas-generating additives, expansion additives and antifoam agents.', 'Furthermore, the cement slurries may contain additives that enhance the flexibility and/or toughness of the set cement.', "Such additives include, but are not limited to, flexible particles having a Young's modulus below about 5000 MPa and a Poisson's ratio above about 0.3.", "Such particles may have a Young's modulus below about 2000 MPa.", 'Examples include, but are not limited to, polypropylene, polyethylene, acrylonitrile butadiene, styrene butadiene and polyamide.', 'Such additives may also include fibers selected from the list comprising polyamide, polyethylene and polyvinyl alcohol.', 'Metallic microribbons may also be included.', 'In an embodiment, the oil-absorbent particles may be elongated, fibrous, cylindrical or asymmetrical.', 'Such particles with an aspect ratio higher than about 1 may interact and form a network inside the cement slurry.', 'The elongated shape may also improve the absorbing ability of the particles.', 'The higher aspect ratio increases the probability that the particles will contact each other throughout the cement slurry, allowing more efficient oil absorption and lower absorbent-particle concentrations to achieve a given result.', 'The particle aspect ratio may be between 1.1 and 2000, or between 10 and 1500, of 15 and 1000 before swelling, or between 2.2 and 3500, or 4 and 1000, or 6 and 350 after swelling.', 'Furthermore, the temperature at which the disclosed fluids operate may be between 80° F. and 400° F., or between 100° F. and 375° F.', 'For all embodiments, the concentration of oil-absorbent particles may vary in the cement sheath.', 'This may be accomplished by varying the rate at which the oil-absorbent particles are added to the cement slurry during mixing and pumping.', 'Certain portions of the cement sheath may not contain oil-absorbent particles.', 'As long as there are regions along the cement sheath providing zonal isolation, the well as a whole may have a hydraulic seal.', 'For example, sections containing the oil-absorbent particles may be located above and below producing zones.', 'Under these circumstances, the concentration of the oil-absorbent particles may vary between 0% and 40% by weight of cement.', 'This approach may be more economical than scenarios where the oil-absorbent particles are present throughout the cement sheath.', 'EXAMPLES\n \nExample 1—Drilling Fluid Rheological Properties\n \nTwo 600-mL cement slurries were prepared in a Waring blender according to a mixing procedure published by the American Petroleum Institute (RP-10B).', 'The density of both slurries was 15 lbm/gal (1800 kg/m\n3\n).', 'Both slurries were prepared with Texas Lehigh Class H cement.', 'A comparative slurry composition is given in Table 1.\n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \n \n \nComparative cement slurry composition.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.3%', 'BWOC\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.1% \n \nBWOC\n \n \n \n \nPolysaccharide Biopolymer\n \n0.3% \n \nBWOC\n \n \n \n \nPolypropylene Glycol\n \n0.050 \n \ngal/sk\n \n \n \n \nWater\n \n6.02 \n \ngal/sk\n \n \n \n \n \n \n \n \nBWOC = by weight of cement;', 'sk = 94-lb sack of portland cement.', 'AMPS = 2-acrylamido-2-methylpropane sulfonic acid.', 'A cement composition according to the disclosure is given in Table 2.', 'The cement slurry contained absorbing particles composed of ground rubber particles.', 'The particle size of the rubber varied between 100 μm and 800 μm.\n \n \n \n \n \n \n \n \nTABLE 2', 'Cement slurry composition according to the disclosure.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \nGround Rubber\n \n31.0% \n \nBVOB\n \n \n \nBarium Sulfate\n \n8.4% \n \nBVOB\n \n \n \nCrystalline Silica\n \n15% \n \nBVOB\n \n \n \nAMPS/Acrylamide copolymer\n \n0.3% \n \nBWOC\n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.4% \n \nBWOC\n \n \n \nPolysaccharide Biopolymer\n \n0.8% \n \nBWOC\n \n \n \nsodium glucoheptonate/crystalline silica/hematite\n \n0.5% \n \nBWOC\n \n \n \nPolypropylene Glycol\n \n0.1 \n \ngal/sk\n \n \n \nSIS Copolymer\n \n1% \n \nBWOB\n \n \n \nWater\n \n4.27 \n \ngal/sk\n \n \n \n \n \n \nBWOB = by weight of blend;\n \n \n \nBVOB = by volume of blend;\n \n \n \nSIS = styrene-isoprene-styrene\n \n \n \n \n \n \n \nBoth slurries were conditioned for 35 min at 168° F. in an atmospheric consistometer.', 'A representative 13 lbm/gal (1620 kg/m\n3\n) inverse emulsion drilling fluid was chosen that contained diesel as the continuous phase (MegaDril™, available from Schlumberger).', '15 mL of the conditioned slurry were placed at the bottom of a glass vial.', '5 mL of the drilling fluid was carefully added to the top of the conditioned slurry.', 'The glass vials were placed in a Turbiscan AGS instrument (available from Formulaction Inc., Worthington, OH) that was preheated to 140° F. (60° C.) and allowed to cure for 8 days.', 'During this time the slurry developed compressive strength, and the drilling fluid in contact with the slurry containing the absorbent particles increased its yield strength compared to that in contact with the comparative cement system.', 'To quantify this rheological change, the drilling fluids were extracted from the vials.', 'The yield strength was analyzed on a TA-DHR3 rheometer (available from TA Instruments, New Castle, DE) in a parallel plate configuration.', 'An oscillatory amplitude sweep was conducted at 68° F. (20° C.) with an angular frequency of 10 rad/s and a logarithmic strain percent sweep from 0.01% to 100%.', 'The drilling fluid that was exposed to the absorbent slurry exhibited a yield strength in some cases approximately 65 times higher than that of the drilling fluid exposed to the comparative slurry under the same conditions (\nFIG.', '4\n)\n \nExample 2—Channel Flow Reduction\n \nApplicant developed a laboratory method to investigate the ability of absorbent containing cement slurry to reduce fluid flow in a drilling-fluid filled channel.', 'Two 600-mL cement slurries were prepared in a Waring blender.', 'The cement was Class H portland cement.', 'The density of both slurries was 14.5 lbm/gal (1740 kg/m\n3\n).', 'Both slurries were extended with fly ash.', 'A comparative slurry composition is given in Table 3.\n \n \n \n \n \n \n \n \nTABLE 3\n \n \n \n \n \n \n \n \nComparative Cement Slurry Composition.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nFly ash\n \n40 \n \nlb/sk\n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.3% \n \nBWOC\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.3% \n \nBWOC\n \n \n \n \nPolysaccharide Biopolymer\n \n0.3% \n \nBWOC\n \n \n \n \nSilica Fume\n \n8.0% \n \nBWOB\n \n \n \n \nSodium Lignosulfonate\n \n0.3% \n \nBWOB\n \n \n \n \nPolypropylene Glycol\n \n0.050 \n \ngal/sk\n \n \n \n \nWater\n \n5.91 \n \ngal/sk\n \n \n \n \n \n \n \n \n \n \n A slurry composition according to the disclosure is given in Table 4. \n \n \n \n \n \n \n \n \nTABLE 4\n \n \n \n \n \n \n \n \nCement slurry composition according to the disclosure.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nFly ash\n \n40 \n \nlb/sk\n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.3%', 'BWOC\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.1% \n \nBWOC\n \n \n \n \nPolysaccharide Biopolymer\n \n0.3% \n \nBWOC\n \n \n \n \nPolypropylene Glycol\n \n0.050 \n \ngal/sk\n \n \n \n \nSodium Lignosulfonate\n \n0.3% \n \nBWOB\n \n \n \n \nSilica Fume\n \n8.0% \n \nBWOB\n \n \n \n \nGround Rubber\n \n5.0% \n \nBWOC\n \n \n \n \nSIS Copolymer\n \n1% \n \nBWOB\n \n \n \n \nWater\n \n5.87 \n \ngal/sk\n \n \n \n \n \n \n \n \n \n \n \nA 3-in.', 'long by 1-in.', 'wide steel pipe was capped on one end and filled with slurry and then capped on the other end.', 'Small vent holes were added to the caps to equalize the pressure during high pressure curing.', 'The pipes containing slurry were loaded into a curing chamber and were exposed to 170° F. (77° F.) and 3000 psi (21 MPa).', 'After the slurry had set, a hole was drilled in the cement leaving a channel of about ⅛-in.', '(0.3-cm) diameter.', 'The bottom of the hole was plugged, the channel was filled with 13-lbm/gal (1620-kg/m\n3\n)', 'MegaDril drilling fluid, and was allowed to set for 6 days at atmospheric conditions.', 'The permeability of the resulting mud channel was probed by the flow of water through the channel.', 'The flow rate was set at 1 mL/min and resulting pressure were measured using a Teledyne ISCO D-series syringe pump.', 'The results, presented in \nFIG.', '5\n, show that the cement prepared according to the present disclosure was 5 times more pressure resistant compared to the comparative cement.', 'The absorbent additive concentration could be adjusted to increase pressure even higher, up 14 psi, if needed.', 'In order to scale the laboratory results to a real application, it could be calculated that 5 psi in a 3-in.', 'tube corresponds to 3000 psi at a 50-ft distance.', 'Example 3—Oil Viscosification\n \nThe ability of an absorbent particle to viscosify oil was investigated.', 'The absorbent particles were made of polystyrene-block-poly(ethylene-ran-butylene)-block-polystyrene and polystyrene-block-polybutadiene-block-polystyrene polymers (manufactured by Sigma-Aldrich Chemie GmbH, Steinheim, Germany).', 'The oil was LVT200 oil, a hydrotreated light distillate manufactured by Deep South Chemical, Inc., Broussard, LA.', 'The following samples were investigated: 0.8 wt % and 5.8 wt % solutions of polystyrene-block-polybutadiene-block-polystyrene polymer (PS-PB) in LVT200 oil and 1 wt %, 2.8 wt %, 5.9 wt % solutions of polystyrene-block-poly(ethylene-ran-butylene)-block-polystyrene polymer (PS-PEPB-PS) in LVT200.', 'The viscosities of samples were measured by MCR300 rheometer from Anton Paar in parallel plate CC17 geometry (\nFIG.', '6\n).', 'The results show that the oil viscosities increase with polymer concentration.', 'Example 4—Elongated Oil-Absorbent Particles with Hydrophobic Fibers\n \n5-in steel pipes with 1-in diameter were capped on one end.', 'Two pipes were filled with the base slurry of Table 5 plus 5.0% ground rubber.', 'Two other pipes contained the base slurry plus 4.0% BWOC ground rubber and 1.0% BWOC non-swellable polyethylene fiber (available from MI Swaco, Houston, TX) (Table 5).', 'The fiber diameter was 30-50 μm.', 'TABLE 5\n \n \n \n \n \n \n \n \nBase-slurry composition.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nFly ash\n \n40 \n \nlb/sk\n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.3%', 'BWOC\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.1% \n \nBWOC\n \n \n \n \nPolysaccharide Biopolymer\n \n0.3% \n \nBWOC\n \n \n \n \nPolypropylene Glycol\n \n0.050 \n \ngal/sk\n \n \n \n \nSodium Lignosulfonate\n \n0.3% \n \nBWOB\n \n \n \n \nSilica Fume\n \n8.0% \n \nBWOB\n \n \n \n \nWater\n \n5.87 \n \ngal/sk\n \n \n \n \n \n \n \n \n \n \n \n3-mm diameter, 7.5-in.', 'length channels were created by inserting wooden dowels into the cement slurries and removing the dowels after 24 hours when the cement slurries had developed sufficient gel strength to maintain the channel structure.', 'Then the channels were filled with 13.0 lbm/gal (1560 kg/m\n3\n) MegaDril mud (available from MI-Swaco).', 'After 72 hours of interaction time between the set cement and the mud channel, permeabilities of the channels were measured using the same apparatus described in Example 2.', 'The pressure necessary to initiate flow through the test channel was approximately 32 psi, which is about 50% higher than the average value observed with the comparative slurries without fibers (\nFIG.', '7\n).', 'The preceding description has been presented with reference to present embodiments.', 'Persons skilled in the art and technology to which this disclosure pertains will appreciate that alterations and changes in the described structures and methods of operation can be practiced without meaningfully departing from the principle, and scope of this present disclosure.', 'Accordingly, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.']

['1.', 'A method for cementing a subterranean well, comprising:\nplacing a cement slurry comprising water, a hydraulic cement, oil-absorbent particles, and non-swellable hydrophobic fibers having a length between 500 μm and 20 mm, and a diameter between 100 nm and 1 mm within the subterranean well, wherein the oil-absorbent particles are elongated, having an aspect ratio between 15 and 1000 before swelling, and between 5 and 350 after swelling, and wherein the oil-absorbent particles contact a non-aqueous component of a drilling fluid within the subterranean well and decrease a property of flowability of the non-aqueous component of the drilling fluid.', '2.', 'The method of claim 1, wherein the oil-absorbent particles comprise rubber, ground rubber, acrylonitrile butadiene, styrene butadiene, styrene isoprene, 2,1 bicycloheptene, alkylstyrene, or crosslinked substituted vinyl acetate copolymer, or combinations thereof.', '3.', 'The method of claim 1, wherein the oil-absorbent particles have a particle size between about 1 μm and about 1000 μm.\n\n\n\n\n\n\n4.', 'The method of claim 1, wherein the elongated particles interact in the subterranean well to form an interconnected network.', '5.', 'The method of claim 1, wherein the oil-absorbent particles are present at a concentration between about 1% by weight of cement (BWOC) and about 40% BWOC.', '6.', 'The method of claim 1, wherein the cement slurry has a density between about 10 lbm/gal and about 24 lbm/gal.\n\n\n\n\n\n\n7.', 'The method of claim 1, wherein the non-aqueous component comprises diesel, mineral oil, olefins, esters, synthetic paraffins, or refined paraffins, or combinations thereof.', '8.', 'The method of claim 1, wherein a concentration of the oil-absorbent particles varies in the cement slurry, between about 1% BWOC and 40% BWOC, thereby creating a cement sheath in the subterranean well with a variable oil-absorbent particles concentration.', '9.', 'The method of claim 1, wherein the non-swellable hydrophobic fibers comprise polyethylene, polyolefins, polystyrene, polyvinylchloride, polytetrafluorethylene, polydimethylsiloxane, epoxies, polyacrylics or polyurethanes or combinations thereof.', '10.', 'The method of claim 9, wherein the non-swellable hydrophobic fibers interact in the subterranean well to form an interconnected network.', '11.', 'The method of claim 1, wherein the non-swellable hydrophobic fibers are present at a concentration between 0.1 wt % and 30 wt %.\n\n\n\n\n\n\n12.', 'A method comprising:\nplacing casing within a subterranean well;\nproviding a cement slurry comprising water, a hydraulic cement, oil-absorbent particles, and non-swellable hydrophobic fibers having a length between 500 μm and 20 mm, and a diameter between 100 nm and 1 mm within the subterranean well,\nwherein the oil-absorbent particles are elongated, having an aspect ratio between 15 and 1000 before swelling, and between 5 and 350 after swelling, and\nwherein the oil-absorbent particles contact a non-aqueous component of residual drilling fluid on the casing and formation surfaces of the subterranean well to decrease a property of flowability of the non-aqueous component of the residual drilling fluid.', '13.', 'The method of claim 12, wherein the oil-absorbent particles comprise rubber, ground rubber, acrylonitrile butadiene, styrene butadiene, styrene isoprene, 2,1 bicycloheptene, alkylstyrene, or crosslinked substituted vinyl acetate copolymer, or combinations thereof.', '14.', 'The method of claim 12, wherein the non-swellable hydrophobic fibers comprise polyethylene, polyolefins, polystyrene, polyvinylchloride, polytetrafluorethylene, polydimethylsiloxane, epoxies, polyacrylics or polyurethanes or combinations thereof.', '15.', 'The method of claim 12, wherein the non-swellable hydrophobic fibers are present at a concentration between 0.1 wt % and 30 wt %.']

['FIG.', '1a is a cross-sectional diagram showing 100% casing centralization in a wellbore.', 'FIG.', '1b is a cross-sectional diagram showing eccentric casing centralization, which may occur in deviated or horizontal well sections.; FIG.', '2 is a cross-sectional diagram showing a drilling fluid channel arising from poor casing centralization in a wellbore.; FIG.', '3 is a diagram showing a drilling fluid channel that has been deposited in the narrow region of an eccentric annulus and affected by the cement slurry according to the present disclosure.', '; FIG.', '4 compares the rheological properties of diesel-based emulsion drilling fluids after exposure to cement slurries.', 'The yield point of a drilling fluid exposed to a cement slurry containing oil-absorbent particles was higher than that of a drilling fluid exposed to a comparative slurry that did not contain absorbent particles.', "The crossover points (stress) where the loss modulus was equal to the storage modulus were the fluids' yield points.", '; FIG.', '5 shows pressure test results for a conventional cement slurry and a cement slurry containing oil-absorbing particles.', '; FIG.', '6 shows the viscosities of oils containing various oil-absorbent polymers.; FIG.', '7 shows the permeability effects of adding swellable particles and non-swellable hydrophobic fibers to a cement slurry.']

US11899161

Optimization under uncertainty for integrated models

Oct 25, 2016

Vijaya Halabe, William J. Bailey, Michael David Prange, Trevor Graham Tonkin

Schlumberger Technology Corporation

Rahim, Shahed, and Zukui Li. “Reservoir geological uncertainty reduction: an optimization-based method using multiple static measures.” Mathematical Geosciences 47.4 (2015): 373-396. (Year: 2015).; Bertoncello, Antoine, and Jef Caers. “Global sensitivity analysis on a hybrid geostatistical model using a distance-based approach.” Published at least by Jun. 20, 2015. https://web.archive.org/web/20150620072811/https://pangea.stanford.edu/departments/ere/dropbox/scrf/documents/reports/23/ (Year: 2015).; [Item V continued] SCRF2010_Report23/SCRF2010_14.Antoine_sensitivity%20analysis_scrf21010.pdf (Year: 2015).; Scheidt, Celine, and Jef Caers. “Uncertainty quantification in reservoir performance using distances and kernel methods—application to a west africa deepwater turbidite reservoir.” SPE Journal 14.04 (2009): 680-692. (Year: 2009).; International Preliminary Report on Patentability for the equivalent International patent application PCT/US2016/058559 dated May 11, 2018.; International Search Report and Written Opinion for the equivalent International patent application PCT/US2016/05859 dated Jan. 31, 2017.; Decker S. et al., “A 256X256 Imaging Array with Wide Dynamic Range Pixels and Column-Parallel Digital Output”, Institute of electrical and electronics engineers University of Pennsylvania, IEEE, 1998, 10 pages.; Exam Report issued in Canada Patent Application 3,004,112 dated Dec. 7, 2022, 4 pages.; Office Action issued in Norway Patent Application No. P28581NO00 dated Feb. 8, 2023, 6 pages.

8793111; July 29, 2014; Tilke et al.; 9223042; December 29, 2015; Maucec et al.; 9523275; December 20, 2016; Ma; 20100332442; December 30, 2010; Goel et al.; 20110054869; March 3, 2011; Li et al.; 20110307230; December 15, 2011; Lee; 20120118637; May 17, 2012; Wang et al.; 20120323544; December 20, 2012; Zhao et al.; 20130238303; September 12, 2013; Round; 20150055436; February 26, 2015; Ma; 20150134304; May 14, 2015; Guiver; 20150285944; October 8, 2015; Herron; 20150355353; December 10, 2015; Whitaker; 20160356125; December 8, 2016; Bello; 20160357887; December 8, 2016; Ortiz; 20170083822; March 23, 2017; Adendorff

2013/106720; July 2013; WO

['A method can include receiving realizations of a model of a reservoir that includes at least one well where the realizations represent uncertainty in a multidimensional space; selecting a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimizing an objective function based at least in part on the selected portion of the realizations; outputting parameter values for the optimized objective function; and generating at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.']

['Description\n\n\n\n\n\n\nRELATED APPLICATIONS', 'This application is a National Stage Entry of International Application No. PCT/US2016/058559, filed 25 Oct. 2016, which claims priority to and the benefit of a U.S. Provisional Application having Ser.', 'No. 62/247,073, filed 27 Oct. 2015, each of which is incorporated by reference herein.', 'BACKGROUND', 'In oilfield operations, computer models of wells are employed to track and predict production.', 'These models may be employed, for example, to determine the economical value for different well production scenarios.', 'Furthermore, the parameters of several wells in a field may depend on one another, and thus computer models of the reservoir, including several wells, may be provided.', 'The reservoir models may be employed to simulate and predict the effects of different production and/or other equipment parameters on the reservoir, and thus, for example, may be used to maximize the economical value of the reservoir or field.', 'A model or models can include some amount of uncertainty, which may be classified as a level of uncertainty as depending on various factors.', 'Uncertainty can be a factor in decision making, development of a reservoir or reservoirs, operation of equipment, etc.', 'SUMMARY\n \nA method can include receiving realizations of a model of a reservoir that includes at least one well where the realizations represent uncertainty in a multidimensional space; selecting a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimizing an objective function based at least in part on the selected portion of the realizations; outputting parameter values for the optimized objective function; and generating at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.', 'A system can include a processor; memory accessible by the processor; processor-executable instructions stored in the memory and executable to instruct the system to: receive realizations of a model of a reservoir that includes at least one well where the realizations represent uncertainty in a multidimensional space; select a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimize an objective function based at least in part on the selected portion of the realizations; output parameter values for the optimized objective function; and generate at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.', 'One or more computer-readable storage media can include processor-executable instructions to instruct a computing system to: receive realizations of a model of a reservoir that includes at least one well wherein the realizations represent uncertainty in a multidimensional space; select a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimize an objective function based at least in part on the selected portion of the realizations; output parameter values for the optimized objective function; and generate at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.', 'Various other apparatuses, systems, methods, etc., are also disclosed.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFeatures and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.\n \nFIG.', '1\n illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.\n \nFIG.', '2\n illustrates a flowchart of a method, according to an embodiment.\n \nFIG.', '3\n illustrates an example of creating reservoir simulation scenarios, according to an embodiment.\n \nFIG.', '4\n illustrates each reservoir having a base case and multiple realizations, according to an embodiment.\n \nFIG.', '5\n illustrates a plot of sensitivity analysis carried out in the realizations, according to an embodiment.\n \nFIG.', '6\n illustrates a plot of survival curves that document the expected run-life failure for equipment after installation, according to an embodiment.\n \nFIG.', '7\n illustrates creating an integrated model in a software platform, according to an embodiment.\n \nFIG.', '8\n illustrates selecting the reduced number of realizations from smart sampling and assigning weights to them according to the desired distribution, according to an embodiment.\n \nFIG.', '9\n illustrates two reservoirs (m=2) and three smart realizations for each reservoir (N=3), according to an embodiment.\n \nFIG.', "10\n illustrates a table showing results of simulations per trial in optimization, with each simulation run's objective function accounted for, according to an embodiment.\n \nFIG.", '11\n illustrates a plot of an optimized objective function corresponding to a strategy, according to an embodiment.\n \nFIG.', '12\n illustrates a plot of several oil production cases, according to an embodiment.\n \nFIG.', '13\n illustrates plots of erosional velocity ratio for gas lift and boosting, according to an embodiment.\n \nFIG.', '14\n illustrates an example of a method.\n \nFIG.', '15\n illustrates examples of equipment in various geologic environments.\n \nFIG.', '16\n illustrates a schematic view of a computing system, according to an embodiment.', 'DETAILED DESCRIPTION', 'The following description includes the best mode presently contemplated for practicing the described implementations.', 'This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.\n \nFIG.', '1\n illustrates an example of a system \n100\n that includes various management components \n110\n to manage various aspects of a geologic environment \n150\n (e.g., an environment that includes a sedimentary basin, a reservoir \n151\n, one or more faults \n153\n-\n1\n, one or more geobodies \n153\n-\n2\n, etc.).', 'For example, the management components \n110\n may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment \n150\n.', 'In turn, further information about the geologic environment \n150\n may become available as feedback \n160\n (e.g., optionally as input to one or more of the management components \n110\n).', 'In the example of \nFIG.', '1\n, the management components \n110\n include a seismic data component \n112\n, an additional information component \n114\n (e.g., well/logging data), a processing component \n116\n, a simulation component \n120\n, an attribute component \n130\n, an analysis/visualization component \n142\n and a workflow component \n144\n.', 'In operation, seismic data and other information provided per the components \n112\n and \n114\n may be input to the simulation component \n120\n.', 'In an example embodiment, the simulation component \n120\n may rely on entities \n122\n.', 'Entities \n122\n may include earth entities or geological objects such as wells, surfaces, bodies, reservoirs, etc.', 'In the system \n100\n, the entities \n122\n can include virtual representations of actual physical entities that are reconstructed for purposes of simulation.', 'The entities \n122\n may include entities based on data acquired via sensing, observation, etc. (e.g., the seismic data \n112\n and other information \n114\n).', 'An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property).', 'Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.', 'In an example embodiment, the simulation component \n120\n may operate in conjunction with a software framework such as an object-based framework.', 'In such a framework, entities may include entities based on pre-defined classes to facilitate modeling and simulation.', 'A commercially available example of an object-based framework is the MICROSOFT® .NET® framework (Redmond, Washington), which provides a set of extensible object classes.', 'In the .NET® framework, an object class encapsulates a module of reusable code and associated data structures.', 'Object classes can be used to instantiate object instances for use in by a program, script, etc.', 'For example, borehole classes may define objects for representing boreholes based on well data.', 'In the example of \nFIG.', '1\n, the simulation component \n120\n may process information to conform to one or more attributes specified by the attribute component \n130\n, which may include a library of attributes.', 'Such processing may occur prior to input to the simulation component \n120\n (e.g., consider the processing component \n116\n).', 'As an example, the simulation component \n120\n may perform operations on input information based on one or more attributes specified by the attribute component \n130\n.', 'In an example embodiment, the simulation component \n120\n may construct one or more models of the geologic environment \n150\n, which may be relied on to simulate behavior of the geologic environment \n150\n (e.g., responsive to one or more acts, whether natural or artificial).', 'In the example of \nFIG. \n1\n, the analysis/visualization component \n142\n may allow for interaction with a model or model-based results (e.g., simulation results, etc.).', 'As an example, output from the simulation component \n120\n may be input to one or more other workflows, as indicated by a workflow component \n144\n.', 'As an example, the simulation component \n120\n may include one or more features of a simulator such as the ECLIPSE™ reservoir simulator (Schlumberger Limited, Houston Texas), the INTERSECT™ reservoir simulator (Schlumberger Limited, Houston Texas), etc.', 'As an example, a simulation component, a simulator, etc., may include features to implement one or more meshless techniques (e.g., to solve one or more equations, etc.).', 'As an example, a reservoir or reservoirs may be simulated with respect to one or more enhanced recovery techniques (e.g., consider a thermal process such as SAGD, etc.).', 'In an example embodiment, the management components \n110\n may include features of a commercially available framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Texas).', 'The PETREL® framework provides components that allow for optimization of exploration and development operations.', 'The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).', 'In an example embodiment, various aspects of the management components \n110\n may include add-ons or plug-ins that operate according to specifications of a framework environment.', 'For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Texas) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow.', 'The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user-friendly interfaces for efficient development.', 'In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'FIG.', '1\n also shows an example of a framework \n170\n that includes a model simulation layer \n180\n along with a framework services layer \n190\n, a framework core layer \n195\n and a modules layer \n175\n.', 'The framework \n170\n may include the commercially available OCEAN® framework where the model simulation layer \n180\n is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.', 'As an example, a framework may include features for implementing one or more mesh generation techniques.', 'For example, a framework may include an input component for receipt of information from interpretation of seismic data, one or more attributes based at least in part on seismic data, log data, image data, etc.', 'Such a framework may include a mesh generation component that processes input information, optionally in conjunction with other information, to generate a mesh.', 'In the example of \nFIG.', '1\n, the model simulation layer \n180\n may provide domain objects \n182\n, act as a data source \n184\n, provide for rendering \n186\n and provide for various user interfaces \n188\n.', 'Rendering \n186\n may provide a graphical environment in which applications can display their data while the user interfaces \n188\n may provide a common look and feel for application user interface components.', 'As an example, the domain objects \n182\n can include entity objects, property objects and optionally other objects.', 'Entity objects may be used to geometrically represent wells, surfaces, bodies, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters.', 'For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).', 'In the example of \nFIG.', '1\n, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks.', 'The model simulation layer \n180\n may be configured to model projects.', 'As such, a particular project may be stored where stored project information may include inputs, models, results and cases.', 'Thus, upon completion of a modeling session, a user may store a project.', 'At a later time, the project can be accessed and restored using the model simulation layer \n180\n, which can recreate instances of the relevant domain objects.', 'In the example of \nFIG.', '1\n, the geologic environment \n150\n may include layers (e.g., stratification) that include a reservoir \n151\n and one or more other features such as the fault \n153\n-\n1\n, the geobody \n153\n-\n2\n, etc.', 'As an example, the geologic environment \n150\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n152\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n155\n.', 'Such information may include information associated with downhole equipment \n154\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n156\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n155\n that may be configured for communications, noting that the satellite may additionally or instead include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n150\n as optionally including equipment \n157\n and \n158\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n159\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n157\n and/or \n158\n may include components, a system, systems, etc., for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As mentioned, the system \n100\n may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable in the PETREL® software, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, a workflow may be a process implementable in the OCEAN® framework.', 'As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).', 'As mentioned, a model or models can include some amount of uncertainty, which may be classified as a level of uncertainty as depending on various factors.', 'Uncertainty can be a factor in decision making, development of a reservoir or reservoirs, operation of equipment, etc.', 'As an example, a method can include evaluating and selecting production parameters (e.g., parameter values) under uncertainty pertaining to a model or models (e.g., consider an integrated model of various sub-models), which may model flow in one or more reservoirs, wells, networks, facilities, etc.', 'As an example, an economic model may be operatively coupled to one or more other models, for example, a production model may be coupled to an economic model to assess economics of production of hydrocarbons from one or more reservoirs.', 'Such an example may consider, for example, one or more of a surface network, a separation facility, a processing facility, transportation, etc.\n \nFIG.', '2\n illustrates a flowchart of an example of a method \n200\n according to an embodiment.', 'As shown, the method \n200\n includes a definition block \n210\n for defining realizations with respect to a reservoir or reservoirs in a geologic environment as created via a modeling framework, a performance block \n220\n for performing a sensitivity analysis on the defined realizations as may be represented by individual models, a selection block \n230\n for selecting a set of representative models (e.g., realizations) based at least in part on the sensitivity analysis such that a desired amount of uncertainty is represented, an optimization block \n240\n for optimizing an objective function that accounts for uncertainty \n244\n and optionally equipment condition \n248\n (e.g., equipment maintenance, failure, etc.) where the objective function is based on parameter values, an output block \n250\n for outputting a parameter values at convergence of the optimizing of the optimization block \n240\n, a validation block \n260\n for validating the parameter values with respect to the realizations to generate results, an audit block \n270\n for auditing the results where, if the audit is acceptable, the method \n200\n continues to a valid block \n280\n that indicates that the results are acceptably valid and where, if the audit is unacceptable, the method \n200\n continues to a not valid block \n290\n and then to the definition block \n210\n for generating additional realizations, which can provide for new representative models per the selection block \n230\n (e.g., new samples).', 'The method \n200\n can be associated with various computer-readable media (CRM) blocks \n211\n, \n221\n, \n231\n, \n241\n, \n251\n, \n261\n, and \n271\n.', 'Such blocks generally include instructions suitable for execution by one or more processors (or cores) to instruct a computing device or system to perform one or more actions.', 'As an example, a single medium may be configured with instructions to allow for, at least in part, performance of various actions of the method \n200\n.', 'As an example, a computer-readable medium (CRM) may be a computer-readable storage medium that is non-transitory and not a carrier wave and not a signal.', 'As shown in \nFIG.', '2\n, the audit block \n270\n is shown next to a series of plots \n272\n, which may be generated as to optimism and/or pessimism.', 'For example, realization-based results may be generated for an objective to maximum cumulative production of hydrocarbons from one or more reservoirs.', 'In such an example, one strategy may involve boosting (B) and another strategy may involve gas lift (GL) where the most optimistic boosting strategy may be compared to the most optimistic gas lift strategy to determine a strategy to implement to produce hydrocarbons from the one or more reservoirs, which may be over a period of years (e.g., optionally a decade or more).', 'As an example, a method such as the method \n200\n of \nFIG.', '2\n can include simulating one or more physical phenomena.', 'For example, a reservoir simulator can be utilized to simulate physical phenomena such as fluid flow from a reservoir to a well or wells.', 'As an example, one or more simulators may be implemented for one or more analyses.', 'As an example, a simulator may implement a finite element model, a finite difference model, a pillar grid model, a volume cell model, etc.', 'As an example, a model may be a dynamic model.', 'As an example, a model may be a static model (e.g., a steady-state model).', 'As an example, a reservoir model may be operative coupled to a surface network model, which may be coupled to one or more facilities models.', 'As an example, a model may be an integrated model that includes various models with coupling(s).', 'As an example, a model can include one or more equipment models such as, for example, a model for an electric submersible pump, a compressor, etc.', 'As an example, equipment can include subsurface equipment (e.g., disposed in a borehole, wellbore, etc.) and/or surface equipment.', 'As an example, a method can include accessing one or more performance tables that may include data generated by one or more model-based simulators.', 'In such an example, a performance table may be generated prior to an optimization and/or prior to a sensitivity analysis.', 'As an example, a model may be a history match material balance model.', 'As an example, a model may be a simplified reservoir model, for example, a model that may be a simplified version of an ECLIPSE® reservoir model or an INTERSECT™ reservoir model.', 'As an example, a model may be honed to reduce run-time overhead.', 'As mentioned, by selecting particular representative realizations (e.g., models or instances of models), a method can reduce run-time overhead with respect to an optimization while preserving an amount of desired uncertainty, which may exist in a larger number of realizations (e.g., statistically generated such as by random number generation of property values, etc., that may populate cells of a model that include grid cells).', 'As an example, a method can include running a preliminary optimization and then, based at least in part on parameter values from the preliminary optimization, running a more complex model (e.g., or integrated model) using a more accurate simulator (e.g., simulation framework such as, for example, ECLIPSE® framework, INTERSECT™ framework, etc.).', 'As an example, a simplified model may be a production decline curve model for a well or wells, which may be based, for example, on reservoir pressure, which may decline over time as pressure in a reservoir drainage area decreases.', 'Various embodiments can include performing a method that accounts for sensitivity.', 'For example, the performance block \n220\n of the method \n200\n can account for sensitivity.', 'As an example, a method can include utilizing an automated optimization tool, for example, in a manner that utilizes a selection process that can account for uncertainty.', 'In such an example, the selection process may be referred to selection under uncertainty utilizing smart sampling.', 'In the example of \nFIG.', '2\n, the selection block \n230\n is shown along with an example plot \n232\n of models (e.g., instances of a model or realizations) in a reduced dimensional space, which may be a metric space.', 'As an example, the selection block \n230\n can include applying a technique or techniques to reduce dimensionality of a multidimensional space associated with the defined realizations.', 'As an example, a method can include performing a cluster analysis of points in a reduced dimensional space (e.g., a metric space) where, for example, points may be selected based at least in part on how the points are clustered.', 'In such an example, individual points may be selected from corresponding individual clusters such that a selected number of representative models (e.g., instances of a model or realizations) may correspond to a number of clusters.', 'As an example, a cluster analysis may include setting a threshold or thresholds as to a size (e.g., area) and/or a number of points to define a cluster.', "As an example, a method may account for one or more decision-makers' tolerances to risk, for example, via a risk-aversion factor.", 'In such an example, the risk-aversion factor can be tied to historical data as to various historic outcomes.', 'For example, where particular risks are known to exist for development and/or production operations for a basin (e.g., oilfield), a risk-aversion factor range may be recommended and may be associated with particular types of favorable and unfavorable outcomes.', 'In such an example, information may guide a user in selection of a risk-aversion factor.', 'As an example, information may include risk sensitivity as to one or more entities and/or one or more mathematical models that account for production and cost.', 'As an example, various methods may account for reservoir uncertainty as well as surface network uncertainty, optionally in a manner that can accommodate equipment failures.', 'For example, one or more of remaining life of available equipment, service schedules of various equipment and operational ranges of various types of equipment may be taken into account for equipment that can be utilized in one or more field operations.', 'Such factors may be considered equipment condition factors such as indicated in the block \n248\n of the optimization block \n240\n of the method \n200\n of \nFIG.', '2\n.', 'As an example, a method may be implemented in a manner that aims to reduce a number of uncertainty realizations via a smart sampling technique.', 'For example, a solution may include a fewer number of uncertainty realizations through use of one or more smart sampling techniques (e.g., smart selection techniques) that may create “clusters” and extract a representative member of each cluster.', 'As an example, a sampling or selecting technique can include dimensional reduction such that a number of variables (e.g., parameters, etc.) are reduced to a fewer number in a multidimensional space (e.g., two-dimensional or three-dimensional) where sampling or selecting can be performed with at least some assurances of adequately accounting for a desired amount of uncertainty, etc.\n \nAs an example, a method can include modeling a complex field development in a manner that includes creating an integrated asset model for coupling reservoir models containing wells with network models, and then interacting this with facilities and an economic model or models at specified points in the system (e.g., boundary conditions).', 'As an example, in various embodiments, a method or methods may facilitate evaluation of an integrated model, for example, capturing uncertainty in a reservoir and an associated fluid flow network.', 'As an example, consider a method that includes the following enumerated activities.', 'A method may include a definition block for defining uncertainty and optimization (U&O) reservoir realizations, which may be generated in a seismic to simulation framework such as the PETREL® framework.', 'Such realizations may be referred to as simulation cases.', 'A method may commence by creating one or more reservoir simulation scenarios within a reservoir modeling framework (e.g., the PETREL® framework, etc.) using an uncertainty and optimization workflow.\n \nFIG.', '3\n shows examples of graphical user interfaces (GUIs) \n300\n, \n310\n and \n320\n as associated with a framework that can perform at a least a portion of the method \n200\n of \nFIG.', '2\n.', 'As shown in \nFIG.', '3\n, the GUI \n300\n includes a simulation graphic control and an uncertainty and optimization graphic control that may be selectable to cause rendering of the GUIs \n310\n and/or \n320\n.', 'The GUI \n310\n includes various graphic controls and fields for base case definition, variables definition, uncertainty definition, etc.', 'The GUI \n310\n also includes a run button, a test button and a free memory graphic control that may allow for releasing memory during a simulation run (e.g., after a number of iterations, a number of runs, etc.).', 'As to the GUI \n320\n, radio button graphic controls are shown as including cases for uncertainty, particularly uncertainty and optimization (U & O).', 'As shown, various uncertainty cases may be generated.', 'As an example, the GUI \n300\n may be a GUI of an uncertainty and optimization framework, which may be, for example, part of or operatively coupled to a framework such as the PETREL® framework.', 'In such an example, a number of realizations may be generated (e.g., instances of a grid cell model) and simulations run to generate results for the realizations.', 'As an example, such results may be part of a sensitivity analysis.', 'As an example, a method can include sensitivity and uncertainty analysis and, for example, generating probabilistic forecasts and/or optimizing operational parameter values, which may be implemented for field development.', 'As an example, an individual reservoir may have a base case and multiple realizations, which may be created to capture asset-level uncertainty, such as one or more of: \n \n \n \nFacies heterogeneity & distribution\n \nContacts: oil-water, gas-oil, multiple contacts\n \nRock property distributions (porosity, permeability in X, Y and Z directions etc.)', 'Faults & transmissibility barriers\n \nFluid properties (PVT).\n \n \n \n \n \nFIG.', '4\n shows an example of a table \n400\n, which may be a graphical user interface (GUI) or part of a GUI.', 'As shown, a number of realizations can be as small as two, depending upon how much uncertainty may be present in a particular reservoir under examination.', 'As an example, a method can include importing these realizations into an asset management software application, such as an integrated asset management (IAM) platform (e.g., IAM framework, marketed by Schlumberger Limited, Houston, Texas), and conducting a sensitivity analysis on the reservoir realizations.', 'For example, the performance block \n220\n of the method \n200\n can include receiving a number of realizations (e.g., two or more) and then performing one or more sensitivity analyses to generate sensitivity information.', 'As an example, realizations can be imported into an IAM platform and one or more sensitivity analyses carried out within these realizations.', 'As an example, sensitivity information generated by the one or more sensitivity analyses may optionally be output in a reduced dimensional space.', 'Models tend to be complex, as is the subsurface, as they can include various elements of modeling, such as the modeling of its structures, the geological processes of growth and/or deposition, the placement, movement or injection/extraction of fluid and gaseous phases contained in the rocks.', 'As such, models tend to be relatively high in their dimensionality, which may be described as a multidimensional space.', 'As information provided by measurement data, whether from boreholes or geophysics, tends to be limited spatially, interpretations based on data may aim to fill gaps, which can be a source of uncertainty in modeling.', 'To account for uncertainty, a number of alternatives, referred to as realizations, can be generated that reflect an ensemble of various sources of uncertainty.', 'However, the intrinsic variation between realizations can tend to be quite complex and challenging to reduce in terms of dimensionality.', 'As an example, an approach to characterize realizations (e.g., models) can include defining distances between models created with different (and possibly randomized) input parameter values.', 'As an example, a distance can be selected to correlate with the difference in a target response between two models (e.g., two realizations).', 'As an example, a distance can define a metric space with a relatively broad gamma of theory.', 'As an example, a method can include redefining a modeling problem (e.g., model selection and screening) with uncertainty evaluation in metric space.', 'Such an approach can increase effectiveness and efficiency where model and response uncertainty considerations are to be taken into account.', 'As an example, a method can include multidimensional scaling (MDS) to reduce dimensionality of models (e.g., realizations or instances of a model).', 'In such an example, sampling (e.g., selecting) may occur in a reduced space.', 'Such an approach may be referred to as smart sampling.', 'As an example, an MDS approach may assess realizations as to similarity and/or differences.', 'Such an approach may aim to preserve uncertainty in a selected number of realizations that is less than a generated number of realizations.', 'As an example, in a MDS approach, values plotted on an axis or axes may be without particular relevance, for example, as to an objective function associated with optimization.', 'In an MDS approach, relative positions of realizations (e.g., models) with respect to one or more other realizations can be instructive in assessing how similar or how different two realizations may be, which can be useful information when accounting for uncertainty.', 'As an example, a distance can be a Euclidean distance between locations of two realizations.', 'As an example, an MDS approach may be implemented in a manner where a reduced dimensional space may be of the order of about 5 dimensions or less.', 'For example, consider a four dimensional space, a three dimensional space or a two dimensional space.', 'As an example, in some instances a one dimensional space may provide for “cluster” analysis where realizations may be clustered along a line.', 'As an example, a selection process may include dimensional reduction to present realizations (e.g., models or instances of a model) in a connectivity distance space.', 'As an example, one or more kernel techniques may be utilized to transform from one metric space into a different metric space such that after projecting in 2D, 3D, etc., clusters may be generated.', 'As an example, one or more techniques may be applied such as clustering, principle component analysis (PCA), regression, etc., in a reduced space, optionally without knowledge of a Cartesian space.', 'As an example, a transformation may be utilized to transform from a metric space to another metric space.', 'Variability between realizations (e.g., models or instances of a model) may be more readily discerned via such a transform.', 'As an example, a MDS approach can transform a non-Euclidean distance into an approximating Euclidean distance.', 'As an example, a method can link Euclidean distances, Gaussian variables and kernels (e.g., radial basis function kernels, etc.).', 'As an example, a kernel function can simplify variability in a metric space defined by approximated Euclidean distances.', 'As an example, a distance may be a construct that captures a difference between two realizations where the distance is not itself a measure (e.g., not a length).', 'FIG.', '5\n shows an example plot \n500\n of realizations and associated two-dimensional coordinates for each of the realizations in a two-dimensional space.', 'In such a space, a method can include selecting representative uncertain reservoir realizations for carry-through into optimization (e.g., smart sampling).', 'As an example, the selection block \n230\n of the method \n200\n of \nFIG.', '2\n can include dimensional reduction at least in part via multidimensional scaling (MDS).', 'In particular, the plot \n500\n shows a plurality of models (e.g., realizations), which may be, for example, Gaussian models, as individual plots where each of the individual plots has a corresponding location in a reduced dimensional space, which may be referred to as a metric space.', 'In the metric space, a distance (e.g., connectivity distance) can exist that characterizes similarity of the models.', 'The models shown in the individual plots of the plot \n500\n correspond to selected models where selection of that portion of the total number of models represented is based on how those models are located in the metric space.', 'As an example, a projection technique may be applied to project a cloud of models from one space to a new space to facilitate selection.', 'As an example, a method can include transforming from a feature space to a metric space.', 'As an example, a method can include transforming from a metric space to another metric space.', 'In the example plot \n500\n, each of the plots can correspond to selected reservoir models where, for example, porosity in each of the models can differ (e.g., each reservoir model being a grid cell model with porosity values assigned to each of the grid cells of the model).', 'In such an example, each model can be a realization or an instance of the grid cell model where the porosity values differ in a manner that is based at least in part on uncertainty as to porosity in the grid cell model.', 'Such models (e.g., instances of the grid cell model) can exist in a high dimensional space where a technique such as MDS can reduce those models to points in a lower dimensional space (e.g., a 2D space).', 'Distances between the points can be distances in a least-squared sense that represent similarity or lack thereof between the models (e.g., instances of the grid cell model or realizations).', 'As an example, after plotting sensitivity information from realizations, a method may include selecting a reduced, but representative, number of samples for optimization purposes based on what are potentially long computational times of the simulator.', 'As an example, smart sampling can be a way to achieve this by identifying clusters, as shown in \nFIG.', '5\n.', 'For example, one or more clusters can be identified in a reduced space and samples extracted such that a representative member of each cluster is selected to generate a representative set of samples (e.g., a representative set of models or realizations).', 'As an example, the selection block \n230\n of the method \n200\n of \nFIG.', '2\n can reduce the number of realizations that may then be used as representative samples for an optimization.', 'Per the plot of \nFIG.', '5\n, such representative samples can be selected with some assurances that they cover a broad range of cases in an uncertainty space (e.g., the two-dimensional plotted space of the plot \n500\n of \nFIG.', '5\n).', 'As an example, smart sampling (or screening) may include using one or more other sampling techniques such as Latin hypercube, polynomial chaos, etc.', 'As explained with respect to the block \n248\n of the method \n200\n of \nFIG.', '2\n, a method can optionally include defining equipment-run-life failure expectations in a wellbore, a surface network and associated facilities.', 'For example, these factors may be declared as survival curves which may be single, expected estimates or an ensemble using confidence intervals straddling these expected survival curves.', 'In a surface network model, survival curves for equipment may be defined as shown in an example plot \n600\n of \nFIG.', '6\n.', 'Such survival curves can document the expected run-life failure for equipment after installation.', 'The plot \n600\n may be generated for different elements and aspects of equipment, whether for a surface network, downhole, facilities, transport, etc.', 'In \nFIG.', '6\n, the plot \n600\n shows Cox Proportional Hazard (CPH) equipment curves and the proportion of equipment that remains operationally “OK” (e.g., usable) with respect to time.', 'As an example, one or more of CPH, Kaplan-Meier (KM) or another type of modeling approach may be utilized to analyze and/or to characterize equipment.', 'As to optimization, for example, per the optimization block \n240\n of the method \n200\n of \nFIG.', '2\n, when running an optimization, random equipment failure may be penalized through one or more time steps of a simulation.', 'For example, equipment failure may be taken into account at each time step via increments and/or via one or more less frequent time steps via an increment, increments or other type of degradation condition (e.g., failure, etc.).', 'As an example, a method can include run an optimization under uncertainty in a manner that includes combining reservoir uncertainty with equipment failure.', 'As an example, such an optimization may be performed in an integrated asset modeler framework (IAM framework).', 'As an example, an optimization can consider a suitable objective function, which may be defined and/or modified by a user.', 'As an example, an objective function may be directed to total production or net present value (NPV) of hydrocarbons based on a volume metric, a rate metric, etc.', 'As an example, once a reduced number of realizations from smart sampling or otherwise, are identified, a method may include bringing them into an integrated model in a framework (e.g., IAM framework).', 'In such an example, first, a base case of each reservoir and surface network (e.g., optionally including failure probabilities) can be used to create an integrated model as shown in an example of a graphical user interface (GUI) \n700\n of \nFIG.', '7\n, where a panel \n710\n (e.g., window of the GUI \n700\n) shows that two reservoirs (e.g., PETREL® framework models) are connected to surface network model (e.g., a PIPESIM™ framework model), facility model and economics model (e.g., a PEEP™ framework model, Schlumberger Limited, Houston, Texas), followed by a validation of the resulting FDP.', 'The GUI \n700\n also shows various graphic controls \n720\n for selection and/or generation of graphs such as, for example, reservoir simulator and/or surface network simulator rates (e.g., GOR, etc.), gas rates, pressure matches, plant power consumption (e.g., compressor power for gas, etc.).', 'As an example, the IAM framework can achieve more accurate forecasts by accounting for the interactions of subsurface deliverability with surface backpressure constraints in model compositional blending, mixing, and injection of multiple producing zones and reservoirs to meet product specifications; optimize the use of artificial lift, EOR, and IOR injection; plan gas storage operations by predicting deliverability and optimizing compression design; control cross flow between sands using optimized inlet control valves in complex wells; and/or debottleneck pipeline network field processing facilities.', 'As an example, the IAM framework can provide a production simulation environment that integrates asset details of a plurality of individual simulation models (e.g., of a reservoir or reservoirs, a well or wells, a surface infrastructure or infrastructures, a process facility or facilities).', 'In such an example, the simulation environment can allow for logical connections, constraints, and optimization routines to be implemented so that the value of multiple development options or operating scenarios can be compared, maximized, etc.\n \nFIG.', '8\n shows an example of a table \n800\n that may be a graphical user interface (GUI) that can be utilized to link models (e.g., reservoir models, such as suitable for a reservoir simulator such as the ECLIPSE® framework simulator).', 'In such an example, a method may utilize such a table or GUI to select the reduced number of realizations from smart sampling and, for example, allow for assigning weights to the selected reduced number of realizations, for example, according to a desired distribution.', 'Such a weighting process may be manually from expert input or computed from their respective distributions (e.g., automated or semi-automated).', 'FIG.', '9\n shows examples of two graphical user interfaces (GUIs) \n910\n and \n920\n for each trial of the optimization that includes running each realization where the computed objective function accounts for the corresponding weight.', 'For example, for the two reservoirs (m=2) and the three smart realizations for each reservoir (N=3), the weights can differ as can a selected number of cases.', 'As mentioned, two reservoirs may be operatively coupled to a common surface network, for example, a surface network that includes at least some common surface equipment.', 'Such a surface network may route hydrocarbons from wells to a common handling facility.', 'As an example, where fluid is injected (e.g., liquid and/or gas) into a well and/or a formation, a surface network may route such fluid (or fluids) from one region to another (e.g., for gas lift, etc.).', 'In the example GUIs \n910\n and \n920\n, the two reservoir scenario results in N*m=9 simulations per trial in the optimization, as shown in a table \n1000\n of \nFIG.', "10\n, with each simulation run's objective function accounted for according to product of weightages, which are normalized to compute a final objective function of the trial.", 'As an example, if one or more equipment failures occur during a trial, the objective function of the corresponding realization may be penalized accordingly.', 'As an example, a method can include establish an optimal operating strategy obtained upon optimization convergence in an IAM framework after accounting for risk.', 'For example, the output block \n250\n of the method \n200\n of \nFIG.', '2\n can output parameter values for an optimization once the optimization has appropriately converged according to one or more convergence criteria (e.g., error, number of iterations, etc.).', 'As an example, for an optimization, an objective function may be, for example, a difference of cumulative oil production and cumulative water production; a net present value; a recover factor; another metric.', 'As mentioned, an objective function may be modified according to a risk-aversion factor (λ).', 'Such a factor may be utilized to compute an objective function (e.g., F=μ λσ) when optimizing an objective function in the presence of uncertainty.', 'In such an example, the factor λ can provide a manner by which a user may establish (e.g., impart) a level of confidence to output parameter values.', 'For example, by assuming that output parameter values are normally distributed, a method can include formulating a table such as Table 1, below, which includes confidence levels with for various values of user-defined (e.g., or user-selected, etc.)', 'risk aversion, λ, as:\n \n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \nValue of Lambda, λ\n \nDegree of confidence at this value\n \n \n \n(Risk Aversion Factor)\n \n(assuming normal distribution of results)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n0\n \n50.00%\n \n \n \n0.5\n \n69.15%\n \n \n \n1.0\n \n84.13%\n \n \n \n1.5\n \n93.32%\n \n \n \n2.0\n \n97.72%\n \n \n \n2.5\n \n99.38%\n \n \n \n3.0\n \n99.87%\n \n \n \n \n \n \n \n \n \n \nAs an example, decision variables—to which the objective function is sensitive—may be defined as those that an optimizer varies to find an optimal solution to a problem.', 'As an example, different decision variables may be employed for the optimization corresponding to a chosen Enhanced Oil Recovery (EOR) strategy such as: Artificial-lift screening; Gas-lift allocation; Booster-pump capacity; Dual lift, etc.', 'As an example, each optimization run can include multiple trials, which continue until a convergence tolerance (e.g., optionally specified by the user) is reached for a given objective function.', 'Such an optimization workflow may be expedited by more rapid solution optimization schemes (more rapid convergence) and smart sampling capabilities.', 'An optimized objective function value can be obtained corresponding to an optimized strategy in a final trial run as shown in example plots \n1110\n and \n1120\n of \nFIG.', '11\n where a solution space is illustrated in the plot \n1110\n that includes a surface and where values are plotted in the plot \n1120\n as to a desired optimization goal are illustrated in reaching an optimized solution (e.g., optimized parameter values).', 'In the plots \n1110\n and \n1120\n of \nFIG. \n11\n, the objective function is formulated to as cumulative oil production such that optimizing can optimize cumulative oil production.', 'In such an example, decision variables included gas injection rates, water injection rates, producer rates, variation in injection rates, and completion zone for injectors.', 'In the plot \n1120\n, an arrow represents an increase in the objection function value where parameter values are optimized to maximize cumulative oil production.', 'The plot \n1110\n shows an arrow and two markers where the arrow represents an overall increase in cumulative oil production with respect to an initial solution (e.g., initial set of parameter values) and an optimized solution (e.g., optimized set of parameter values).', 'The path from one marker to the other may differ depending on the type of optimization algorithm utilized (e.g., not necessarily a straight line path in the plot \n1110\n).', 'In the example of \nFIG. \n11\n, the plot \n1120\n of objective function values versus trials demonstrates how interpretation and analysis accounts for uncertainty (e.g., as in simulations) to determine operational configurations and/or settings (e.g., parameter values).', 'In the plot \n1120\n, each marker represents a set of parameters values in an uncertainty space that gives rise to a corresponding level of production.', 'Such an approach accounts for an amount of uncertainty that is preserved via selection of representative realizations (e.g., models or model instances), which may occur, for example, in a metric space that is generated at least in part by MDS.', 'As mentioned with respect to the method \n200\n of \nFIG.', '2\n, the validation block \n260\n can provide for validating output parameter values with respect to realizations to generate results.', 'For example, a validation process can include validating output parameter values of an optimizer where the parameter values represent an optimal strategy.', 'In such an example, validating can include applying the optimal strategy to at least some of the realizations (e.g., at least a portion of the models).', 'As an example, validating may apply the optimal strategy to each of the realizations and/or to each of the selected realizations (e.g., selected representative models).', 'As an example, a method can include validating an optimal strategy by using optimal parameter values for PETREL® U & O realizations.', 'As an example, results generated from validating can be used to generate statistics and analysis curves.\n \nFIG.', '12\n shows an example plot \n1200\n of curves labeled as corresponding to optimistic and pessimistic cases, as may be extracted, P10, P50 and P90 cases or others degrees of confidence, etc.', 'As shown, such curves can depend, for example, upon one or more selected strategies.', 'For example, the plot \n1200\n shows curves for a boosting strategy (B) and curves for a gas lifting strategy (GL).', 'As an example, an audit may be analyzed.', 'For example, the audit block \n270\n can include analyzing audit results for acceptability; where, if not acceptable (e.g., not valid), the method \n200\n may restart at the definition block \n210\n.', 'As an example, results may be audited for acceptability based on whether they are within one or more tolerances.', 'For example, consider an erosional velocity limit due to flow rates due to choke setting or increased gas lift or boosting as shown in an example plot \n1300\n of \nFIG. \n13\n.', 'In such an example, if the results are not acceptable, then the method \n200\n may be restarted, for example, with one or more modified realizations, and re-run until an acceptable, satisfactory solution is found.', 'As shown in the example method \n200\n of \nFIG.', '2\n, if the audit results are acceptable, then the optimization under uncertainty for integrated models workflow may be complete.', 'In such an example, implementation of at least a portion of the strategy may be undertaken.', 'For example, one or more parameter values associated with an optimal strategy may be utilized to perform one or more operations, which may include one or more field operations, one or more off-site operations, etc.\n \nFIG.', '14\n shows an example of a method \n1400\n that includes a reception block \n1410\n for receiving realizations for a model of a reservoir that includes at least one well; a selection block \n1420\n for selecting a portion of the realizations to preserve an amount of uncertainty; an optimization block \n1430\n for optimizing an objective function; an output block \n1440\n for outputting parameter values for the optimized objective function; and a generation block \n1450\n for generating at least a portion of a field operations plan based at least in part on the parameter values.', 'The method \n1400\n can be associated with various computer-readable media (CRM) blocks \n1411\n, \n1421\n, \n1431\n, \n1441\n, and \n1451\n.', 'Such blocks generally include instructions suitable for execution by one or more processors (or cores) to instruct a computing device or system to perform one or more actions.', 'As an example, a single medium may be configured with instructions to allow for, at least in part, performance of various actions of the method \n1400\n.', 'As an example, a computer-readable medium (CRM) may be a computer-readable storage medium that is non-transitory and not a carrier wave and not a signal.', 'In the example of \nFIG.', '14', ', the field operations plan of the generation block \n1450\n can include parameters where at least some of those parameters may be assigned values output by the output block \n1440\n.', 'As an example, a field operations plan can include one or more well plans.', 'A well plan can include a well trajectory that is to be followed to drill a well.', 'As an example, a field operations plan can include one or more pieces of surface network equipment.', 'As an example, a field operations plan can include an equipment schedule for maintenance, replacement, etc. of equipment.', 'As an example, a field operations plan can include an operational schedule for operating one or more pieces of equipment (e.g., controlling one or more pieces of equipment such as, for example, a choke valve, a gas lift valve, an electric submersible pump, etc.).', 'In the example of \nFIG.', '14\n, the optimization block \n1430\n can optimize an objective function that spans a period of time.', 'For example, one of the at least one well can be a producing well that produces hydrocarbons over a period of time.', 'In such an example, the production of hydrocarbons may depend on one or more parameter values, which may include time dependency.', 'For example, a parameter value may be associated with a choke valve of the well, a parameter value may be associated with a gas lift rate, etc.', 'As an example, a well may have a production curve over a period of time where a cumulative amount of hydrocarbons can be produced over that period of time.', 'As an example, the rate of production over that period of time may change.', 'For example, consider a production decline curve where production from a well declines over time.', 'In such an example, factors such as choke valve setting(s) and/or gas lift rate(s) may affect a production decline curve for a well.', 'As an example, parameter values may include a series of parameter values for equipment control over a period of time.', 'For example, consider a series of parameter values for control of a choke on a monthly basis over a period time that spans a year or more.', 'As an example, output from an optimization may be a schedule of how to adjust a choke valve over a period of time.', 'As mentioned, uncertainty can exist as to various factors and a method such as the method \n1400\n can aim to represent such uncertainty with a particular number of realizations, which is less than a number of generated realizations.', 'In such an example, the number of generated realizations may be statistically generated and then analyzed using, for example, an MDS approach whereby a selection process can appropriately select a number of the generated realizations, which is less than the total number, to reduce a problem for optimization while maintaining representative uncertainty.', 'As an example, the realizations of the reception block \n1410\n of the method \n1400\n can be defined with respect to a multidimensional space and the portion of the realizations of the selection block \n1420\n can be selected via selection of points in a reduce dimensional space, a space with a fewer number of dimensions than the multidimensional space of the realizations of the reception block \n1410\n.', 'In such an example, the reduced dimensional space may be a metric space, which may be generated via a technique such as, for example, multidimensional scaling (MDS).', 'As an example, a clustering technique may be applied (e.g., kernel approach) to identify one or more clusters.', 'As an example, a selection technique can include selecting representative realizations based on clusters where, for example, a point may be selected from an identified cluster of points in a metric space.', 'As an example, a method can include metric space modeling to reduce dimensionality of realizations from a multidimensional space to a reduced dimensionality metric space.', 'In such an example, processes accompanied by modeling a reservoir or reservoirs may be reformulated and performed in metric space, where the location of a model is determined by mutual differences in responses as defined by a distance (a metric space distance).', 'In such an example, a method can include defining a distance to construct a metric space for an initial set of multiple models and then representing the metric space by its projection to a low-dimensional space via a technique such as multidimensional scaling (MDS).', 'In such an example, MDS can generate a map of points while maintaining the distance between pairs of two points.', 'In such an example, MDS can allow for further analysis of an ensemble of multiple models via visual inspection and/or via one or more statistical analysis techniques.', 'From a constructed metric space, a number of representative models may be selected.', 'Such a selection process may utilize one or more approaches (e.g., screening, clustering, etc.).', 'Dimensional reduction can, for example, transform a model, which may be an integrated model represented by millions of parameters (e.g., properties at each grid cell of a grid cell model, node of a surface network model, etc.), into metric space where the model is represented by a distance between other models that can be a distance that is correlated with the output of application (e.g., response of interest, etc.).', 'As an example, a distance in an MDS approach can be defined at least in part by response of a model, such as, for example, oil production, bottom hole pressure, etc., as may be obtained via simulation, etc.', 'As an example, an integrated model can be a model that includes heterogeneous models.', 'For example, a reservoir model and a surface network model are heterogeneous models as one pertains to hydrocarbons in a reservoir and the other pertains to equipment for handling of hydrocarbons and optionally one or more other materials; whereas, two ECLIPSE® reservoir simulator flow models are homogenous models.', 'As an example, an integrated model can include models of different frameworks, such that they are defined as heterogeneous models.', 'As an example, an integrated model can have a response that depends on coupling of a plurality of models, which can include heterogeneous models.\n \nFIG.', '15\n shows an example of a geologic environment \n1510\n that includes reservoirs \n1511\n-\n1\n and \n1511\n-\n2\n, which may be faulted by faults \n1512\n-\n1\n and \n1512\n-\n2\n. \nFIG.', '15\n also shows some examples of offshore equipment \n1514\n for oil and gas operations related to the reservoirs \n1511\n-\n1\n and \n1511\n-\n2\n and onshore equipment \n1516\n for oil and gas operations related to the reservoir \n1511\n-\n1\n.', 'As an example, a model may be made that models a geologic environment in combination with equipment, wells, etc.', 'For example, a model may be a flow simulation model for use by a simulator to simulate flow in an oil, gas or oil and gas production system.', 'Such a flow simulation model may include equations, for example, to model multiphase flow from a reservoir to a wellhead, from a wellhead to a reservoir, etc.', 'A flow simulation model may also include equations that account for flowline and surface facility performance, for example, to perform a comprehensive production system analysis.', 'As an example, a flow simulation model may be a network model that includes various sub-networks specified using nodes, segments, branches, etc.', 'As an example, a flow simulation model may be specified in a manner that provides for modeling of branched segments, multilateral segments, complex completions, intelligent downhole controls, etc.', 'As an example, one or more portions of a production network (e.g., optionally sub-networks, etc.) or a group of signal components and/or controllers may be modeled as sub-models.', 'As an example, a system may provide for transportation of oil and gas fluids from well locations to processing facilities and may represent a substantial investment in infrastructure with both economic and environmental impact.', 'Simulation of such a system, which may include hundreds or thousands of flow lines and production equipment interconnected at junctions to form a network, can involve multiphase flow science and, for example, use of engineering and mathematical techniques for large systems of equations.', 'As an example, a flow simulation model may include equations for performing nodal analysis, pressure-volume-temperature (PVT) analysis, gas lift analysis, erosion analysis, corrosion analysis, production analysis, injection analysis, etc.', 'In such an example, one or more analyses may be based, in part, on a simulation of flow in a modeled network.', 'As to nodal analysis, it may provide for evaluation of well performance, for making decisions as to completions, etc.', 'A nodal analysis may provide for an understanding of behavior of a system and optionally sensitivity of a system (e.g., production, injection, production and injection).', 'For example, a system variable may be selected for investigation and a sensitivity analysis performed.', 'Such an analysis may include plotting inflow and outflow of fluid at a nodal point or nodal points in the system, which may indicate where certain opportunities exist (e.g., for injection, for production, etc.).', 'A modeling framework may include components to facilitate generation of a flow simulation model.', 'For example, a component may provide for modeling completions for vertical wells, completions for horizontal wells, completions for fractured wells, etc.', 'A modeling framework may include modules for particular types of equations, for example, black-oil equations, equation-of-state (EOS) equations, etc.', 'A modeling framework may include modules for artificial lift, for example, to model fluid injection, fluid pumping, etc.', 'As an example, consider a component that includes features for modeling one or more electric submersible pumps (ESPs) (e.g., based in part on pump performance curves, motors, cables, etc.).', 'As an example, an analysis using a flow simulation model may be a network analysis to: identify production bottlenecks and constraints; assess benefits of new wells, additional pipelines, compression systems, etc.; calculate deliverability from field gathering systems; predict pressure and temperature profiles through flow paths; or plan full-field development.', 'As an example, a flow simulation model may provide for analyses with respect to future times, for example, to allow for optimization of production equipment, injection equipment, etc.', 'As an example, consider an optimal time-based and conditional-event logic representation for daily field development operations that can be used to evaluate drilling of new developmental wells, installing additional processing facilities over time, choke-adjusted wells to meet production and operating limits, shutting in of depleting wells as reservoir conditions decline, etc.\n \nAs to equations, sets of conservation equations for mass momentum and energy describing single, two or three phase flow (e.g., according to one or more of a LEDAFLOW™ (Kongsberg Oil & Gas Technologies AS, Sandvika, Norway), OLGA™ model (Schlumberger Ltd, Houston, Texas), TUFFP unified mechanistic models (Tulsa University Fluid Flow Projects, Tulsa, Oklahoma), etc.).', 'FIG.', '15\n also shows an example of a relatively small production system network \n1580\n (e.g., optionally a portion of a larger network \n1570\n).', 'As shown, the network \n1580\n forms somewhat of a tree like structure where flowlines represent branches (e.g., segments) and junctions represent nodes.', 'As shown in \nFIG.', '15\n, the network \n1580\n provides for transportation of oil and gas fluids from well locations along flowlines interconnected at junctions with final delivery at a central processing facility.', 'In the example of \nFIG.', '15\n, various portions of the network \n1580\n may include conduit, for example, consider two conduits which may be a conduit to Man1 and a conduit to Man3 in the network \n1580\n.', 'The conduits may be specified at various points by characteristics, which may be characteristics of the environment, characteristics of the conduits, characteristics of fluid in the conduits, etc.', 'For example, consider conduit elevation, which may allow for determination of conduit inclination.', 'As an example, consider conduit cross-sectional flow area, which may be defined by one or more parameters such as, for example, a conduit diameter.', 'As an example, consider fluid that may flow in a conduit where the fluid may be characterized at least in part by a property such as, for example, viscosity.', 'As an example, thermal conditions may optionally be considered such as, for example, latent heat, heat transfer, etc.', 'As an example, thermal conditions may depend on insulation of equipment, temperature of an environment, wind, sun, rain, snow, etc.', 'Such factors may be considered when assessing an existing network, developing a network, extending a network, etc.', 'As an example, given information of operating condition(s) at boundary nodes (e.g., where fluid enters and exists the system) and the physical environment between them (e.g., geographical location, elevation, ambient temperature, etc.), a production engineer may aim to design a production system that meets business and regulatory requirements constrained to operating limits of available equipment.', 'As an example, a method can include implementing one or more modules to simulate steady state operation of a production system, for example, as including a network (e.g., as a sub-network, etc.) as in the example of \nFIG.', '15\n (also see, e.g., \nFIG.', '1\n).', 'Such a method may include simulating the steady state operation over a selected range of operating conditions and configurations (e.g., optionally a broadest reasonable range).', 'As explained, a production system may provide for transportation of oil and gas fluids from well locations to a processing facility and can represent a substantial investment in infrastructure with both economic and environmental impact.', 'Simulation of such a system, which may include hundreds or thousands of flow lines and production equipment interconnected at junctions to form a network, can be complex and involve multiphase flow science and engineering and mathematical methods to provide solutions (e.g., by solving large systems of non-linear equations).', 'Factors associated with solid formation, corrosion and erosion, and environmental impact may increase complexity and cost.', 'As an example of a production network consider the Kashagan Island D, which is a structural development for field operations as connected with a plurality of wells (e.g., over 10 wells).', 'The Island D includes trains of production for separating oil and gas and for delivering these fluids to an onshore plant and, for example, for dehydrating and partly re-injecting sour gas into the reservoir.', 'Fluid is transported onshore by an approximately 92 kilometer long pipeline.', 'Initial production is expected to be about 90,000 barrels per day (14,000 m\n3\n/d), reaching a production rate of about 370,000 barrels per day (59,000 m\n3\n/d).', 'As an example, the method \n1400\n of \nFIG.', '14\n may be implemented at a site such as a field site where various field operations are to be performed.', 'As an example, during development of a site, such a method may be run more than once, for example, to optimize on-going development (e.g., to account for variations from a field operations plan, etc.).', 'As an example, during production of hydrocarbons, information acquired may be utilized in one or more comparisons with respect to a generated field operations plan, which may inform a subsequent optimization, etc.', 'As an example, a method can include receiving realizations of a model of a reservoir that includes at least one well where the realizations represent uncertainty in a multidimensional space; selecting a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimizing an objective function based at least in part on the selected portion of the realizations; outputting parameter values for the optimized objective function; and generating at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.', 'In such an example, the realizations of the model can be or can include randomly generated realizations.', 'As an example, realizations may be generated using one or more statistical techniques (e.g., sampling from distributions, etc.).', 'As an example, a method can include selecting a portion of realizations from a number of generated multidimensional space realizations via multidimensional scaling of the generated multidimensional space realizations to a reduced dimensional space where, for example, the reduced dimensional space can be a metric space.', 'In such an example, clustering may be utilized.', 'As an example, k-means clustering may be utilized, which can include vector quantization for partitioning n observations into k clusters in which each observation belongs to the cluster with the nearest mean, which can serve as a prototype of the cluster.', 'As an example, k-means clustering may partition a space into Voronoi cells.', 'As an example, a selection process can include selecting individual realizations (e.g., a model or instance of a model) from a plurality of individual clusters, which may be Voronoi cells.', 'As an example, a method can include weighting selected realizations.', 'For example, the GUIs \n910\n and \n920\n of \nFIG.', '9\n show how a GUI may be implemented to allow for receipt of input that weights individual realizations, which are shown as individual cases.', 'Such weights can then be utilized in an optimization routine that optimizes an objective function based at least in part on the selected realizations.', 'As an example, a method may include equal weighting where the weights sum to unity or may include biased weighting where one or more realizations are weighted differently than one or more other realizations.', 'As an example, a method can include performing a sensitivity analysis on realizations of a model.', 'In such an example, the method can include selecting a portion of the realizations via multidimensional scaling that is based at least in part on performing the sensitivity analysis.', 'As an example, a model can be an integrated model, which may be an integrated model of homogenous model types or an integrated model of heterogeneous model types.', 'For example, an integrated model of heterogeneous model types can include a surface network model operatively coupled to a reservoir model or reservoir models.', 'As an example, a model can be an integrated model of a surface network model operatively coupled to a plurality of reservoir models.', 'As an example, an objective function can accounts for equipment condition.', 'In such an example, the objective function can be penalized for equipment failure.', 'In such an example, the objective function can account for time, which may be, for example, a period of years.', 'In such an example, where one or more pieces of equipment deteriorate in their condition, failure may occur, which can then penalize the objective function such that an optimization process may seek alternatives where equipment failure does not occur, does not occur to such an extent, is delayed in time (e.g., to a lower production rate period of time), etc.', 'As an example, data and/or models of equipment condition may be received and utilized as part of a method.', 'As an example, a method can include optimizing an objective function to optimize cumulative production of hydrocarbons from a reservoir.', 'As an example, parameter values from an optimization can include at least one time dependent series of parameter values.', 'For example, consider at least one time dependent series of parameter values that includes a time dependent series of well choke valve parameter values for a well or wells and/or a time dependent series of gas lift parameter values for a well or wells.', 'As an example, a method can include rendering a graphical user interface to a display and linking output from at least two modeling frameworks to generate the model, which can be an integrated model.', 'As an example, a method can include generating at least a portion of a field operations plan based at least in part on parameter values from an optimization of an objective function for a selected number of realizations and, for example, auditing at least a portion of the parameter values for a plurality of realizations, which may optionally exceed the selected number of realizations.', 'As an example, a method can include receiving a risk factor value and modifying an objective function based at least in part on the risk factor value.', 'As an example, a system can include a processor; memory accessible by the processor; processor-executable instructions stored in the memory and executable to instruct the system to: receive realizations of a model of a reservoir that includes at least one well where the realizations represent uncertainty in a multidimensional space; select a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimize an objective function based at least in part on the selected portion of the realizations; output parameter values for the optimized objective function; and generate at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.', 'In such an example, the model can be an integrated model.', 'For example, consider an integrated model of a surface network model operatively coupled to the reservoir model.', 'As an example, a system can implement an objective function that accounts for equipment condition where such equipment may be equipment to be utilized in a field operation or operations.', 'As an example, a system can include processor-executable instructions to receive a risk factor value and to modify an objective function based at least in part on the risk factor value.', 'As an example, one or more computer-readable storage media can include processor-executable instructions to instruct a computing system to: receive realizations of a model of a reservoir that includes at least one well where the realizations represent uncertainty in a multidimensional space; select a portion of the realizations in a reduced dimensional space to preserve an amount of the uncertainty; optimize an objective function based at least in part on the selected portion of the realizations; output parameter values for the optimized objective function; and generate at least a portion of a field operations plan based at least in part on at least a portion of the parameter values.', 'As an example, method for modeling a reservoir can include defining a plurality of reservoir realizations; conducting a sensitivity analysis on the plurality of reservoir realizations; selecting one or more uncertain reservoir realizations based on the sensitivity analysis; determining uncertainty by combining reservoir uncertainty with equipment failure, using an objective function; determining an operating strategy based on the uncertainty; and validating the operating strategy by applying optimal strategy to each of the plurality of realizations.', 'As an example, a computing system can include one or more processors; and a memory system that includes one or more non-transitory computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations, the operations including: defining a plurality of reservoir realizations; conducting a sensitivity analysis on the plurality of reservoir realizations; selecting one or more uncertain reservoir realizations based on the sensitivity analysis; determining uncertainty by combining reservoir uncertainty with equipment failure, using an objective function; determining an operating strategy based on the uncertainty; and validating the operating strategy by applying optimal strategy to each of the plurality of realizations.', 'As an example, a non-transitory computer-readable medium can store instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations, the operations including: defining a plurality of reservoir realizations; conducting a sensitivity analysis on the plurality of reservoir realizations; selecting one or more uncertain reservoir realizations based on the sensitivity analysis; determining uncertainty by combining reservoir uncertainty with equipment failure, using an objective function; determining an operating strategy based on the uncertainty; and validating the operating strategy by applying optimal strategy to each of the plurality of realizations.', 'In some embodiments, the methods of the present disclosure may be executed by a computing system.', 'FIG.', '16\n illustrates an example of such a computing system \n1600\n, in accordance with some embodiments.', 'The computing system \n1600\n may include a computer or computer system \n1601\n-\n1\n, which may be an individual computer system \n1601\n-\n1\n or an arrangement of distributed computer systems.', 'The computer system \n1601\n-\n1\n includes one or more analysis modules \n1602\n that are configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein.', 'To perform these various tasks, the analysis module/instructions \n1602\n executes independently, or in coordination with, one or more processors \n1604\n, which is (or are) connected to one or more storage media \n1606\n.', 'The processor(s) \n1604\n is (or are) also connected to a network interface \n1607\n to allow the computer system \n1601\n-\n1\n to communicate over a data network \n1609\n with one or more additional computer systems and/or computing systems, such as \n1601\n-\n2\n, \n1601\n-\n3\n, and/or \n1601\n-\n4\n (note that computer systems \n1601\n-\n2\n, \n1601\n-\n3\n and/or \n1601\n-\n4\n may or may not share the same architecture as computer system \n1601\n-\n1\n, and may be located in different physical locations, e.g., computer systems \n1601\n-\n1\n and \n1601\n-\n2\n may be located in a processing facility, while in communication with one or more computer systems such as \n1601\n-\n3\n and/or \n1601\n-\n4\n that are located in one or more data centers, and/or located in varying countries on different continents).', 'A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'The storage media \n1606\n may be implemented as one or more computer-readable or machine-readable storage media.', 'Note that while in the example embodiment of \nFIG.', '16\n storage media \n1606\n is depicted as within computer system \n1601\n-\n1\n, in some embodiments, storage media \n1606\n may be distributed within and/or across multiple internal and/or external enclosures of computing system \n1601\n-\n1\n and/or additional computing systems.', 'Storage media \n1606\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY® disks, or other types of optical storage, or other types of storage devices.', 'Note that the instructions discussed above may be provided on one computer-readable or machine-readable storage medium, or may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture).', 'An article or article of manufacture may refer to any manufactured single component or multiple components.', 'The storage medium or media may be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In some embodiments, computing system \n1600\n contains one or more asset modeling module(s) \n1608\n.', 'In the example of computing system \n1600\n, computer system \n1601\n-\n1\n includes the asset modeling module \n1608\n.', 'In some embodiments, a single asset modeling module may be used to perform some aspects of one or more embodiments of the methods disclosed herein.', 'In other embodiments, a plurality of asset modeling modules may be used to perform some aspects of methods herein.', 'The computing system \n1600\n is merely one example of a computing system, and that computing system \n1600\n may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of \nFIG.', '16\n, and/or computing system \n1600\n may have a different configuration or arrangement of the components depicted in \nFIG. \n16\n.', 'The various components shown in \nFIG.', '16\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices.', 'These modules, combinations of these modules, and/or their combination with general hardware are included within the scope of the present disclosure.', 'Geologic interpretations, models, and/or other interpretation aids may be refined in an iterative fashion; this concept is applicable to the methods discussed herein.', 'This may include use of feedback loops executed on an algorithmic basis, such as at a computing device (e.g., computing system \n1600\n, \nFIG. \n16\n), and/or through manual control by a user who may make determinations regarding whether a given step, action, template, model, or set of curves has become sufficiently accurate for the evaluation of the subsurface three-dimensional geologic formation under consideration.', 'As an example, a device may be a mobile device that includes one or more network interfaces for communication of information.', 'For example, a mobile device may include a wireless network interface (e.g., operable via IEEE 802.11, ETSI GSM, BLUETOOTH®, satellite, etc.).', 'As an example, a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM slot, audio/video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery.', 'As an example, a mobile device may be configured as a cell phone, a tablet, etc.', 'As an example, a method may be implemented (e.g., wholly or in part) using a mobile device.', 'As an example, a system may include one or more mobile devices.', 'As an example, a system may be a distributed environment, for example, a so-called “cloud” environment where various devices, components, etc. interact for purposes of data storage, communications, computing, etc.', 'As an example, a device or a system may include one or more components for communication of information via one or more of the Internet (e.g., where communication occurs via one or more Internet protocols), a cellular network, a satellite network, etc.', 'As an example, a method may be implemented in a distributed environment (e.g., wholly or in part as a cloud-based service).', 'As an example, information may be input from a display (e.g., consider a touchscreen), output to a display or both.', 'As an example, information may be output to a projector, a laser device, a printer, etc. such that the information may be viewed.', 'As an example, information may be output stereographically or holographically.', 'As to a printer, consider a 2D or a 3D printer.', 'As an example, a 3D printer may include one or more substances that can be output to construct a 3D object.', 'For example, data may be provided to a 3D printer to construct a 3D representation of a subterranean formation.', 'As an example, layers may be constructed in 3D (e.g., horizons, etc.), geobodies constructed in 3D, etc.', 'As an example, holes, fractures, etc., may be constructed in 3D (e.g., as positive structures, as negative structures, etc.).', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words “means for” together with an associated function.']

['1.', 'A method, comprising:\ninputting realizations of a model of a reservoir that comprises at least one well into a computing system comprising a processor, wherein the realizations represent an uncertainty in a multidimensional space;\nwherein the processor is configured to reduce run-time overhead by: selecting a portion of the realizations in a reduced dimensional space to maintain a same amount of the uncertainty, wherein the portion of realizations is less than a number of the realizations, and wherein the same amount of the uncertainty is maintained by using multidimensional scaling of the realizations to reduce dimensionality of the realizations, generating a parameter value by performing a preliminary optimization of an objective function that is based on the portion of the realizations, running, based on the parameter value, the model to generate a field operations plan; and\nadjusting operation of one or more pieces of wellbore equipment based on the field operations plan generated from the model to maximize production of hydrocarbons from one or more reservoirs.', '2.', 'The method of claim 1 wherein the realizations of the model comprise randomly generated realizations.', '3.', 'The method of claim 1 wherein the reduced dimensional space is a metric space.', '4.', 'The method of claim 1 wherein the selecting comprises performing a sensitivity analysis on the realizations of the model.', '5.', 'The method of claim 4 wherein the multidimensional scaling is based at least in part on performing the sensitivity analysis.', '6.', 'The method of claim 1 wherein the model comprises an integrated model of a surface network model operatively coupled to a reservoir model.', '7.', 'The method of claim 1 wherein the model comprises an integrated model of a surface network model operatively coupled to a plurality of reservoir models.', '8.', 'The method of claim 1 wherein the objective function accounts for equipment condition.', '9.', 'The method of claim 8 wherein the objective function is penalized for equipment failure.', '10.', 'The method of claim 1 wherein the preliminary optimization optimizes cumulative production of hydrocarbons from the reservoir.\n\n\n\n\n\n\n11.', 'The method of claim 1 wherein the parameter value comprises at least one time dependent series of parameter values.\n\n\n\n\n\n\n12.', 'The method of claim 11 wherein the at least one time dependent series of parameter values comprises a time dependent series of well choke valve parameter values.', '13.', 'The method of claim 11 wherein the at least one time dependent series of parameter values comprises a time dependent series of gas lift parameter values.', '14.', 'The method of claim 1 further comprising:\nrendering a graphical user interface to a display, and\nlinking output from at least two modeling frameworks to generate the model.', '15.', 'The method of claim 1 further comprising:\ngenerating at least a portion of the field operations plan based on auditing the parameter value for a plurality of the realizations.', '16.', 'The method of claim 1 further comprising receiving a risk factor value and modifying the objective function based at least in part on the risk factor value.', '17.', 'The method of claim 1 wherein the adjusting operation of the one or more pieces of wellbore equipment comprises at least one of installing additional processing facilities, installing choke-adjusted wells, and shutting in of depleting wells.\n\n\n\n\n\n\n18.', 'The method of claim 1 wherein the parameter value comprises a series of parameter values for control of a choke valve of the at least one well on a monthly basis over a period time that spans a year or more, and wherein the field operations plan comprises a schedule of how to adjust the choke valve over the period of time based on the series of parameter values.\n\n\n\n\n\n\n19.', 'The method of claim 18 wherein the adjusting operation of the one or more pieces of wellbore equipment comprises adjusting a choke valve setting of one or more choke valves based on the schedule.']

['FIG. 1 illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.; FIG.', '2 illustrates a flowchart of a method, according to an embodiment.; FIG.', '3 illustrates an example of creating reservoir simulation scenarios, according to an embodiment.; FIG.', '4 illustrates each reservoir having a base case and multiple realizations, according to an embodiment.; FIG.', '5 illustrates a plot of sensitivity analysis carried out in the realizations, according to an embodiment.; FIG.', '6 illustrates a plot of survival curves that document the expected run-life failure for equipment after installation, according to an embodiment.; FIG.', '7 illustrates creating an integrated model in a software platform, according to an embodiment.;', 'FIG. 8 illustrates selecting the reduced number of realizations from smart sampling and assigning weights to them according to the desired distribution, according to an embodiment.;', 'FIG. 9 illustrates two reservoirs (m=2) and three smart realizations for each reservoir (N=3), according to an embodiment.; FIG.', "10 illustrates a table showing results of simulations per trial in optimization, with each simulation run's objective function accounted for, according to an embodiment.; FIG.", '11 illustrates a plot of an optimized objective function corresponding to a strategy, according to an embodiment.; FIG.', '12 illustrates a plot of several oil production cases, according to an embodiment.; FIG.', '13 illustrates plots of erosional velocity ratio for gas lift and boosting, according to an embodiment.; FIG.', '14 illustrates an example of a method.; FIG.', '15 illustrates examples of equipment in various geologic environments.; FIG.', '16 illustrates a schematic view of a computing system, according to an embodiment.; FIG.', '1 illustrates an example of a system 100 that includes various management components 110 to manage various aspects of a geologic environment 150 (e.g., an environment that includes a sedimentary basin, a reservoir 151, one or more faults 153-1, one or more geobodies 153-2, etc.).', 'For example, the management components 110 may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 150.', 'In turn, further information about the geologic environment 150 may become available as feedback 160 (e.g., optionally as input to one or more of the management components 110).; FIG.', '1 also shows an example of a framework 170 that includes a model simulation layer 180 along with a framework services layer 190, a framework core layer 195 and a modules layer 175.', 'The framework 170 may include the commercially available OCEAN® framework where the model simulation layer 180 is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.; FIG. 1 also shows the geologic environment 150 as optionally including equipment 157 and 158 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 159.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 157 and/or 158 may include components, a system, systems, etc., for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG.', '2 illustrates a flowchart of an example of a method 200 according to an embodiment.', 'As shown, the method 200 includes a definition block 210 for defining realizations with respect to a reservoir or reservoirs in a geologic environment as created via a modeling framework, a performance block 220 for performing a sensitivity analysis on the defined realizations as may be represented by individual models, a selection block 230 for selecting a set of representative models (e.g., realizations) based at least in part on the sensitivity analysis such that a desired amount of uncertainty is represented, an optimization block 240 for optimizing an objective function that accounts for uncertainty 244 and optionally equipment condition 248 (e.g., equipment maintenance, failure, etc.) where the objective function is based on parameter values, an output block 250 for outputting a parameter values at convergence of the optimizing of the optimization block 240, a validation block 260 for validating the parameter values with respect to the realizations to generate results, an audit block 270 for auditing the results where, if the audit is acceptable, the method 200 continues to a valid block 280 that indicates that the results are acceptably valid and where, if the audit is unacceptable, the method 200 continues to a not valid block 290 and then to the definition block 210 for generating additional realizations, which can provide for new representative models per the selection block 230 (e.g., new samples).', '; FIG.', '3 shows examples of graphical user interfaces (GUIs) 300, 310 and 320 as associated with a framework that can perform at a least a portion of the method 200 of FIG.', '2.', 'As shown in FIG.', '3, the GUI 300 includes a simulation graphic control and an uncertainty and optimization graphic control that may be selectable to cause rendering of the GUIs 310 and/or 320.', 'The GUI 310 includes various graphic controls and fields for base case definition, variables definition, uncertainty definition, etc.', 'The GUI 310 also includes a run button, a test button and a free memory graphic control that may allow for releasing memory during a simulation run (e.g., after a number of iterations, a number of runs, etc.).', 'As to the GUI 320, radio button graphic controls are shown as including cases for uncertainty, particularly uncertainty and optimization (U & O).', 'As shown, various uncertainty cases may be generated.', '; FIG.', '4 shows an example of a table 400, which may be a graphical user interface (GUI) or part of a GUI.', 'As shown, a number of realizations can be as small as two, depending upon how much uncertainty may be present in a particular reservoir under examination.', 'As an example, a method can include importing these realizations into an asset management software application, such as an integrated asset management (IAM) platform (e.g., IAM framework, marketed by Schlumberger Limited, Houston, Texas), and conducting a sensitivity analysis on the reservoir realizations.', 'For example, the performance block 220 of the method 200 can include receiving a number of realizations (e.g., two or more) and then performing one or more sensitivity analyses to generate sensitivity information.', '; FIG.', '5 shows an example plot 500 of realizations and associated two-dimensional coordinates for each of the realizations in a two-dimensional space.', 'In such a space, a method can include selecting representative uncertain reservoir realizations for carry-through into optimization (e.g., smart sampling).', 'As an example, the selection block 230 of the method 200 of FIG.', '2 can include dimensional reduction at least in part via multidimensional scaling (MDS).; FIG.', '8 shows an example of a table 800 that may be a graphical user interface (GUI) that can be utilized to link models (e.g., reservoir models, such as suitable for a reservoir simulator such as the ECLIPSE® framework simulator).', 'In such an example, a method may utilize such a table or GUI to select the reduced number of realizations from smart sampling and, for example, allow for assigning weights to the selected reduced number of realizations, for example, according to a desired distribution.', 'Such a weighting process may be manually from expert input or computed from their respective distributions (e.g., automated or semi-automated).', '; FIG.', '9 shows examples of two graphical user interfaces (GUIs) 910 and 920 for each trial of the optimization that includes running each realization where the computed objective function accounts for the corresponding weight.', 'For example, for the two reservoirs (m=2) and the three smart realizations for each reservoir (N=3), the weights can differ as can a selected number of cases.', 'As mentioned, two reservoirs may be operatively coupled to a common surface network, for example, a surface network that includes at least some common surface equipment.', 'Such a surface network may route hydrocarbons from wells to a common handling facility.', 'As an example, where fluid is injected (e.g., liquid and/or gas) into a well and/or a formation, a surface network may route such fluid (or fluids) from one region to another (e.g., for gas lift, etc.).', '; FIG.', '12 shows an example plot 1200 of curves labeled as corresponding to optimistic and pessimistic cases, as may be extracted, P10, P50 and P90 cases or others degrees of confidence, etc.', 'As shown, such curves can depend, for example, upon one or more selected strategies.', 'For example, the plot 1200 shows curves for a boosting strategy (B) and curves for a gas lifting strategy (GL).', '; FIG.', '14 shows an example of a method 1400 that includes a reception block 1410 for receiving realizations for a model of a reservoir that includes at least one well; a selection block 1420 for selecting a portion of the realizations to preserve an amount of uncertainty; an optimization block 1430 for optimizing an objective function; an output block 1440 for outputting parameter values for the optimized objective function; and a generation block 1450 for generating at least a portion of a field operations plan based at least in part on the parameter values.; FIG.', '15 shows an example of a geologic environment 1510 that includes reservoirs 1511-1 and 1511-2, which may be faulted by faults 1512-1 and 1512-2. FIG.', '15 also shows some examples of offshore equipment 1514 for oil and gas operations related to the reservoirs 1511-1 and 1511-2 and onshore equipment 1516 for oil and gas operations related to the reservoir 1511-1.; FIG.', '15 also shows an example of a relatively small production system network 1580 (e.g., optionally a portion of a larger network 1570).', 'As shown, the network 1580 forms somewhat of a tree like structure where flowlines represent branches (e.g., segments) and junctions represent nodes.', 'As shown in FIG.', '15, the network 1580 provides for transportation of oil and gas fluids from well locations along flowlines interconnected at junctions with final delivery at a central processing facility.']

US11919754

Automated spooling control system using stochastic inference

Feb 12, 2021

Muhannad Abuhaikal, Tianxiang Su, Chris Bogath

SCHLUMBERGER TECHNOLOGY CORPORATION

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['A system and method that is configured to automatically control a spooling of a drum of a deployment unit used in hydrocarbon recovery operations.', 'The method may comprise obtaining data related to a sensor and measurements system connected to the deployment unit.', 'Processing the data obtained by the sensor and measurements system in a processing unit that makes a stochastic inference.', 'Controlling an auto spooling of the drum of the deployment unit through an auto-spooling controller connected to the deployment unit based upon the stochastic inference.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThe present application claims priority to U.S. Provisional Application 63/111,909, entitled: “AUTOMATED SPOOLING”, and filed on Nov. 10, 2020, the entirety of which is incorporated by reference.', 'FIELD OF THE DISCLOSURE\n \nAspects of the disclosure relate to wireline, coiled tubing, and slickline operations for hydrocarbon recovery operations.', 'More specifically, aspects of the disclosure relate to automated spooling mechanisms and methods for use in hydrocarbon recovery operations.', 'BACKGROUND\n \nWireline, coiled tubing, and slickline operations are used to perform different functions in a wellbore.', 'Hydrocarbon recovery operations are expensive to perform, therefore, there is a push by the industry to cut costs related to such operations.', 'Performing activities in the oil field in a cost-effective manner, however, can result in a rushed operation in a bid to result in well economic viability.', 'With wireline, coiled tubing, and slickline operations, such rushed operations can lead to wireline, coiled tubing, or slickline entanglement, dropped loads and other problems.', 'It is desired, therefore, to minimize the possible problems presented above while performing the highly needed activities.', 'As time has progressed automation has become more commonplace in specific industries.', 'The purpose of automation is to reduce the number of workers performing a work task, improve the quality of the service, and accelerate delivery.', 'Minimizing the number of workers can lead to increased savings for operations.', 'To date, however, automation in the oil field is not as prevalent as in other industries.', 'There is a need to provide automated apparatus and methods that are easier to operate than conventional apparatus and methods.', 'There is a further need to provide apparatus and methods that do not have the drawbacks of increased costs and potentially fouled wireline operations.', 'SUMMARY\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized below, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted that the drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments without specific recitation.', 'Accordingly, the following summary provides just a few aspects of the description and should not be used to limit the described embodiments to a single concept.', 'In one non-limiting example embodiment, a system for automated spooling of a deployment unit is disclosed.', 'The system may comprise a sensor and measurement system configured to measure a drum position, an elongated member length, a spooling pressure and a tension in the elongated member deployed by a system, such as a wireline unit, a coiled tubing unit, a slickline unit, or other unit for deploying an elongated member.', 'The elongated member can be coiled tubing, slickline, wireline, or the like.', 'The system may also comprise a data driven system identification system configured to accept and process data related to winch parameters, spooling guide parameters, truck parameters and site parameters.', 'The system may further comprise a spooling arm interface or a linear carriage system configured to receive and process measurements from the sensor and measurement system.', 'The system may further comprise a stochastic inference system configured to receive the processed measurements to calculate an elongated member position, a layer direction, a fleet angle and a radius.', 'The system may also comprise an auto-spooling controller connected to the deployment unit and the data driven system identification system, where the auto-spooling controller is configured to interface with the stochastic inference system and control the deployment unit and the auto-spooling controller is configured to control actions of the deployment unit based upon a processing of data from the sensor and measurement system, the stochastic inference system, the spooling arm interface or the linear carriage system and the data driven system identification system.', 'In another example embodiment, a method to control a spooling of a drum of a deployment unit is disclosed.', 'The method may comprise obtaining data related to a sensor and measurements system connected to the deployment unit.', 'The deployment unit can be a wireline unit, a coiled tubing unit, a slickline unit, or the like.', 'The method may further comprise processing the data obtained by the sensor and measurements system in a processing unit that makes a stochastic inference.', 'The method may also comprise controlling an auto spooling of the drum of the deployment unit through an auto-spooling controller connected to the deployment unit based upon the stochastic inference.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.', 'It should also be noted that when the term “cable” is used in the figures that any elongated member can be used such as a cable, a wireline, a slickline, or a coiled tubing.', 'It should also be noted that when the terms “arm angle controller”, “arm controller”, and spooling arm” are used in the figures that these terms refer to illustrative elongated member guides.', 'FIG.', '1\n is a picture of a conventional deployment unit that carries a measuring head and systems to control the fleet angle.\n \nFIG.', '2\n is a side view of a spooling arm arrangement.\n \nFIG.', '3\n is an overview of a spooling automation system.', 'FIGS.', '4\nA, \n4\nB and \n4\nC\n are a series of pictographic definitions of zero, lagging and leading fleet angles proceeding from left to right.\n \nFIG.', '5\n is a view of main parameters and coordinate system of the spooling arm.\n \nFIG.', '6\n is a side view of spooling arm hydraulics used in one example embodiment of the disclosure.\n \nFIG.', '7\n is a general block diagram of an adaptive cascade controller that can be used in controlling operation of the systems for auto spooling.\n \nFIG.', '8\n is a diagrammatic view of an arm controller used in controlling operation of the systems for auto spooling.\n \nFIG.', '9\n is a diagrammatic layout of a winch system showing a spooling arm, drum, and elongated member.', 'FIGS.', '10\nA and \n10\nb \nare a series of pictographic examples of layer direction.', 'FIGS.', '11\nA, \n11\nB and \n11\nC\n are a series of pictographic examples of effective fleet angle for a neutral position, a lagging fleet angle, and a leading fleet angle.', 'FIGS.', '12\nA through \n12\nE\n are a series of pictographic examples of a successful mode while spooling and failure modes while spooling.\n \nFIG.', '13\n is an ideal uncontrolled fleet angle profile.\n \nFIG.', '14\n is an example of an asymmetric fleet angle profile.', 'FIG.', '15\n is a flow chart for a fusion framework for updating flange position.\n \nFIG.', '16\n is a set of example results for prior positions, after a first measurement position and after 100 measurement positions.\n \nFIG.', '17\n is a side view of a position point making an angle λ with the vertical.\n \nFIG.', '18\n is an estimate of theta angle and Gaussian CDF values for a typical gap failure.', 'To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures (“FIGS”).', 'It is contemplated that elements disclosed in one embodiment may be beneficially utilized on other embodiments without specific recitation.', 'DETAILED DESCRIPTION', 'In the following, reference is made to embodiments of the disclosure.', 'It should be understood, however, that the disclosure is not limited to specific described embodiments.', 'Instead, any combination of the following features and elements, whether related to different embodiments or not, is contemplated to implement and practice the disclosure.', 'Furthermore, although embodiments of the disclosure may achieve advantages over other possible solutions and/or over the prior art, whether or not a particular advantage is achieved by a given embodiment is not limiting of the disclosure.', 'Thus, the following aspects, features, embodiments and advantages are merely illustrative and are not considered elements or limitations of the claims except where explicitly recited in a claim.', 'Likewise, reference to “the disclosure” shall not be construed as a generalization of inventive subject matter disclosed herein and should not be considered to be an element or limitation of the claims except where explicitly recited in a claim.', 'Although the terms first, second, third, etc., may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms.', 'These terms may be only used to distinguish one element, components, region, layer or section from another region, layer or section.', 'Terms such as “first”, “second” and other numerical terms, when used herein, do not imply a sequence or order unless clearly indicated by the context.', 'Thus, a first element, component, region, layer or section discussed herein could be termed a second element, component, region, layer or section without departing from the teachings of the example embodiments.', 'When an element or layer is referred to as being “on,” “engaged to,” “connected to,” or “coupled to” another element or layer, it may be directly on, engaged, connected, coupled to the other element or layer, or interleaving elements or layers may be present.', 'In contrast, when an element is referred to as being “directly on,” “directly engaged to,” “directly connected to,” or “directly coupled to” another element or layer, there may be no interleaving elements or layers present.', 'Other words used to describe the relationship between elements should be interpreted in a like fashion.', 'As used herein, the term “and/or” includes any and all combinations of one or more of the associated listed terms.', 'Some embodiments will now be described with reference to the figures.', 'Like elements in the various figures will be referenced with like numbers for consistency.', 'In the following description, numerous details are set forth to provide an understanding of various embodiments and/or features.', 'It will be understood, however, by those skilled in the art, that some embodiments may be practiced without many of these details, and that numerous variations or modifications from the described embodiments are possible.', 'As used herein, the terms “above” and “below”, “up” and “down”, “upper” and “lower”, “upwardly” and “downwardly”, and other like terms indicating relative positions above or below a given point are used in this description to more clearly describe certain embodiments.', 'To enable remote operations and automation of spooling operations to deploy/retrieve elongated members, such as mining operations, wellbore service operations, hoisting operations, ship mooring operations, or the like.', 'For example, the disclosed methods and systems can be utilized with wellbore service jobs, wherein systems are designed to convey elongated members and sometimes tools connected therewith, such as wireline tools, coiled tubing tools, fishing tools, or the like, and retract them on the spool automatically without operator interaction.', 'The process is known as “auto spooling”.', 'The main objective of auto-spooling, in its simplest form, is to maintain the fleet angle within a specific variable range throughout the spooling process.', 'Due to challenges in obtaining a reliable direct measurement of the fleet angle, the fleet angle is estimated based on a several other measurements.', 'The arm angle is also controlled (which is much easier to measure reliably) to obtain the desired fleet angle.', 'This controller then works in tandem with an anomaly detection and classification system to create a fully autonomous spooling system.', 'The anomaly prediction and detection are achieved through a combination of failure prediction with time series data from traditional sensors and failure detection using computer vision with deep neural networks.', 'In addition to anomaly detection, the computer vision system also provides redundant measurements of critical variables necessary for the auto-spooling controller such as elongated member position and fleet angle.', 'The robustness of the auto-spooling controller relies heavily on reliable estimation of the state of the system and for this purpose, a probabilistic framework is devised for the spool state estimation.', 'This framework relies on timeseries data collected from several existing sensors including the drum rotation and the tool depth in addition to the new measurement of the arm angle and a monocular camera for computer vision.', 'The framework includes several inference algorithms that estimate all relevant variables such as elongated member position, layer direction, spool radius, flange position, etc.', 'These variables and parameters are then fused probabilistically using Bayesian estimation theory in a Layer Chart (L-Chart) that keeps a log of all relevant layer properties and is used to estimate several spool parameters.', 'The L-Chart is built to fuse and update measurements from various sources or measurements such as timeseries data, computer vision, or direct measurements to create a data-driven estimation of the state of the spool and eliminate manual initialization of the spooling controller.', 'A wellbore job can include conveying a tool string downhole and retrieving it using an electric cable, a slickline, a coiled tubing, or the like to acquire subsurface petrophysical and/or geophysical data and the delivery of well construction services.', 'A deployment unit, e.g., a winch, can be used to convey the tool string downhole by unspooling and spooling the elongated member on a drum while controlling the fleet angle (the angle at which the elongated member enters the drum during spooling) using an elongated member guide, such as a spooling arm or linear carriage.', 'The spooling arm is a legacy spooling guide design used with deployment units that dates back to about a hundred years ago and it was initially used to carry the measuring head (IDW and CMTD) and roughly control the fleet angle to create a smooth spool as shown in \nFIG \n1\n.', 'Another advantage of such design on modern units is that it allows unspooling without resistance when in neutral mode.', 'Traditionally, a deployment unit is aligned with the wellhead manually at an optimal distance to facilitate the spooling process and reduce the involvement of the operator with the spooling process.', 'This optimal configuration is not always guaranteed or possible and the operator will intervene to compensate.', 'The spooling arm on deployment units rotates around two axes, the vertical rotation around the axle and the rotation around the arm pivot as shown in \nFIG.', '2\n.', 'The axle can be rotated via a pneumatic piston and the spooling arm can be rotated around the pivot with two hydraulic pistons as shown in \nFIG \n2\n.', 'During the spooling process, the arm is subjected to an external torque resulting from the tension in the elongated member and an internal torque applied by the pressure in the pistons.', 'To control the arm, an encoder can be added to the arm pivot that measures the arm angle and is used for feedback control.', 'The auto-spooling controller, which controls the fleet angle during the spooling process, controls the arm position directly by applying the necessary pressure to the pistons.', 'Referring to \nFIG.', '3\n, an overview of the spooling automation system \n300\n is illustrated.', 'A data driven system identification system \n302\n is provided to monitor several parameters.', 'These parameters may be winch parameters, spooling guide parameters, truck parameters, and site parameters.', 'Data from the data driven system identification system \n302\n may be fed to an auto-spooling controller \n308\n.', 'An anomaly detection and health monitoring system \n304\n is provided to detect both errors that may occur within the system \n300\n and overall health monitoring functions for the system \n300\n.', 'To aid in the performance of these aspects, a computer vision system may be used.', 'Such computer vision system may be a monitoring camera system.', 'The camera system may use reference points identified with the deployment unit to provide a constant reference point, in some embodiments.', 'A Bayesian inference system may also be included in the health monitoring system \n304\n.', 'The Bayesian inference system may help in determining statistical probabilities of certain occurrences happening.', 'In this way, a specific course of action may be chosen by the system \n300\n to minimize anomalous actions.', 'As illustrated, the auto-spooling controller \n308\n may feed data to the anomaly detection and health monitoring system \n304\n.', 'The anomaly detection and health monitoring system \n304\n may provide for actionable insights and failure or preventative correction analysis that is fed to an orchestration system \n306\n that controls functions of the deployment unit, such as the winch, drum and various arms.', 'A sensor and measurement system \n312\n may also obtain and process data from sensors placed on various mechanical components.', 'These may include measurements of drum position, elongated member length, spooling pressure, tension in elongated member, arm angle, axle angle as well as a separate computer vision tracking system.', 'Data from the sensor and measurement system \n312\n may be provided to a spooling guide interface \n310\n.', 'A stochastic inference \n311\n is also provided to evaluate elongated member position, layer direction, fleet angle and radius as non-limiting embodiments.', 'The objective of the spooling controller \n308\n is to automatically spool the elongated member on the drum in a prefect orthocyclic spool to prevent damage to the elongated member and improve its service life.', 'Since it is not physically possible to directly control the state of the spool, instead the fleet angle is controlled.', 'In embodiments, different aspects of the system are monitored such as the state of the spool.', 'The state of the spool can be monitored for anomaly prediction and detection.', 'The fleet angle is the angle at which the elongated member enters the drum as shown in \nFIGS.', '4\nA, \n4\nB, \n4\nC\n, and it is the most critical variable to control during the spooling process.', 'The general solution of spooling automation consists of the required measurements and their interfaces, real-time state estimation, data-driven system identification, anomaly prediction and detection, and the auto-spooling controller in addition to a higher-level orchestration for failure correction.', 'Different measurements may be used including, for example, measurements on drum position, elongated member length measurement, spooling pressure, and the tension in the elongated member may be performed.', 'Since it was not possible to build an automated spooling controller with the existing measurements, a sensor has been added at the pivot of the spooling arm to measure the arm angle and an additional sensor to measure the axle angle and improve the fleet angle estimation.', 'In embodiments, a monocular camera is added for anomaly detection and to provide a redundant set of estimations for elongated member position, fleet angle, and drum speed.', 'If a linear carriage is used, information from the linear carriage system, computer vision, and/or sensors in communication with the linear carriage system can be used to provide position information of the elongated member guide to allow for calculation of the fleet angle estimation.', 'For state estimation, a set of inference algorithms are established to estimate the states required for the controller such as the elongated member position, layer direction and spool radius to build a digital spool.', 'These algorithms include a novel flange detection algorithm designed to detect and localize a flange crossing based on existing measurements such as the drum rotation, elongated member length measurement, and the arm angle or elongated member guide angle.', 'The inference algorithms also include data fusion and construction of the digital spool (the L-Chart) which is then used to estimate elongated member position, spool radius, and layer direction.', 'The L-Chart is also used to store information about the spooling process such as tension history, layer numbers, layer thicknesses and many other properties as function of drum rotation.', 'For anomaly prediction and detection, as provided in \nFIG.', '3\n, \n304\n, a combination of time-series data analysis and inference are used with a redundant computer vision system for detection.', 'The anomaly prediction is achieved by estimating the fleet angle in real time and quantifying its uncertainty.', 'The known properties of the system are also used and the bounds on failure angles (leading and lagging) are determined.', 'These properties are combined with the rotation of the drum to estimate the probability of failure in real time.', 'A data-driven system identification \n302\n is used to improve the performance of the spooling controller \n308\n by inferring certain parameters and quantities such as wellhead position and spooling guide parameters.', 'The spooling guide can be a spooling arm or an elongated member guide used with a linear carriage deployment system.', 'The spooling guide parameters can include spooling arm parameters such as length, width, or other relevant information related to the spooling arm or parameters of an elongated member guide used with a linear carriage can include linear position, guide height, guide speed, or the like.', 'One skilled in the art with the aid of this disclosure would know the parameters to measure with regards to the deployment system used.', 'Finally, the auto-spooling controller \n308\n can be developed to control the fleet angle in real time by consuming the state estimations and the parameter estimation and controlling the fleet angle indirectly by controlling the arm angle.', 'In some embodiments, the system can be designed to not only automate spooling, but to also track the state of the system and provide information about the spooling system \n300\n that can be used for predictive maintenance and health monitoring.', 'The spooling system can be now known or future known systems, such as spooling systems using a spooling arm, spooling systems using a synchronized linear carriage, or the like.', 'Auto-Spooling Controller\n \nThe spooling controller \n308\n can be used to maintain the fleet angle within a specific range during the spooling process to minimize the probability of a spooling anomaly occurrence.', 'This can be achieved by controlling the position of an elongated member guide such as spooling arm angle or the position of a linear carriage (e.g. fairlead, measure head . . . ).', 'The optimal fleet angle profile is discussed in detail below where the fleet angle setpoint is determined based on the estimate of the elongated member position and the layer direction in real time.', 'For spooling guide that uses the spooling arm design, measuring and controlling the fleet angle θ directly is not trivial even with the use of monocular or stereoscopic computer vision.', 'Instead, the auto-spooling controller is a closed-loop feedback controller that measures and controls the spooling arm angle γ (see \nFIG.', '5\n).', 'The arm angle setpoint (reference) at each time step is calculated based on the desired fleet angle, the layer direction, and the current elongated member position on the drum.', 'Once the desired fleet angle setpoint is determined, the current elongated member position and layer direction may be used in conjunction with the geometry and layout of the spooling system to determine the arm angle setpoint.', 'This approach led to the development of three main controller blocks: a spool state observer, a fleet angle profile, and a setpoint calculation, and the fleet angle controller that determines the arm angle setpoint as shown in the general block diagram of the controller in \nFIG \n7\n.', 'The secondary controllers “torque controller” and “pressure controller” can be linearization functions derived from the arm characterization and calibration procedures or from the geometry of the arm.', 'For the spooling guide that uses the spooling arm design, the arm angle can be controlled by applying pressure to the hydraulic pistons shown in \nFIGS.', '5\n and \n6\n.', 'The arm command (shown as CMD\nsp \nin \nFIG.', '7\n.)', 'ranges between −1.00 to +1.00, where the magnitude corresponds to the proportional voltage applied to the proportional valve to control the pressure in the system and the sign of the command determines the direction of pressure application to move the arm to the right or the left.', 'As illustrated in \nFIG.', '7\n, a series of controllers may be used to provide commands for spooling guide \n200\n actuation.', 'As shown, if the spooling guide is a spooling arm, an arm angle controller \n700\n can be provided to control spooling arm \n200\n actuation.', 'Data from the arm angle controller \n700\n may be fed to a torque controller \n702\n and a pressure controller \n704\n.', 'Additional controllers include a fleet angle controller \n706\n.', 'To monitor and ensure positioning of components are correct, an elongated member position layer direction and spool radius observer \n708\n is provided.', 'Additionally, a fleet angle profile \n710\n is provided.', 'An arm characterization and calibration system \n712\n and spool state estimator \n714\n are also provided to accept and process data.', 'The spool state estimator \n714\n may be configured with an L chart.', 'Additionally, a model parameters estimation system \n716\n is provided to accept data measurements, such as arm angle, axle angle, spooling pressure, elongated member tension, drum position and depth and process this data to arrive at an estimation for a premade computer model of the system.', 'Once the fleet angle setpoint is determined, the corresponding arm angle is calculated based on the geometry and is then combined with the backlash to calculate the desired arm angle setpoint.', 'The arm angle controller then compensates for the residual arm angle error using different methods including a PID controller \n804\n, a feedforward friction observer (FFFO) \n800\n, pulse width modulation (PWM) \n802\n, and an active disturbance rejection (ADR) \n806\n (see \nFIG. \n8\n.).', 'Due to changes in the PID gains based on the elongated member tension and arm angle, the gains are estimated based on the inferred system state that takes into account the predicted behavior of the system and the inferred parameters.', 'FFFO \n800\n is used to compensate for the friction in the system including friction in the pistons and the arm pivot.', 'The PWM \n802\n is designed to take into account the minimum pressure in the system and the corresponding minimum torque.', 'Finally, the ADR \n806\n is designed to further improve the performance of the controller by predicting the required torque based on the state of the system and the inferred system parameters.', 'The secondary controllers (torque \n702\n and pressure \n704\n controllers) are designed to compensate for the non-linearities in the system and can be open loop controllers based on the system identification or can be closed loop controllers if the proper bandwidth is available.', 'Optimal Fleet Angle Profile\n \nThe fleet angle is defined as the angle between the elongated member and the axis normal to the axis of rotation of the drum shown as θ in \nFIG.', '9\n and \nFIGS.', '4\nA-\n4\nC\n.', 'The fleet angle is known to directly influence the spooling quality and must be maintained within a specific range.', 'This range is usually achieved by aligning the winch with the sheave wheel and by maintaining an optimal distance to prevent miss spooling.', 'In case good alignment and optimal distance cannot be achieved, the elongated member guide is used to compensate for the fleet angle.', 'In an embodiment when the spooling guide is a spooling arm, the spooling arm is controlled through pressure in the hydraulic piston at the pivot of the arm, and the fleet angle is achieved through force balance at the end of the spooling arm.', 'If an elongated member guide associated with a linear carriage is used, then a elongated member guide mounted on the linear carriage can be used to control the fleet angle.', 'In an embodiment, if a linear carriage deployment system is used system controls the fleet angle by moving an elongated member guide or “cable” guide on a linear actuator powered by a power screw, a trapezoidal screw, a timing belt, a chained connection, or a reversible screw.', 'The relative position of the elongated member guide with respect to the elongated member position on the drum determines the fleet angle.', 'The elongated member guide position can be controlled based on the estimated elongated member position on the drum and the desired fleet angle setpoint.', 'The position of the elongated member can also be estimated and controlled using computer vision.', 'The second quantity necessary to develop an optimal fleet angle profile is the layer direction σ.', 'The layer direction is defined as the relative position of the new wrap with respect to the previous wrap during the spooling process (not unspooling) and it is defined as positive when the spooling progression is in the +y direction and negative if spooling is in −y direction as shown in \nFIGS.', '10\nA and \n10\nB\n.', 'σ\n \n=\n \n \n{\n \n \n \n \n \n+\n \n1\n \n \n \n \n \nwhen\n \n\u2062\n \n \n \n \n\u2062\n \nspooling\n \n\u2062\n \n \n \n \n\u2062\n \nfrom\n \n\u2062\n \n \n \n \n\u2062\n \nright\n \n\u2062\n \n \n \n \n\u2062\n \nto\n \n\u2062\n \n \n \n \n\u2062\n \nleft\n \n\u2062\n \n \n \n \n\u2062\n \n \n(\n \n \n+\n \ny\n \n \n)\n \n \n \n \n \n \n \n \n-\n \n1\n \n \n \n \n \nwhen\n \n\u2062\n \n \n \n \n\u2062\n \nspooling\n \n\u2062\n \n \n \n \n\u2062\n \nfrom\n \n\u2062\n \n \n \n \n\u2062\n \nleft\n \n\u2062\n \n \n \n \n\u2062\n \nto\n \n\u2062\n \n \n \n \n\u2062\n \nright\n \n\u2062\n \n \n \n \n\u2062\n \n \n(\n \n \n-\n \ny\n \n \n)\n \n \n \n \n \n \n \n \n \n \n \n(\n \n1\n \n)', 'The effective fleet angle (θ\ne\n) is defined as the product of the fleet angle and the spooling direction: \n θ\ne\n=σ*θ\u2003\u2003(2)', 'The effective fleet angle θ\ne \nis negative when the elongated member guide (end of spooling arm/caster/fairlead) is lagging the current wrap, and it is positive when the elongated member guide is leading the current wrap as shown in \nFIG.', '4\nB\n and FIG, \n4\nC respectively.', 'Referring to \nFIG.', '11\nA\n, a zero effective fleet angle is illustrated.', 'Referring to \nFIG.', '11\nB\n, a lagging fleet angle is illustrated.', 'Referring to \nFIG.', '11\nC\n, a leading fleet angle is illustrated.', 'The range of the acceptable effective fleet angle is defined as θ\ne\n∈(α, b), where α is the limit on the lagging fleet angle (reverse-climbing limit) and b is the limit on the leading angle (gap limit), then |α|>b due to forces on the elongated member.', 'Although the range is larger on the lagging angle, the elongated member must maintain a lagging angle (with a gap limit b) on the current layer at the flange to prevent pileup in the first wrap of next layer.', 'If a lagging angle is maintained at the end of the current layer at the flange, it will form a leading angle at the beginning of the next layer.', 'This property of the system suggests that the ideal fleet angle is not constant, but varies from a leading angle at the beginning of the layer for the first wrap to a lagging angle at the end of the layer.', 'In case the effective fleet angle away from the flange is too large θ\ne\n b, a gap can form as shown in \nFIG. \n12\nC\n, and if the elongated member is too close to the flange at the beginning of the layer, it can cause the elongated member to pile up at the flange as shown in \nFIG. \n12\nD\n, and if θ\ne\n>b when starting a new layer, this can lead to a runaway failure as shown in \nFIG.', '12\nE\n.', 'There are two less common modes of failure, the first is the knife-through which results from the increased spooling tension in higher layers, and the second is the micro-gaps which can happen as a result of migrating cross-over zone over time.', 'Bounds on the fleet angle can be determined by means of finite element simulations of spooling or by carefully collecting experimental data of spooling failures.', 'In general, these bounds are function of elongated member diameter, friction between the elongated member and the spool, spool radius, spooling speed, tension in the elongated member, whether a flat or grooved drum is used for spooling, and flexural stiffness of the elongated member.', 'The fleet angle profile is a relationship between the desired fleet angle and the elongated member position and layer direction while taking into consideration the proximity of the elongated member to the flange.', 'An optimal fleet angle profile is the profile that takes into consideration the robustness and reliability of the auto-spooling controller while minimizing the probability of failure and reduce scrubbing (abrasion) between the elongated member and the spool, if possible.', 'As detailed previously, there are four modes of failure that are directly related to the fleet angle that must be considered when designing a fleet angle profile.', 'In general, and based on these modes of failure, the effective fleet angle away from the flange must be maintained between the bounds a and b, θ\ne \n∈(a, b) and must be maintained between 0 and b, θ\ne \n∈(0, b) at the beginning of the layer in the proximity of the flange.', 'For larger elongated member diameters and in the absence of the spooling guide, it is possible to create a smooth spool by aligning the winch with the well head and placing it at an optimal distance.', 'This would create a linear fleet angle profile that is particularly suitable for shorter length scales (see \nFIG. \n13\n).', 'When ideal winch positioning is not possible or dealing with larger length scales and smaller elongated member diameters (such as wireline cable) a fleet angle compensation will be necessary to obtain the smooth spool.', 'There are several possible profiles that allow good spooling.', 'One profile is the linear profile mentioned previously, but also a zero-fleet angle profile can perform the same job but might need a kicker plate at the flange of the drum to prevent pile up at the flange.', 'Ideally, the most flexible profile can be parametrized to minimize the probability of failure while reducing scrubbing in the elongated member.', 'The optimal fleet angle must fall in the middle between the lagging bound and the leading bound to minimize the probability of failure.', 'Since the magnitude of the lagging angle bound is larger than that of the leading angle bound, the optimal fleet angle designed to minimize the probability of failure is always a lagging angle.', 'However, lagging angle cannot be maintained across the entire width of the drum due to failure modes at the flange (pileup and runaway).', 'FIG.', '14\n shows an optimal fleet angle profile with the following parameters: x represents the uncertainty in elongated member position estimation.', 'a is the lagging bound of the fleet angle.', 'b is the leading bound of the fleet angle.', 'And s is the slope of the linear segments and is chosen to create a smooth transition between the leading and lagging angle during the spooling process while taking into account the maximum speed at which the spooling controller can move the arm.', 'Flange Detection and Elongated Member Position Estimation', 'In one embodiment, for an automated spooling controller, the elongated member position, layer direction, and the spool radius are estimated in real time.', 'The elongated member position and layer direction can be estimated directly using a computer vision system or a direct measurement of the elongated member position.', 'Another possible method to obtain the elongated member position can be based on the rotation of the drum and flange-crossing detection.', 'To estimate the elongated member position, layer direction, and build the digital spool, a flange detection is required to determine when the elongated member climbs or descends from one layer to the next.', 'The flange detection can be achieved by different types of sensors such as mechanical switches or optical or proximity sensors.', 'In one example embodiment, a flange detection algorithm is built based on the change in spool radius as function of elongated member length measurement and drum rotation.', 'There are several possible methods that can be used for flange detection such as change point or dynamic Bayesian networks.', 'In one embodiment, a method is provided that performs a detection of flange crossing by comparing a linear regression of a data batch with a piecewise linear regression of the same batch and compare the residual error to determine the presence of a flange and detect the position of the flange at the same time.', 'In this method, the residual error from a linear regression is calculated and compared to the residual error of piecewise linear least squares fitting.', 'A linear regression of the data batch is considered followed by an investigation of the residual error in presence and absence of a flange crossing in the data batch.', 'In absence of a flange crossing from the data batch, the sources of error in a linear fit include random noise from the measurement of the drum position and the elongated member length and the number of data points in the data batch.', 'In the presence of a flange in the data batch, the residual error includes the layer thickness, number of wraps, number of data points in the batch, and measurement noise.', 'In some embodiments, the accuracy of the algorithm can be further improved by using arm angle measurement and other predicted values such as the layer thickness.', 'Digital Spool and the L-Chart\n \nTo harness the power of spooling data for automation and health monitoring, a digital spool was built.', 'The digital spool is a stochastic representation of the spool built by fusing data from all the available sensors with an initial model of the spool based on the dimensions of the drum and the elongated member.', 'The initial model is then updated continuously to reflect the real spool every time a spooling or unspooling process is performed.', 'The spool model breaks the spool into layers where each layer is mainly defined by a starting and ending drum position (flange position).', 'Each layer also includes information about that layer such as the layer thickness, number of wraps per layer, estimated pitch, elongated member length, elongated member diameter, tension profile of the layer, spool radius, number of layers and many other properties suited for automation and health monitoring.', 'Since the digital spool is built on the base of layers, it is referred to as the Layer Chart or shortly L-Chart.', 'The initial spool can be constructed beforehand or after the first flange detection or an elongated member position measurement or using manual input by the operator.', 'Once the initial spool model is constructed, it is updated with each flange detection or elongated member position measurement with the corresponding variance using the Bayesian estimation theory.', 'Whenever a flange is detected, the segmental linear regression algorithm discussed previously outputs the inferred flange position.', 'These individual inferences are defined as the “measured flange positions” to distinguish them from the “believed flange positions” which are obtained by fusing the individual inferences.', 'There are three challenges for the fusion: \n \n \n \n1.', 'For every single flange, there could be multiple detections of the measured flange position, wherein each contains noise depending on the quality of the drum encoder.', 'Also, detections for different flanges are not independent: The positions of two neighboring flanges give information on all other flanges, as they are evenly spaced in an ideal spooling.\n \n2.', 'The measured flange positions may contain false positives.', 'For example, when an anomaly occurs where the elongated member climbs on top of itself in the middle of the drum, the segmental linear fit algorithm will falsely infer that the elongated member has touched a flange to change a layer, and therefore outputs a false flange position.', '3.', 'The drum rotation encoder occasionally outputs step drifts.', 'For example, a linear increase drum angle time signal could contain a step increase in the middle.', 'This leads to inconsistency between the flange positions detected before and after the drifts.', 'To address challenge \n1\n, Bayesian inference is used to fuse the measured flange positions.', 'Believed flange positions were tracked in terms of Gaussian distributions.', 'Whenever a measured flange position arrives, the believes are updated by combining the prior (the distributions before the measurement arrives) and the likelihood (given a set of guessed flange positions, how likely we will receive such a measurement).', 'To address challenge \n2\n, a hypothesis Z test was performed for each measured flange position before fusing them into the current believes.', 'A measurement that fails the Z test, i.e., one that is incompatible with the current believes, will be used to initialize a copy of the secondary believes, to be discussed in more details next.', 'To address challenge \n3\n, two copies (primary and secondary) are kept of the flange position believes.', 'After an encoder drift, subsequent new measurements will disagree with the primary believes formed by earlier detections.', 'Instead of filtering them out directly, they are stored in the secondary believes.', 'Over time, if the secondary believes become more popular, it will overthrow the primary one.', 'For the infrequent false positive detections, however, the secondary believes will never become popular as they are just outliers.', 'FIG.', '15\n shows a flow chart of the fusion framework. \nFIG.', '16\n shows example results, where the top, middle and bottom panels show the distributions of the believed flange positions before receiving any measured flange position, after receiving \n1\n, and \n100\n measured flange positions respectively.', 'On each row of the figure, the left figure shows the believes of all the \n120\n flanges while the right figure shows a zoom in version of the first few distributions.', 'As expected, the system becomes more confident on the flange positions upon receiving measurements as the distribution variances shrink.', 'Fleet Angle Estimation and Failure Prediction\n \nMethods and Algorithms to Estimate the Fleet Angle and Quantify Uncertainty in Real Time\n \nTo predict spooling failure from timeseries data, the fleet angle is estimated and compared to the known failure bounds associated with all failure modes.', 'To determine the probability of the fleet angle being out of bounds, the estimated fleet angle distributions are convoluted with the likelihood of a failure mode given the current fleet angle estimation.', 'The fleet angle out of bounds probability is calculated for each possible failure mode.', 'Although the fleet angle being out of bounds is the direct cause of failure, it is not possible to cause a failure unless the elongated member is being spooled on the drum, or in other words, the drum is rotating.', 'Hence the failure prediction is basically the probability of failure given a fleet angle estimation, failure bounds for each failure mode, and the drum rotation.', 'Fleet angle estimation is based on the arm angle, the axle angle, the current radius of the spool, the elongated member position, the arm length, and the position of the center of the drum with respect to the pivot of the arm.', 'In order to estimate the fleet angle, the geometric relation between the variables mentioned above is established.', 'Along with the fleet angle estimate, it is also important to quantify the uncertainty in this estimate as a function of uncertainties of the input.', 'In summary, the fleet angle estimate, which is a distribution with a mean and variance, is estimated using the input mean and variances of the quantities that it depends on.', 'The uncertainties in the argument variables are then propagated to understand the uncertainty in the fleet angle estimate.', 'Several methods were investigated for this purpose such as particle filters, Monte Carlo method, derivative methods, and an unscented Kalman filter (UKF).', 'The UKF proved to be the best compromise between speed and accuracy.', 'A likelihood function of Gaussian CDF is assumed for the probability of failure (out of bounds) given a fleet angle as shown in \nFIG.', '18\n below.', 'For example, say the gap anomaly occurs at a fleet angle of 3.15°±0.5°.', 'Hence, the probability of the fleet angle being out of bounds for a given anomaly type is calculated by convolution of the fleet angle distribution and the likelihood function.', 'Data Driven System Identification\n \nData-driven system identification is employed to improve the performance of the controller by inferring some of the critical parameters and variables such as the wellhead position, friction torque, arm backlash, relationship between pressure and torque, etc.', 'The estimation of the well head position is discussed herein which can improve the performance of the controller by improving the active disturbance rejection.', 'Wellhead position estimation also plays a critical role to assess the positioning of the deployment unit with respect to the wellhead and to determine the ability to spool under high tension.', 'Several methods were investigated for wellhead position estimation including neutral unspooling data analysis, swing test, and real time estimation for controlled spooling.', 'The neutral unspooling approach relies on movement of the spooling arm during uncontrolled unspooling (RIH) due to tension in the elongated member.', 'The spooling arm will follow the elongated member movement across the drum, and if we start by assuming absence of backlash and friction torque, then the can be assumed to form a straight line from a known elongated member position on the drum to the wellhead position.', 'Based on the known geometry of the spooling system and assuming a fixed wellhead relative position, the wellhead position is estimated given the uncertainties in the geometry.', 'This method is also used to estimate the friction torque and backlash in the spooling arm.', 'The swing test is performed when the drum is stationary with known elongated member position.', 'In an example, if the spooling guide is a spooling arm a small and gradual pressure/torque is applied to the arm to the right then left while monitoring the arm angle measurement.', 'If performed at different tension values at different depths, this method is used to estimate the well head position as well as the backlash and friction torque in the arm.', 'Real time estimation of the wellhead position, on the other hand, is performed during the controlled spooling or unspooling by monitoring the required pressure/torque to maintain the desired fleet angle under known tension.', 'Static equilibrium between the tension torque and the pressure torque can be used to infer the wellhead position.', 'A more accurate estimate is obtained using dynamic equilibrium to infer the wellhead position, friction torque, and backlash using an Unscented Kalman Filter.', 'In one non-limiting example embodiment, a system for automated spooling of a deployment unit is disclosed.', 'The system may comprise a sensor and measurement system configured to measure a drum position, an elongated member length, a spooling pressure and a tension in an elongated member of the deployment unit.', 'The system may also comprise a data driven system identification system configured to accept and process data related to winch parameters, spooling guide parameters, truck parameters and site parameters.', 'The system may further comprise a spooling guide interface configured to receive and process measurements from the sensor and measurement system.', 'The system may further comprise a stochastic inference system configured to receive the processed measurements to calculate an elongated member position, a layer direction, a fleet angle and a radius.', 'The system may also comprise an auto-spooling controller connected to the deployment unit and the data driven system identification system, wherein the auto-spooling controller is configured to interface with the stochastic inference system and control the deployment unit, and the auto-spooling controller is configured to control actions of the deployment unit based upon a processing of data from the sensor and measurement system, the stochastic inference system, the spooling guide interface and the data driven system identification system.', 'In another example embodiment, the system may further comprise an orchestration system connected to the deployment unit and configured to alter at least one function of the deployment unit.', 'The system may also comprise an anomaly detection and health monitoring system connected to the auto-spooling controller, wherein the anomaly detection and health monitoring system is configured to identify an anomaly and send data to the orchestration system.', 'In another example embodiment, the system may be configured wherein the orchestration system is further configured to vary at least one mechanical function of the deployment unit based upon a health monitoring command generated by the anomaly detection and health monitoring system.', 'In another example embodiment, the system may be configured wherein the varying the at least one mechanical function of the deployment unit is through at least one of an actional insight and a failure preventative correction message.', 'In another example embodiment, the system may be configured wherein the sensor and measurement system includes a computer vision system.', 'In another example embodiment, the system may be configured wherein the anomaly detection and health monitoring system is configured with a computer vision system.', 'In another example embodiment, the system may further comprise a Bayesian inference system within the anomaly detection and health monitoring system.', 'In another example embodiment, the system may further comprise an arm angle controller.', 'In another example embodiment, the system may be configured wherein the arm angle controller is configured with at least one of a feedforward friction observer, a pulse width modulation system and an active disturbance rejection system.', 'In another example embodiment, a method to control a spooling of a drum of a deployment unit is disclosed.', 'The method may comprise obtaining data related to a sensor and measurement system connected to the deployment unit.', 'The method may further comprise processing the data obtained by the sensor and measurement system in a processing unit that makes a stochastic inference.', 'The method may also comprise controlling an auto spooling of the drum of the deployment unit through an auto-spooling controller connected to the deployment unit based upon the stochastic inference.', 'In another example embodiment, the method may be performed wherein the stochastic inference determines an elongated member position, a layer direction, a fleet angle and a radius value.', 'In another example embodiment, the method may further comprise obtaining visual data of the deployment unit through a computer vision system and wherein the visual data is processed by one of a spooling arm interface and the processing unit configured to make the stochastic inference.', 'In another example embodiment, the method may further comprise obtaining data related to at least one of winch parameters, spooling arm parameters, truck parameters and site parameters through a data driven system identification system, processing the data obtained by the data driven system identification system and transmitting the processed data to the auto-spooling controller.', 'In another example embodiment, the method may further comprise performing an anomaly detection on the deployment unit during the controlling the spooling of the drum of the deployment unit.', 'In another example embodiment, the method may further comprise using a computer vision system during the performing the anomaly detection on the deployment unit.', 'The foregoing description of the embodiments has been provided for purposes of illustration and description.', 'It is not intended to be exhaustive or to limit the disclosure.', 'Individual elements or features of a particular embodiment are generally not limited to that particular embodiment, but, where applicable, are interchangeable and can be used in a selected embodiment, even if not specifically shown or described.', 'The same may be varied in many ways.', 'Such variations are not to be regarded as a departure from the disclosure, and all such modifications are intended to be included within the scope of the disclosure.', 'While embodiments have been described herein, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments are envisioned that do not depart from the inventive scope.', 'Accordingly, the scope of the present claims or any subsequent claims shall not be unduly limited by the description of the embodiments described herein.']

['1.', 'A system for automated spooling of a deployment unit, comprising:\na sensor and measurement system configured to measure a drum rotation, an elongated member length, an elongated member speed, a spooling pressure, an elongated member guide angle, an axle angle and a tension in an elongated member of the deployment unit;\na data driven system identification system configured to accept and process data related to winch parameters, spooling guide parameters, truck parameters, and site parameters;\na spooling guide interface configured to receive and process the measurements from the sensor and measurement system;\na stochastic inference system configured to receive the processed measurements from the spooling guide interface to calculate an elongated member position, a layer direction, a fleet angle, and a radius; and\nan auto-spooling controller connected to the deployment unit and the data driven system identification system, wherein the auto-spooling controller is configured to interface with the stochastic inference system and control the deployment unit, and the auto-spooling controller is configured to control actions of the deployment unit based upon a processing of data from the sensor and measurement system, the stochastic inference system, the spooling guide interface, and the data driven system identification system.', '2.', 'The system according to claim 1, further comprising:\nan orchestration system connected to the deployment unit and configured to alter at least one function of the deployment unit; and\nan anomaly detection and health monitoring system connected to the auto-spooling controller, wherein the anomaly detection and health monitoring system is configured to identify an anomaly and send data to the orchestration system.', '3.', 'The system according to claim 2, wherein the orchestration system is further configured to vary at least one mechanical function of the deployment unit based upon a health monitoring command generated by the anomaly detection and health monitoring system.', '4.', 'The system according to claim 3, wherein the varying of at least one mechanical function of the deployment unit is through at least one of an actional insight and a failure preventative correction message.', '5.', 'The system according to claim 1, wherein the sensor and measurement system includes a computer vision system.', '6.', 'The system according to claim 2, wherein the anomaly detection and health monitoring system is configured with a computer vision system.', '7.', 'The system according to claim 6, further comprising a Bayesian inference system within the anomaly detection and health monitoring system.', '8.', 'The system according to claim 7, further comprising an arm angle controller.', '9.', 'The system according to claim 8, wherein the arm angle controller is configured with at least one of a feedforward friction observer, a pulse width modulation system and an active disturbance rejection system.']

['FIG.', '1 is a picture of a conventional deployment unit that carries a measuring head and systems to control the fleet angle.; FIG.', '2 is a side view of a spooling arm arrangement.; FIG.', '3 is an overview of a spooling automation system.;', 'FIGS.', '4A, 4B and 4C are a series of pictographic definitions of zero, lagging and leading fleet angles proceeding from left to right.', '; FIG.', '5 is a view of main parameters and coordinate system of the spooling arm.; FIG.', '6 is a side view of spooling arm hydraulics used in one example embodiment of the disclosure.', '; FIG. 7 is a general block diagram of an adaptive cascade controller that can be used in controlling operation of the systems for auto spooling.; FIG. 8 is a diagrammatic view of an arm controller used in controlling operation of the systems for auto spooling.', '; FIG.', '9 is a diagrammatic layout of a winch system showing a spooling arm, drum, and elongated member.; FIGS.', '10A and 10b are a series of pictographic examples of layer direction.', '; FIGS.', '11A, 11B and 11C are a series of pictographic examples of effective fleet angle for a neutral position, a lagging fleet angle, and a leading fleet angle.; FIGS.', '12A through 12E are a series of pictographic examples of a successful mode while spooling and failure modes while spooling.; FIG.', '13 is an ideal uncontrolled fleet angle profile.; FIG.', '14 is an example of an asymmetric fleet angle profile.; FIG.', '15 is a flow chart for a fusion framework for updating flange position.; FIG.', '16 is a set of example results for prior positions, after a first measurement position and after 100 measurement positions.; FIG.', '17 is a side view of a position point making an angle λ with the vertical.; FIG.', '18 is an estimate of theta angle and Gaussian CDF values for a typical gap failure.; FIG.', '14 shows an optimal fleet angle profile with the following parameters: x represents the uncertainty in elongated member position estimation.', 'a is the lagging bound of the fleet angle.', 'b is the leading bound of the fleet angle.', 'And s is the slope of the linear segments and is chosen to create a smooth transition between the leading and lagging angle during the spooling process while taking into account the maximum speed at which the spooling controller can move the arm.; FIG.', '15 shows a flow chart of the fusion framework.', 'FIG.', '16 shows example results, where the top, middle and bottom panels show the distributions of the believed flange positions before receiving any measured flange position, after receiving 1, and 100 measured flange positions respectively.', 'On each row of the figure, the left figure shows the believes of all the 120 flanges while the right figure shows a zoom in version of the first few distributions.', 'As expected, the system becomes more confident on the flange positions upon receiving measurements as the distribution variances shrink.']

US11932807

Methods and compositions using dissolvable gelled materials for diversion

Oct 9, 2020

Yenny Christanti, Konstantin Viktorovich Vidma, Changsheng Xiang, Samuel Danican, Valerie Gisele Helene Lafitte

Schlumberger Technology Corporation

Search Report and Written Opinion of International Patent Application No. PCT/US2020/054944 dated Jan. 20, 2021, 11 pages.; Russian Office Action and Search Report; Application No. 2022112106/03(025430); dated Jan. 30, 2024; 18 pages with English Translation.

6367548; April 9, 2002; Purvis et al.; 7004255; February 28, 2006; Boney; 7380600; June 3, 2008; Willberg et al.; 7565929; July 28, 2009; Bustos et al.; 8109335; February 7, 2012; Luo et al.; 8905133; December 9, 2014; Potapenko et al.; 20060185848; August 24, 2006; Surjaatmadja et al.; 20100212906; August 26, 2010; Fulton et al.; 20110226479; September 22, 2011; Tippel et al.; 20140048260; February 20, 2014; Reddy; 20160003022; January 7, 2016; Rothrock et al.; 20160122618; May 5, 2016; Nguyen; 20170198191; July 13, 2017; Potapenko; 20170342307; November 30, 2017; Vasquez; 20210130504; May 6, 2021; Kim

2636526; November 2017; RU; 2666800; September 2018; RU

['A wellbore treatment fluid is disclosed herein, the fluid comprising a butenediol vinyl alcohol copolymer.', 'Also, a wellbore treatment fluid comprises a dissolvable material capable of forming a gel upon hydration, the dissolvable material having a cylindrical cross-sectional shape.', 'Methods of treating a subterranean formation includes introducing a treatment fluid comprising a butenediol vinyl alcohol copolymer, and creating a plug with the treatment fluid.']

['Description\n\n\n\n\n\n\nPRIORITY', 'This nonprovisional application is a National Stage Entry of International Application No.', 'PCT/US2020/054944, filed on Oct. 9, 2020, which claims the benefit of U.S. Provisional Application Ser.', 'No. 62/913,929, filed on Oct. 11, 2019.', 'BACKGROUND', 'The statements in this section merely provide background information related to the present disclosure and may not constitute prior art.', 'Some embodiments relate to methods applied to a wellbore penetrating a subterranean formation, and more particularly, methods for zonal isolation.', 'Hydrocarbons (oil, condensate, and gas) are typically produced from wells that are drilled into the formations containing them.', 'For a variety of reasons, such as inherently low permeability of the reservoirs or damage to the formation caused by drilling and completion of the well, the flow of hydrocarbons into the well is undesirably low.', 'In this case, the well is “stimulated” for example using hydraulic fracturing, chemical (usually acid) stimulation, or a combination of the two (called acid fracturing or fracture acidizing).', 'In hydraulic and acid fracturing, a first, viscous fluid called the pad is typically injected into the formation to initiate and propagate the fracture.', 'This is followed by a second fluid that contains a proppant to keep the fracture open after the pumping pressure is released.', 'Granular proppant materials may include sand, ceramic beads, or other materials.', 'These types of materials are well known to those skilled in the art.', 'In “acid” fracturing, the second fluid contains an acid or other chemical such as a chelating agent that can dissolve part of the rock, causing irregular etching of the fracture face and removal of some of the mineral matter, resulting in the fracture not completely closing when the pumping is stopped.', 'Occasionally, hydraulic fracturing can be done without a highly viscosified fluid (i.e., slick water) to minimize the damage caused by polymers or the cost of other viscosifiers.', 'Hydraulic and acid fracturing of horizontal wells, as well as multi-layered formations, frequently require using diverting techniques in order to enable fracturing redirection between different zones.', 'In other cases, the generation of highly conductive fractures (natural or induced) during fracturing may impede the creation of new fractures.', 'Thus, fracturing fluids formulated with a diverting agent, capable of temporary or permanent bridging (i.e., plugging) existing fractures, divert flow of fracturing fluids from regions of high permeability to those of lower permeability, such as where stimulation will be more effective.', 'The list of these diverting methods includes, but not limited to, using mechanical isolation devises such as packers and wellbore plugs, setting bridge plugs, pumping ball sealers, pumping slurred benzoic acid flakes and removable/degradable particulates.', 'As well, other treatment may require use of diverting techniques.', 'Treatment diversion with particulates is typically based on bridging the particles of diverting material behind a casing and forming a plug by accumulating the rest of the particles at the formed bridge.', 'Several typical problems related to treatment diversion with particulate materials are: reducing bridging ability of diverting slurry during pumping because of dilution with wellbore fluid (interface mixing), necessity of using relatively large amount of diverting materials, and poor stability of some diverting agents during pumping and during subsequent treatment stage.', 'In other cases, during the drilling of a wellbore, various fluids are typically used in the well for a variety of functions.', 'The fluids may be circulated through a drill pipe and drill bit into the wellbore, and then may subsequently flow upward through the wellbore to the surface.', 'During this circulation, the drilling fluid may act to remove drill cuttings from the bottom of the hole to the surface, to suspend cuttings and weighting material when circulation is interrupted, to control subsurface pressures, to maintain the integrity of the wellbore until the well section is cased and cemented, to isolate the fluids from the formation by providing sufficient hydrostatic pressure to prevent the ingress of formation fluids into the wellbore, to cool and lubricate the drill string and bit, and/or to maximize penetration rate.', 'In other aspects, lost circulation may be a recurring drilling problem, characterized by loss of drilling mud into downhole formations.', 'It can occur naturally in formations that are fractured, highly permeable, porous, cavernous, or vugular.', 'These earth formations can include shale, sands, gravel, shell beds, reef deposits, limestone, dolomite, and chalk, among others.', 'Other problems encountered while drilling and producing oil and gas include stuck pipe, hole collapse, loss of well control, and loss of or decreased production.', 'Lost circulation may be controlled by including an additive in fluids injected into wellbores.', 'The most common additive used to control or cease lost circulation is bentonite which will seal small holes or fractures.', 'Bentonite, in higher concentrations, increases viscosity and slows the fluid flow into the surrounding rock.', 'Other solids, such as ground paper, ground corn cobs and sawdust, have also been used to control fluid loss.', 'Polymers are also sometimes used to increase the viscosity of a wellbore fluid and to control fluid loss.', 'Polymer additives, however, are generally more expensive than particulates such as bentonite.', 'Methods and compositions disclosed herewith relate to diversion, zonal isolation or techniques thereof.', 'SUMMARY', 'In an aspect, a method of treating a subterranean formation penetrated by a wellbore is disclosed.', 'The method may include introducing a treatment fluid into the wellbore whereby the treatment fluid comprises a first component comprising vinyl alcohol polymer, butenediol vinyl alcohol copolymer for example, as a diverting agent, and creating a plug with the treatment fluid.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n illustrates particles and flakes, including dimensions, in accordance with aspects of the present disclosure.\n \nFIG.', '2\n illustrates shapes of perforation tunnels, in accordance with aspects of the present disclosure.\n \nFIG.', '3\n illustrates particles size distribution for reducing plug permeability, in accordance with aspects of the present disclosure.\n \nFIG.', '4\n illustrates a near wellbore diversion pack, in accordance with aspects of the present disclosure.\n \nFIG.', '5\n depicts a laboratory setup for creating a plug, in accordance with aspects of the present disclosure.\n \nFIG.', '6\n depicts dissolution studies of butenediol vinyl alcohol copolymer in accordance with aspects of the present disclosure.', "DETAILED DESCRIPTION\n \nAt the outset, it should be noted that in the development of any actual embodiments, numerous implementation-specific decisions must be made to achieve the developer's specific goals, such as compliance with system and business-related constraints, which can vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort might be complex and time consuming but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'The description and examples are presented solely for the purpose of illustrating some embodiments and should not be construed as a limitation to the scope and applicability.', 'In the summary and this detailed description, each numerical value should be read once as modified by the term “about” (unless already expressly so modified), and then read again as not so modified unless otherwise indicated in context.', 'Also, in the summary and this detailed description, it should be understood that a concentration range listed or described as being useful, suitable, or the like, is intended that any and every concentration within the range, including the end points, is to be considered as having been stated.', 'For example, “a range of from 1 to 10” is to be read as indicating each and every possible number along the continuum between about 1 and about 10.', 'Thus, even if specific data points within the range, or even no data points within the range, are explicitly identified or refer to only a few specific, it is to be understood that inventors appreciate and understand that any and all data points within the range are to be considered to have been specified, and that inventors possession of the entire range and all points within the range disclosed and enabled the entire range and all points within the range.', 'The following definitions are provided in order to aid those skilled in the art in understanding the detailed description.', 'The term “treatment”, or “treating”, refers to any subterranean operation that uses a fluid in conjunction with a desired function and/or for a desired purpose.', 'The term “treatment”, or “treating”, does not imply any particular action by the fluid.', 'The term “fracturing” refers to the process and methods of breaking down a geological formation and creating a fracture, i.e. the rock formation around a wellbore, by pumping fluid at very high pressures (pressure above the determined closure pressure of the formation), in order to increase production rates from a hydrocarbon reservoir.', 'The fracturing methods otherwise use conventional techniques known in the art.', 'Vinyl Alcohol Copolymer\n \nThe present disclosure contemplates dissolvable materials for ultralow temperature diversion in fracturing treatment.', 'Such treatment fluids may comprise dissolvable vinyl alcohol copolymer based particulates (e.g., butenediol vinyl alcohol copolymer) as a temporary diverting agent.', 'In an aspect, the treatment fluids may comprise about at least 0.5 wt % butenediol vinyl alcohol copolymer in its composition.', 'In embodiments, treatment fluids herein may comprise up to about 5.0 wt % butenediol vinyl alcohol copolymer in its composition.', 'The butenediol vinyl alcohol copolymer, a biodegradable and eco-friendly polymer, may be capable of bridging narrow portions of the fractures such as those encountered during hydraulic fracturing operations.', 'Generally, diverting agents may divert a portion of treatment fluids into a particular region in a subterranean zone.', 'Diverting agents herein may also be capable of bridging narrow portions of fractures, such as those encountered during hydraulic fracturing or acidizing operations.', 'As the vinyl alcohol copolymer-based particulates herein are transported through the near wellbore fractures, the particles may stick together and bridge portions of the fracture(s).', 'The dissolvable materials are capable of forming a gel upon hydration with low permeability and dissolve away in a short period of time (about 8 hours) at ultralow temperature (below 120° F.).', 'In an embodiment, the dissolvable vinyl alcohol copolymer material may form a sticky gel or swellable gel.', 'The sticky (i.e., adhesive) or swellable nature of the hydrated particles may keep the diversion material from spreading during transport, aid in bridging, and aid in the reduction of permeability within the diversion pack.', 'The hydrated particles may form a gel with low permeability, which may not require particles in different sizes or the aid of fibers to achieve the low permeability.', 'In some embodiments, degradation of the vinyl alcohol copolymer material may occur at about room temperature to 150° F.', 'The dissolvable gelled material may expand the temperature window of diverting operations and improve the job efficiency compared to solely using degradable materials such as polylactide, or the like, which take months to degrade below 120° F.', 'This material may also improve the ease of job operation since only one type of diverting material may need to be pumped during the job.', 'The dissolvable vinyl alcohol copolymer diverter material may comprise one or more non-deformable bridging particles.', 'The diversion mixture may or may not contain degradable or non-degradable fibers.', 'As the dissolvable diverter material is transported through the near wellbore fractures, the larger particles may begin to bridge starting accumulation of the diversion particles.', 'During this process, small particles may fill the interpore space between the large particles as shown in \nFIG. \n4\n.', 'As the large and smaller particles pack off, the permeability may decrease and lead to near wellbore diversion.', 'If fiber is used, it may help transport the diversion material, keep the diversion material from spreading during transport, aid in bridging, and/or aid in the reduction of permeability within the diversion pack.', 'Dissolvable diverter materials disclosed herein may comprise poly(vinyl alcohol) (PVOH) such as butenediol vinyl alcohol copolymer and/or a thermoplastic starch blend, and the like.', 'Particulates herein may be present in various particles sizes.', 'Specifically, the vinyl alcohol copolymer material may be present in varying particle sizes, such as, for example, about 4.5 mm, 2.5 mm, 1 mm, 0.6 mm, 200 micron cross-sectional diameter.', 'Dissolvable diverter materials herein may exist as a particulate; the terms “particulate” or “particle” herein may refer to a solid 3D object with maximal dimension significantly less than 1 meter, for example.', 'Further, a “dimension” of an object refers to the distance between two arbitrary parallel planes, each plane touching the surface of the object at least one point.', 'A maximal or maximum dimension refers to the largest distance existing for the object between any two parallel planes, and a minimal or minimum dimension refers to the shortest distance existing for the object between any two parallel planes.', 'In some embodiments, particulates used herein may be within a ratio between the maximal and the minimal dimensions (particle aspect ratio x/y) of less than 5 or even of less than 3, such as shown in \nFIG.', '1\n.', 'The term “flake” may refer to a type of particulate as defined above.', 'The flake may be a solid 3D object having a thickness smaller than its other dimensions, for example its length and width.', 'Flake aspect ratios (diameter/thickness, length/thickness, width/thickness) may be in the range of from about 5 to about 50 or more, also as seen in \nFIG.', '1\n.', 'Pertaining to the flake, a flake aspect ratio may be the ratio of the length or width to the thickness.', 'Any suitable ratio of length to width may be used herein.', 'The terms “particle size”, “particulate size” or “flake size” may refer to the diameter of the smallest imaginary circumscribed sphere which may include such particulate or flake.', 'For the purposes of the present disclosure, components of treatment fluid may comprise particles and flakes, having homogeneous or non-homogeneous structure, made of porous or composite materials, for example.', 'Particles or flakes herein may be embodied as proppants.', 'Such proppants may be natural or synthetic (including but not limited to glass beads, ceramic beads, sand, and bauxite), coated, or contain chemicals; and more than one can be used sequentially or in mixtures of different sizes or different materials.', 'The proppant may be resin coated (curable), pre-cured resin coated, or have a corrosion resistant material formed thereon Proppants and gravels in the same or different wells or treatments can be the same material and/or the same size as one another and the term proppant is intended to include gravel in this disclosure.', 'In some embodiments, any reasonable shaped particles may be used as proppants, such as rod-shaped particles, elongated particles, plate-like particles, or the like.', 'Such particles may also have any reasonable cross-sectional shapes such as cylindrical or the like.', 'In an embodiment, treatment fluids may comprise a blend rod-shaped, flake, or cylindrical cross-sectional shaped dissolvable materials.', 'Enhanced bridging properties have been shown with a blend of both flake and cylindrical cross-sectional shaped particles.', 'The term “average size” may refer to an average size of solids in a group of solids of each type.', 'In each group j of particles or flakes average size can be calculated as mass-weighted value\n \n \n \n \n \n \n \nL\n \n_\n \n \nj\n \n \n=\n \n \n \n \n∑\n \n \ni\n \n=\n \n1\n \n \nN\n \n \n \n \n \n \nl\n \ni\n \n \n\u2062\n \n \nm\n \ni\n \n \n \n \n \n \n∑\n \n \ni\n \n=\n \n1\n \n \nN\n \n \n \n \n \nm\n \ni\n \n \n \n \n \n \n \n Where N—number of particles or flakes in the group, l\ni\n, (i=1 . . .', 'N)—sizes of individual particles or flakes; m\ni \n(i=1 . . .', 'N)—masses of individual particles or flakes.', 'The term “hole” may refer to a 2D object of any geometry defined only by its perimeter.', 'The term “hole diameter” or “hole size” may refer to the diameter of the biggest imaginary circle which is included in such hole.', 'While the embodiments described herewith may refer to well treatments, they may also be applicable to any well operations where zonal isolation occurs, such as drilling operations, workover operations, and the like.', 'A method of treatment for diversion or for temporally zonal isolation is disclosed.', 'The method uses a composition which may comprise blends of particles or blends of particles and flakes.', 'According to an embodiment, the size(s) of the largest particles or flakes in the blends may be slightly smaller than the diameter of perforation holes in the zone to isolate or divert.', 'According to a further embodiment, the size of particles or flakes in the blends may be larger than an average width of the void intended to be closed or temporally isolated.', 'The average width of the void may be the smallest width of the void after the perforation hole or another entry in such void, at 10 cm, at 20 cm, at 30 cm or at 50 cm or at 500 cm, for example, when going into the formation from the wellbore.', 'Such void may be a perforation tunnel, hydraulic fracture or wormhole, such as shown in \nFIG.', '2\n.', 'Introducing blends or compositions into perforation holes may result in jamming the largest particles in the voids proximate the wellbore.', 'Thereafter, there may be an accumulation of other particles on the formed bridge.', 'In one embodiment, the ratio between particles and flakes in the blends may be designed to reduce permeability of the formed plugs.', 'According to one aspect, treatment fluids herein may enable zonal isolation by creating plugs proximate to a wellbore.', 'In comparison to traditional treatment diversion techniques, compositions herein may require lower amounts of diverting material.', 'The following benefits exist with fluids herein: lower risk of wellbore plugging, lower risk of formation damage, and enhanced clean up.', 'In an example where the diverting blend is designed for sealing perforation tunnels (e.g. slick-water treatments), the amount of diverting material required for diversion between several perforation clusters may be as low as several kilograms.', 'Removal of diverting material is achieved either by self-degradation at downhole conditions or by introducing special chemical agents or by wellbore intervention.', 'Fibers', 'In some embodiments, treatment fluids herein may optionally contain fibers (either or both degradable and non-degradable).', 'In embodiments, fibers may aid the bridging of PVOH particles.', 'The fibers may be straight, curved, bent or undulated.', 'Other non-limiting shapes may include hollow, generally spherical, rectangular, polygonal, etc.', 'Fibers or elongated particles may be used in bundles.', 'The fibers may have a length of less than about 1 mm to about 30 mm or more.', 'In certain embodiments the fibers may have a length of 12 mm or less with a diameter or cross dimension of about 200 microns or less, with from about 10 microns to about 200 microns being typical.', 'For elongated materials, the materials may have a ratio between any two of the three dimensions of greater than 5 to 1.', 'In certain embodiments, the fibers or elongated materials may have a length of greater than 1 mm, with from about 1 mm to about 30 mm, from about 2 mm to about 25 mm, from about 3 mm to about 20 mm, being typical.', 'In certain applications the fibers or elongated materials may have a length of from about 1 mm to about 10 mm (e.g. 6 mm).', 'The fibers or elongated materials may have a diameter or cross dimension of from about 5 to 100 microns and/or a denier of about 0.1 to about 20, more particularly a denier of about 0.15 to about 6.', 'The fiber may be formed from a degradable material or a non-degradable material.', 'The fiber may be organic or inorganic.', 'Non-degradable materials are those wherein the fiber remains substantially in its solid form within the well fluids.', 'Examples of such materials include glass, ceramics, basalt, carbon and carbon-based compound, metals and metal alloys, etc. Polymers and plastics that are non-degradable may also be used as non-degradable fibers.', 'These may include high density plastic materials that are acid and oil-resistant and exhibit a crystallinity of greater than 10%.', 'Other non-limiting examples of polymeric materials include nylons, acrylics, styrenes, polyesters, polyethylene, oil-resistant thermoset resins and combinations of these.', 'Degradable fibers may include those materials that can be softened, dissolved, reacted or otherwise made to degrade within the well fluids.', 'Such materials may be soluble in aqueous fluids or in hydrocarbon fluids.', 'Oil-degradable particulate materials may be used that degrade in the produced fluids.', 'Non-limiting examples of degradable materials may include, without limitation, polyvinyl alcohol, polyethylene terephthalate (PET), polyethylene, dissolvable salts, polysaccharides, waxes, benzoic acid, naphthalene-based materials, magnesium oxide, sodium bicarbonate, calcium carbonate, sodium chloride, calcium chloride, ammonium sulfate, soluble resins, and the like, and combinations of these.', 'Degradable materials may also include those that are formed from solid-acid precursor materials.', 'These materials may include polylactic acid (PLA), polyglycolic acid (PGA), carboxylic acid, lactide, glycolide, copolymers of PLA or PGA, and the like, and combinations of these.', 'Such materials may also further facilitate the dissolving of the formation in the acid fracturing treatment.', 'Also, fibers can be any fibrous material, such as, but not necessarily limited to, natural organic fibers, comminuted plant materials, synthetic polymer fibers (by non-limiting example polyester, polyaramide, polyamide, novoloid or a novoloid-type polymer), fibrillated synthetic organic fibers, ceramic fibers, inorganic fibers, metal fibers, metal filaments, carbon fibers, glass fibers, ceramic fibers, natural polymer fibers, and any mixtures thereof.', 'Particularly useful fibers are polyester fibers coated to be highly hydrophilic, such as, but not limited to, DACRON® polyethylene terephthalate (PET) fibers available from Invista Corp., Wichita, Kans., USA, 67220.', 'Other examples of useful fibers include, but are not limited to, polylactic acid polyester fibers, polyglycolic acid polyester fibers, polyvinyl alcohol fibers, and the like.', 'Polymer fibers may comprise polyesters obtained by polymerization of hydroxycarboxylic acids, such as the aliphatic polyester of lactic acid, referred to as polylactic acid; glycolic acid, referred to as polyglycolic acid; 3-hydroxybutyric acid, referred to as polyhydroxybutyrate; 2-hydroxyvaleric acid, referred to as polyhydroxyvalerate; epsilon caprolactone, referred to as polyepsilon caprolactone or polyprolactone; the polyesters obtained by esterification of hydroxyl aminoacids such as serine, threonine and tyrosine; and the copolymers obtained by mixtures of the monomers listed above.', 'A general structure for the above-described homopolyesters is: \n H—{O—[C(R1,R2)]\nx\n-[C(R3,R4)]\ny\n-C═O}\nz\n—OH \n \n \n \nwhere,\n \nR1, R2, R3, R4 is either H, linear alkyl, such as CH\n3\n, CH', '2\nCH\n3\n, (CH\n2\n)\nn\nCH\n3\n, branched alkyl, aryl, alkylaryl, a functional alkyl group (bearing carboxylic acid groups, amino groups, hydroxyl groups, thiol groups, or others) or a functional aryl group (bearing carboxylic acid groups, amino groups, hydroxyl groups, thiol groups, or others);\n \nx is an integer between 1 and 11;\n \ny is an integer between 0 and 10; and\n \nz is an integer between 2 and 50,000.', 'In the appropriate conditions (e.g., pH, temperature, water content), polyesters described herein can hydrolyze and degrade to yield hydroxycarboxylic acid and compounds that pertain to those acids referred to in the foregoing as “monomeric acids.”', 'One example of a suitable polymeric acid precursor, as mentioned above, is the polymer of lactic acid, sometimes called polylactic acid, “PLA,” polylactate or polylactide.', 'Lactic acid is a chiral molecule and has two optical isomers.', 'These are D-lactic acid and L-lactic acid.', 'The poly(L-lactic acid) and poly(D-lactic acid) forms are generally crystalline in nature.', 'Polymerization of a mixture of the L- and D-lactic acids to poly(DL-lactic acid) results in a polymer that is more amorphous in nature.', 'The polymers described herein are essentially linear.', 'The degree of polymerization of the linear polylactic acid can vary from a few units (2-10 units) (oligomers) to several thousands (e.g. 2000-5000).', 'Cyclic structures may also be used.', 'The degree of polymerization of these cyclic structures may be smaller than that of the linear polymers.', 'These cyclic structures may include cyclic dimers.', 'Another example is the polymer of glycolic acid (hydroxyacetic acid), also known as polyglycolic acid (“PGA”), or polyglycolide.', 'Other materials suitable as polymeric acid precursors are all those polymers of glycolic acid with itself or other hydroxy-acid-containing moieties.', 'The polylactic acid and polyglycolic acid may each be used as homopolymers, which may contain less than about 0.1% by weight of other comonomers.', 'As used with reference to polylactic acid, “homopolymer(s)” is meant to include polymers of D-lactic acid, L-lactic acid and/or mixtures or copolymers of pure D-lactic acid and pure L-lactic acid.', 'Additionally, random copolymers of lactic acid and glycolic acid and block copolymers of polylactic acid and polyglycolic acid may be used.', 'Combinations of the described homopolymers and/or the above-described copolymers may also be used.', 'Random, block, graft, and star- and hyper-branched aliphatic polyesters may also be used.', 'Other examples of polyesters of hydroxycarboxylic acids that may be used as polymeric acid precursors may include polymers of hydroxyvaleric acid (polyhydroxyvalerate), hydroxybutyric acid (polyhydroxybutyrate) and their copolymers with other hydroxycarboxylic acids.', 'Polyesters resulting from the ring opening polymerization of lactones such as epsilon caprolactone (polyepsiloncaprolactone) or copolymers of hydroxyacids and lactones may also be used as polymeric acid precursors.', 'Polyesters obtained by esterification of other hydroxyl-containing acid-containing monomers such as hydroxyaminoacids may be used as polymeric acid precursors.', 'Naturally occurring aminoacids are L-aminoacids.', 'Among the 20 most common aminoacids the three that contain hydroxyl groups are L-serine, L-threonine, and L-tyrosine.', 'These aminoacids may be polymerized to yield polyesters at the appropriate temperature and using appropriate catalysts by reaction of their alcohol and their carboxylic acid group.', 'D-aminoacids are less common in nature, but their polymers and copolymers may also be used as polymeric acid precursors.', 'NatureWorks, LLC, Minnetonka, MN, USA, produces solid cyclic lactic acid dimer called “lactide” and from it produces lactic acid polymers, or polylactates, with varying molecular weights and degrees of crystallinity, under the generic trade name NATUREWORKS™ PLA.', "The PLA's currently available from NatureWorks, LLC have number averaged molecular weights (Mn) of up to about 100,000 and weight averaged molecular weights (Mw) of up to about 200,000, although any polylactide (made by any process by any manufacturer) may be used.", 'Those available from NatureWorks, LLC typically have crystalline melt temperatures of from about 120° C. to about 170° C., but others are obtainable.', 'Poly(d,l-lactide) at various molecular weights is also commercially available from Bio-Invigor, Beijing and Taiwan.', 'Bio-Invigor also supplies polyglycolic acid (also known as polyglycolide) and various copolymers of lactic acid and glycolic acid, often called “polyglactin” or poly(lactide-co-glycolide).', 'Polymers herein may occur in crystalline form, and the extent of crystallinity may be controlled by the manufacturing method for homopolymers and by the manufacturing method and the ratio and distribution of lactide and glycolide for the copolymers.', 'Additionally, the chirality of the lactic acid used also affects the crystallinity of the polymer.', 'Polyglycolide can be made in a porous form.', 'Some of the polymers dissolve very slowly in water before they hydrolyze.', 'Amorphous polymers may be useful in certain applications.', 'An example of a commercially available amorphous polymer is that available as NATUREWORKS 4060D PLA, available from NatureWorks, LLC, which is a poly(DL-lactic acid) and contains approximately 12% by weight of D-lactic acid and has a number average molecular weight (Mn) of approximately 98,000 g/mol and a weight average molecular weight (Mw) of approximately 186,000 g/mol.', 'Other polymer materials that may be useful are the polyesters obtained by polymerization of polycarboxylic acid derivatives, such as dicarboxylic acids derivatives with polyhydroxy containing compounds, in particular dihydroxy containing compounds.', 'Polycarboxylic acid derivatives that may be used are those dicarboxylic acids such as oxalic acid, propanedioic acid, malonic acid, fumaric acid, maleic acid, succinic acid, glutaric acid, pentanedioic acid, adipic acid, phthalic acid, isophthalic acid, terephthalic acid, aspartic acid, or glutamic acid; polycarboxylic acid derivatives such as citric acid, poly and oligo acrylic acid and methacrylic acid copolymers; dicarboxylic acid anhydrides, such as, maleic anhydride, succinic anhydride, pentanedioic acid anhydride, adipic anhydride, phthalic anhydride; dicarboxylic acid halides, primarily dicarboxylic acid chlorides, such as propanedioic acid chloride, malonyl chloride, fumaroil chloride, maleyl chloride, succinyl chloride, glutaroyl chloride, adipoil chloride, phthaloil chloride.', 'Useful polyhydroxy containing compounds are those dihydroxy compounds such as ethylene glycol, propylene glycol, 1,4 butanediol, 1,5 pentanediol, 1,6 hexanediol, hydroquinone, resorcinol, bisphenols such as bisphenol acetone (bisphenol A) or bisphenol formaldehyde (bisphenol F); polyols such as glycerol.', 'When both a dicarboxylic acid derivative and a dihydroxy compound are used, a linear polyester results.', 'It is understood that when one type of dicarboxylic acid is used, and one type of dihydroxy compound is used, a linear homopolyester is obtained.', 'When multiple types of polycarboxylic acids and/or polyhydroxy containing monomer are used copolyesters are obtained.', 'According to the Flory Stockmayer kinetics, the “functionality” of the polycarboxylic acid monomers (number of acid groups per monomer molecule) and the “functionality” of the polyhydroxy containing monomers (number of hydroxyl groups per monomer molecule) and their respective concentrations, will determine the configuration of the polymer (linear, branched, star, slightly crosslinked or fully crosslinked).', 'All these configurations can be hydrolyzed or “degraded” to carboxylic acid monomers, and therefore can be considered as polymeric acid precursors.', 'As a particular case example, not willing to be comprehensive of all the possible polyester structures one can consider, but just to provide an indication of the general structure of a case that one can encounter, the general structure for the linear homopolyesters may be: \n H—{O—R1-O—C═O—R2-C═O}\nz\n—OH \n \n \n \nwhere,\n \nR1 and R2, are linear alkyl, branched alkyl, aryl, alkylaryl groups; and\n \nz is an integer between 2 and 50,000.\n \n \n \n \n \nOther examples of suitable polymeric acid precursors are the polyesters derived from phthalic acid derivatives such as polyethyleneterephthalate (PET), polybutyleneterephthalate (PBT), polyethylenenaphthalate (PEN), and the like.', 'Compositions herein may be made of blends of particles or blends of particles and flakes in a carrier fluid.', 'The carrier fluid may be water including fresh water, produced water, seawater.', 'Other non-limiting examples of carrier fluids include hydratable gels (e.g. guars, poly-saccharides, xanthan, hydroxy-ethyl-cellulose, etc.), a cross-linked hydratable gel, a viscosified acid (e.g. gel-based), an emulsified acid (e.g. oil outer phase), an energized fluid (e.g. an N\n2 \nor CO\n2 \nbased foam), and an oil-based fluid including a gelled, foamed, or otherwise viscosified oil.', 'Additionally, the carrier fluid may be a brine, and/or may include a brine.', 'The carrier fluid may include an acid, including but not limited to, hydrochloric acid, hydrofluoric acid, ammonium bifluoride, formic acid, acetic acid, lactic acid, glycolic acid, maleic acid, tartaric acid, sulfamic acid, malic acid, citric acid, methyl-sulfamic acid, chloro-acetic acid, an amino-poly-carboxylic acid, 3-hydroxypropionic acid, a poly-amino-poly-carboxylic acid, and/or a salt of any acid.', 'In certain embodiments, the carrier fluid may include a poly-amino-poly-carboxylic acid, a trisodium hydroxyl-ethyl-ethylene-diamine triacetate, mono-ammonium salts of hydroxyl-ethyl-ethylene-diamine triacetate, and/or mono-sodium salts of hydroxyl-ethyl-ethylene-diamine tetra-acetate.', 'Such solid polymeric acid precursor material may be capable of undergoing an irreversible breakdown into fundamental acid products downhole.', 'As referred to herein, the term “irreversible” will be understood to mean that the solid polymeric acid precursor material, once broken downhole, should not reconstitute while downhole, e.g., the material should break down in situ but should not reconstitute in situ.', 'The term “break down” refers to both the two relatively extreme cases of hydrolytic degradation that the solid polymeric acid precursor material may undergo, e.g., bulk erosion and surface erosion, and any stage of degradation in between these two.', 'This degradation can be a result of, inter alia, a chemical reaction.', 'The rate at which the chemical reaction takes place may depend on, inter alia, the chemicals added, temperature and time.', 'The breakdown of solid polymeric acid precursor materials may or may not depend, at least in part, on its structure.', 'For instance, the presence of hydrolyzable and/or oxidizable linkages in the backbone often yields a material that will break down as described herein.', 'The rates at which such polymers break down are dependent on factors such as, but not limited to, the type of repetitive unit, composition, sequence, length, molecular geometry, molecular weight, morphology (e.g., crystallinity, size of spherulites, and orientation), hydrophilicity, hydrophobicity, surface area, and additives.', 'The manner in which the polymer breaks down also may be affected by the environment to which the polymer is exposed, e.g., temperature, presence of moisture, oxygen, microorganisms, enzymes, pH, and the like.', 'Another class of suitable solid polymeric acid precursor material that may be used includes polyamides and polyimides.', 'Such polymers may comprise hydrolyzable groups in the polymer backbone that may hydrolyze under the conditions that exist in cement slurries and in a set cement matrix.', 'Such polymers also may generate byproducts that may become sorbed into a cement matrix.', 'Calcium salts are a nonlimiting example of such byproducts.', 'Nonlimiting examples of suitable polyamides include proteins, polyaminoacids, nylon, and poly(caprolactam).', 'Another class of polymers that may be suitable for use are those polymers that may contain hydrolyzable groups, not in the polymer backbone, but as pendant groups.', 'Hydrolysis of the pendant groups may generate a water-soluble polymer and other byproducts that may become sorbed into the cement composition.', 'A nonlimiting example of such a polymer includes polyvinylacetate, which upon hydrolysis forms water-soluble polyvinylalcohol and acetate salts.', 'The particle(s) or the flake(s) can be embodied as material reacting with chemical agents.', 'Some examples of materials that may be removed by reacting with other agents are carbonates including calcium and magnesium carbonates and mixtures thereof (reactive to acids and chelates); acid soluble cement (reactive to acids); polyesters including esters of lactic hydroxylcarbonic acids and copolymers thereof (can be hydrolyzed with acids and bases); active metals such as magnesium, aluminum, zinc and their alloys (reactive to water, acids and bases) etc.', 'Particles and flakes may also be embodied as material that accelerate degradation of other component of the formed plug.', 'Some non-limited examples of it is using metal oxides (e.g. MgO) or bases (e.g. Mg(OH)\n2\n; Ca(OH)\n2\n) or salts of weak acids (e.g. CaCO\n3\n) for accelerating hydrolysis of polyesters such as polylactic or polyglycolic acids.', 'The particle(s) or the flake(s) can be embodied as melting materials.', 'Examples of meltable materials that can be melted at downhole conditions hydrocarbons with number of carbon atoms greater than 30 include, but are not limited to, polycaprolactones, paraffin, waxes, or carboxylic acids such as benzoic acid and its derivatives; etc.', 'Wax particles may be used.', 'The particles are solid at the temperature of the injected fluid, and that fluid cools the formation sufficiently that the particles enter the formation and remain solid.', 'Aqueous wax may be commonly used in wood coatings, engineered wood processing, paper and paperboard converting, protective architectural and industrial coatings, paper coatings, rubber and plastics, inks, textiles, ceramics, and the like.', 'They are made by such companies as Hercules Incorporated, Wilmington, Del., U.S.A., under the trade name PARACOL®, Michelman, Cincinnati, Ohio, U.S.A., under the trade name MICHEM®, and ChemCor, Chester, N.Y., U.S.A. Particularly suitable waxes include those commonly used in commercial car washes.', 'In addition to paraffin waxes, other waxes, such as polyethylenes and polypropylenes, may also be used.', 'The particle(s) or the flake(s) can be embodied as water-soluble material or hydrocarbon-soluble material.', 'The list of the materials that can be used for dissolving in water may include water-soluble polymers, water-soluble elastomers, carbonic acids, rock salt, amines, inorganic salts).', 'List of the materials that can be used for dissolving in oil may include oil-soluble polymers, oil-soluble resins, oil-soluble elastomers, polyethylene, carbonic acids, amines, waxes).', 'The particle(s) and the flake(s) size may be chosen so the size of the largest particles or flakes is slightly smaller than the diameter of the perforation holes in casing and larger than the average width of the voids behind casing (perforation tunnels, fractures or wormholes).', 'By perforation hole, we mean any type of hole present in the casing.', 'This hole can be a perforation, a jetted hole, hole from a slotted liner, port or any opening in a completion tool, casing fluid exit point.', 'According to a further embodiment, the size of particles or flakes in the blend is designed for reducing permeability of the plugs in the narrow voids behind casing (perforation tunnels, fractures or wormholes).', 'In general, the particle or flake used will have an average particle size of less than several centimeters, preferably less than 2 cm, and more preferably less than 1 cm.', 'In one embodiment, some particle or flake will have an average particle size of from about 0.2 mm to about 4.76 mm, preferable from about 0.5 mm to about 4.76 mm, more preferably from about 1 mm to about 4.76 mm and other particles will have an average particle size of from 0.04 mm to about 2 mm, preferable from 0.04 mm to about 1.5 mm, more preferably from 0.1 mm to 1 mm.', 'According to a further embodiment, the compositions may comprise particles or flakes with different particles/flakes size distribution.', 'In one embodiment, the composition comprises particulate materials with defined particles size distribution.', 'In certain embodiments, the selection of the size for the first amount of particulates is dependent upon the characteristics of the perforated hole as described above: the size of the largest particles or flakes is slightly smaller than the diameter of the perforation holes in casing.', 'In certain further embodiments, the selection of the size of the first amount of particulates is dependent upon the void behind casing: the size of the particles is larger than the average width of the voids behind casing (perforation tunnels, fractures or wormholes).', 'In certain further embodiments, the selection of the size for the first amount of particulates is dependent upon the characteristics of the perforated hole and the void behind casing: the size of the largest particles or flakes is slightly smaller than the diameter of the perforation holes in casing and larger than the average width of the voids behind casing (perforation tunnels, fractures or wormholes).', 'In certain further embodiments, the selection of the size for the first amount of particulates is dependent upon the characteristics of the desired fluid loss characteristics of the first amount of particulates as a fluid loss agent, the size of pores in the formation, and/or the commercially available sizes of particulates of the type comprising the first amount of particulates.', 'In certain embodiments, the selection of the size for the second amount of particulates is dependent upon the characteristics of the desired fluid loss characteristics of the second amount of particulates as a fluid loss agent, the size of pores in the formation, and/or the commercially available sizes of particulates of the type comprising the second amount of particulates.', 'In certain embodiments, the selection of the size for the second amount of particulates is dependent upon the characteristics of the desired fluid loss characteristics of the second amount of particulates as a fluid loss agent, the size of pores in the formation, and/or the commercially available sizes of particulates of the type comprising the second amount of particulates.', 'The particle size is in the range of 10-100% of the size of the first amount of particulate, more preferably 20-80% of the size of the first amount of particulate.', 'In certain embodiments, the selection of the size particulates is dependent upon maximizing or optimizing a packed volume fraction (PVF) of the mixture of the first amount of particulates and the second amount of particulates.', 'The PVF or packing volume fraction is the fraction of solid content volume to the total volume content.', 'The particles size distribution required for maximizing PVF in narrow slot may be different from the particles size distribution required for maximizing PVF in a continuum system.', 'Therefore, in certain embodiments, the selection of the size of particulates is dependent upon maximizing or optimizing a PVF of the mixture of the first amount of particulates and the second amount of particulates in narrow voids between 2 mm and 2 cm.', 'In certain embodiments, the selection of the size of particulates is dependent upon maximizing or optimizing a PVF of the mixture of the first amount of particulates and the second amount of particulates in a fracture or slot with width of less than 20 mm.', 'In certain embodiments, the particulates combine to have a PVF above 0.74 or 0.75 or above 0.80.', 'In certain further embodiments the particulates may have a much higher PVF approaching 0.95.', 'In certain further embodiments, the composition may further include particulates/flakes having a third average particle size that is smaller than the second average particulate/flake size.', 'In certain further embodiments, the same chemistry can be used for the second, third, fourth, or fifth average particulate/flake size.', 'For the purposes of enhancing the PVF of the composition, additional particles may be added for other reasons, such as the chemical composition of the additional particles, the ease of manufacturing certain materials into the same particles versus into separate particles, the commercial availability of particles having certain properties, and other reasons understood in the art.', 'In certain further embodiments, the composition may further have a viscosifying agent.', 'The viscosifying agent may be any crosslinked polymers.', 'The polymer viscosifier can be a metal-crosslinked polymer.', 'Suitable polymers for making the metal-crosslinked polymer viscosifiers include, for example, polysaccharides such as substituted galactomannans, such as guar gums, high-molecular weight polysaccharides composed of mannose and galactose sugars, or guar derivatives such as hydroxypropyl guar (HPG), carboxymethylhydroxypropyl guar (CMHPG) and carboxymethyl guar (CMG), hydrophobically modified guars, guar-containing compounds, and synthetic polymers.', 'Crosslinking agents based on boron, titanium, zirconium or aluminum complexes are typically used to increase the effective molecular weight of the polymer and make them better suited for use in high-temperature wells.', 'Other suitable classes of polymers effective as viscosifying agent may include polyvinyl polymers, polymethacrylamides, cellulose ethers, lignosulfonates, and ammonium, alkali metal, and alkaline earth salts thereof.', 'More specific examples of other typical water-soluble polymers are acrylic acid-acrylamide copolymers, acrylic acid-methacrylamide copolymers, polyacrylamides, partially hydrolyzed polyacrylamides, partially hydrolyzed polymethacrylamides, polyvinyl alcohol, polyalkyleneoxides, other galactomannans, heteropolysaccharides obtained by the fermentation of starch-derived sugar and ammonium and alkali metal salts thereof.', 'Cellulose derivatives are used to a smaller extent, such as hydroxyethylcellulose (HEC) or hydroxypropylcellulose (HPC), carboxymethylhydroxyethylcellulose (CMHEC) and carboxymethylcellulose (CMC), with or without crosslinkers.', 'Xanthan, diutan, and scleroglucan, three biopolymers, have been shown to have excellent particulate-suspension ability even though they are more expensive than guar derivatives and therefore have been used less frequently, unless they can be used at lower concentrations.', 'In other embodiments, the viscosifying agent is made from a crosslinkable, hydratable polymer and a delayed crosslinking agent, wherein the crosslinking agent comprises a complex comprising a metal and a first ligand selected from the group consisting of amino acids, phosphono acids, and salts or derivatives thereof.', 'Also, the crosslinked polymer can be made from a polymer comprising pendant ionic moieties, a surfactant comprising oppositely charged moieties, a clay stabilizer, a borate source, and a metal crosslinker.', 'The viscosifying agent may be a viscoelastic surfactant (VES).', 'The VES may be selected from the group consisting of cationic, anionic, zwitterionic, amphoteric, nonionic and combinations thereof.', 'The viscoelastic surfactants, when used alone or in combination, are capable of forming micelles that form a structure in an aqueous environment that contribute to the increased viscosity of the fluid (also referred to as “viscosifying micelles”).', 'These fluids are normally prepared by mixing in appropriate amounts of VES suitable to achieve the desired viscosity.', 'The viscosity of VES fluids may be attributed to the three-dimensional structure formed by the components in the fluids.', 'When the concentration of surfactants in a viscoelastic fluid significantly exceeds a critical concentration, and in most cases in the presence of an electrolyte, surfactant molecules aggregate into species such as micelles, which can interact to form a network exhibiting viscous and elastic behavior.', 'In general, particularly suitable zwitterionic surfactants may have the formula: \n RCONH—(CH\n2\n)\na\n(CH\n2\nCH\n2\nO)\nm\n(CH\n2\n)\nb\n—N\n+\n(CH\n3\n)\n2\n—(CH\n2\n)\na′\n(CH\n2\nCH\n2\nO)\nm′\n(CH\n2\n)', 'b′\nCOO\n−\n \n in which R is an alkyl group that contains from about 11 to about 23 carbon atoms which may be branched or straight chained and which may be saturated or unsaturated; a, b, a′, and b′ are each from 0 to 10 and m and m′ are each from 0 to 13; a and b are each 1 or 2 if m is not 0', 'and (a+b) is from 2 to 10 if m is 0; a′ and b′ are each 1 or 2 when m′ is not 0', 'and (a′+b′) is from 1 to 5 if m is 0; (m+m′) is from 0 to 14; and CH\n2\nCH\n2\nO may also be OCH\n2\nCH\n2\n.', 'In some embodiments, a zwitterionic surfactants of the family of betaine is used.', "Examples of suitable cationic VES's include cationic surfactants having the structure: \n R\n1\nN\n+\n(R\n2\n)(R\n3\n)(R\n4\n)X\n−\n \n in which R\n1 \nhas from about 14 to about 26 carbon atoms and may be branched or straight chained, aromatic, saturated or unsaturated, and may contain a carbonyl, an amide, a retroamide, an imide, a urea, or an amine; R\n2\n, R\n3\n, and R\n4 \nare each independently hydrogen or a C\n1 \nto about C\n6 \naliphatic group which may be the same or different, branched or straight chained, saturated or unsaturated and one or more than one of which may be substituted with a group that renders the R\n2\n, R\n3\n, and R\n4 \ngroup more hydrophilic; the R\n2\n, R\n3 \nand R\n4 \ngroups may be incorporated into a heterocyclic 5- or 6-member ring structure which includes the nitrogen atom; the R\n2\n, R\n3 \nand R\n4 \ngroups may be the same or different; R\n1\n, R\n2\n, R\n3 \nand/or R\n4 \nmay contain one or more ethylene oxide and/or propylene oxide units; and X\n−\n is an anion.", 'Mixtures of such compounds are also suitable.', 'As a further example, R\n1 \nis from about 18 to about 22 carbon atoms and may contain a carbonyl, an amide, or an amine, and R\n2\n, R\n3\n, and R\n4 \nare the same as one another and contain from 1 to about 3 carbon atoms.', "Amphoteric VES's are also suitable.", 'Exemplary amphoteric VES systems may include amine oxides, amidoamine oxides, and the like.', 'Mixtures of zwitterionic surfactants and amphoteric surfactants are suitable.', 'An example is a mixture of about 13% isopropanol, about 5% 1-butanol, about 15% ethylene glycol monobutyl ether, about 4% sodium chloride, about 30% water, about 30% cocoamidopropyl betaine, and about 2% cocoamidopropylamine oxide.', 'The VES system may also be based upon any suitable anionic surfactant.', 'In some embodiments, the anionic surfactant is an alkyl sarcosinate.', 'The alkyl sarcosinate can generally have any number of carbon atoms.', 'Alkyl sarcosinates can have about 12 to about 24 carbon atoms.', 'The alkyl sarcosinate can have about 14 to about 18 carbon atoms.', 'Specific examples of the number of carbon atoms include 12, 14, 16, 18, 20, 22, and 24 carbon atoms.', 'The anionic surfactant is represented by the chemical formula: \n R\n1\nCON(R\n2\n)CH\n2\nX \n wherein R\n1 \nis a hydrophobic chain having about 12 to about 24 carbon atoms, R\n2 \nis hydrogen, methyl, ethyl, propyl, or butyl, and X is carboxyl or sulfonyl.', 'The hydrophobic chain can be an alkyl group, an alkenyl group, an alkylarylalkyl group, or an alkoxyalkyl group.', 'Specific examples of the hydrophobic chain include a tetradecyl group, a hexadecyl group, an octadecentyl group, an octadecyl group, and a docosenoic group.', 'In some embodiments, the carrier fluid may optionally further comprise additional additives, including, but not limited to, acids, fluid loss control additives, gas, corrosion inhibitors, scale inhibitors, catalysts, clay control agents, biocides, friction reducers, combinations thereof and the like.', 'For example, in some embodiments, it may be desired to foam the composition using a gas, such as air, nitrogen, or carbon dioxide.', 'The composition may be used for carrying out a variety of subterranean treatments, including, but not limited to, drilling operations, fracturing treatments, diverting treatments, zonal isolation and completion operations (e.g., gravel packing).', 'In some embodiments, the composition may be used in treating a portion of a subterranean formation.', 'In certain embodiments, the composition may be introduced into a wellbore that penetrates the subterranean formation as a treatment fluid.', 'For example, the treatment fluid may be allowed to contact the subterranean formation for a period of time.', 'In some embodiments, the treatment fluid may be allowed to contact hydrocarbons, formations fluids, and/or subsequently injected treatment fluids.', 'After a chosen time, the treatment fluid may be recovered through the wellbore.\n \nMethods of wellsite and downhole delivery of the composition are the same as for existing particulate diverting materials.', 'Typically, such particulate materials are introduced in the pumping fluid and then displaced into the perforations at high pumping rate.', 'The list of injecting equipment may include various dry additive systems, flow-through blenders etc.', 'In one embodiment the blends of particles may be batch mixed and then introduced into the treating fluid in slurred form.', 'Simple flow-through injecting apparatuses may also be used as the one which scheme is shown in \nFIG.', '5\n.', 'In one embodiment, the composition may be delivered downhole in a conventional bailer or in a tool comprising bailer and a perforation gun.', 'Another way of delivering the composition can be envisioned, for example, with a wireline tool, a drill string, through a slickline, with a coil tubing or microcoil, with a downhole tool or any type of other device introduced downhole and able to deliver the composition at a defined location.', 'A microcoil or Microhole Coiled Tubing Drilling Rig (MCTR) is a tool capable of performing an entire “grass-roots” operation in the 0-5000 ft true vertical depth range including drilling and casing surface, intermediate, and production and liner holes.', 'As soon as the volume of diverting blend required for treatment diversion is relatively low, there is a risk that particles in the blend will be separated during pumping through the wellbore.', 'It may result in poorer treatment diversion because of forming plugs of higher permeability than expected.', 'To avoid this situation, long slugs with low concentration of diverting blends may be introduced in the treating fluid for minimizing the risk of particles separation in the main amount of the pumped blend.', 'In one other embodiment, to avoid this situation diverting blends may be pumped in long slugs at low concentrations which will make volume of the diverting stage comparable with the volume of the wellbore.', 'For example for wells with wellbore volume of 200 bbl (32 m\n3\n) the volumes of the diverting stage that minimizes the risk of particles separation may be in the range of 20-100 bbl (3.2-16 m\n3\n).', 'For 5-25 kg of diverting material it corresponds to the range of concentrations of 0.3-8 kg/m\n3\n.', 'Creating plugs of the proposed diverting blends happens by accumulating particles in the void space behind casing.', 'Examples of such voids may be perforation tunnels, hydraulic fractures or wormholes.', 'Plug creation consists of two steps.', 'In the first step some largest particles in the diverting blend jam in the void creating a bridge.', 'During the next step other particles are being accumulated at the formed bridge resulting in plug formation.', 'After treatment, the created plugs are removed.', 'There are several methods that may be applied for removal of the created plugs.', 'If the composition comprises degradable materials, self degradation will occur.', 'If the composition comprises material reacting with chemical agents, those are removed by reacting with other agents.', 'If the composition comprises melting material, melting may result in reduction in mechanical stability of the plug.', 'If the composition comprises water soluble or hydrocarbon soluble materials.', 'Plug removal may be achieved through physical dissolution of at least one of the components of the diverting blend in the surrounding fluid.', 'Solubility of the mentioned components may be in significant dependence on temperature.', 'In this situation post-treatment temperature recovery in the sealed zone may trigger the removal of the sealer.', 'Disintegration of at least one component of the composition may occur.', 'Plug removal may be also achieved through disintegration of the sealer into smaller pieces that will be flushed away.', 'List of possible materials that may possess disintegration include plastics such as PLA, polyamides and composite materials comprising degradable plastics and non-degradable fine solids.', 'It worth to mention that some of degradable material pass disintegration stage during degradation process.', 'As an example only, PLA may turn into fragile materials before complete degradation.', 'Vinyl alcohol copolymers herein, such as butenediol vinyl alcohol copolymers, may expand the temperature window of diverting operations and possibly improve job efficiency compared with polylactide-based materials alone, which may take months to degrade at temperatures below 120° F.', 'In addition to the relatively fast dissolution rate of vinyl alcohol copolymers herein, such as butenediol vinyl alcohol copolymers, the relative ease of job design may also improve job efficiency during operations.', 'Vinyl alcohol copolymers herein, such as butenediol vinyl alcohol copolymers, may also improve the ease of operations since only one type of diverting material may be pumped during the job.', 'To facilitate a better understanding, the following examples of embodiments are given.', 'In no way should the following examples be read to limit, or define, the scope of the overall invention.', 'EXAMPLES\n \nExperiments were conducted to demonstrate the methods of treatment discussed herein.', 'Example 1\n \nThe present example is a dissolution study of butenediol vinyl alcohol copolymer in distilled water (DI).', '1 g of the test material (e.g., vinyl alcohol copolymer) was added into 100 mL DI and placed in a heat source (e.g., oven) at around 100° C. After a certain period, the test material was filtered, dried and weighed.', 'The weight of the test material was recorded to generate the dissolution rate as shown in \nFIG.', '6\n.', 'Dissolvable materials herein, such as vinyl alcohol copolymer materials including butenediol vinyl alcohol copolymer, may provide a solution for ultralow temperature diversion in fracturing treatments.', 'The relatively fast dissolution rate of such vinyl alcohol copolymer materials may improve the job efficiency during operations, with dissolution rates being enhanced by the addition of acid, such as HCl, for example.', 'Example 2\n \nIn the present study, thermoplastic starch (TPS) and plasticized butenediol vinyl alcohol (P-BVOH) were prepared by melt mixing technique(s), and the plasticization effect of glycerol on starch and BVOH with different composition was observed for optimized processing condition(s).', 'Based on the preliminary study, TPS was blended with varying amounts of P-BVOH, such as in weight ratios including 100:0, 90:10, 80:20, 70:30, 60:40, and 50:50.', 'The foregoing disclosure and description is illustrative and explanatory, and it can be readily appreciated by those skilled in the art that various changes in the size, shape and materials, as well as in the details of the illustrated construction or combinations of the elements described herein can be made without departing from the spirit of the invention.']

['1.', 'A method comprising:\nintroducing into a wellbore, a treatment fluid comprising about 0.5 wt % to about 5.0 wt % of a butenediol vinyl alcohol copolymer based on a total weight of the treatment fluid; and\ncreating a plug with the treatment fluid within a subterranean formation.', '2.', 'The method of claim 1, wherein the butenediol vinyl alcohol copolymer has a cylindrical cross-sectional shape.', '3.', 'The method of claim 1, comprising a degradable material, wherein in the butenediol vinyl alcohol copolymer or the degradable material has a first average particle size between about 2 mm and 2 cm.\n\n\n\n\n\n\n4.', 'The method of claim 1, wherein the treatment fluid comprises thermoplastic starch (TPS).', '5.', 'The method of claim 1, wherein the treatment fluid comprises fibers.', '6.', 'The method of claim 1, wherein the treatment fluid comprises a carrier fluid, a viscosifying agent or friction reducer.', '7.', 'The method of claim 6, wherein the carrier fluid is a treatment fluid selected from the group consisting of slickwater, spacer, mutual solvent, flush, formation dissolving fluid, fracturing fluid, scale dissolution fluid, paraffin dissolution fluid, asphaltene dissolution fluid, diverter fluid, water control agent, chelating agent, viscoelastic diverting acid, self-diverting acid, acid, and mixtures thereof.', '8.', 'The method of claim 1 further comprising removing the plug.\n\n\n\n\n\n\n9.', 'A wellbore treatment fluid, comprising:\na dissolvable material capable of forming a gel upon hydration, wherein the dissolvable material comprises particles having a cylindrical cross-sectional shape,\nwherein the dissolvable material comprises about 0.5 wt % to about 5.0 wt % of a butenediol vinyl alcohol copolymer based on a total weight of the wellbore treatment fluid.', '10.', 'The wellbore treatment fluid of claim 9 comprising thermoplastic starch (TPS).', '11.', 'The wellbore treatment fluid of claim 9 comprising fibers.', '12.', 'The wellbore treatment fluid of claim 9 comprising a carrier fluid, a viscosifying agent or friction reducer.', '13.', 'The wellbore treatment fluid of claim 9, wherein the dissolvable material forms a plug within a subterranean formation.', '14.', 'A wellbore treatment fluid, comprising:\nabout 0.5 wt % to about 5.0 wt % of a butenediol vinyl alcohol copolymer based on a total weight of the wellbore treatment fluid.', '15.', 'The wellbore treatment fluid of claim 14 wherein particles of the butenediol vinyl alcohol copolymer have a cylindrical cross-sectional or rod shape.', '16.', 'The wellbore treatment fluid of claim 14 comprising thermoplastic starch (TPS).', '17.', 'The wellbore treatment fluid of claim 14 wherein the butenediol vinyl alcohol copolymer forms a plug within a subterranean formation.', '18.', 'The wellbore treatment fluid of claim 14 comprising a carrier fluid, a viscosifying agent or friction reducer.']

['FIG. 1 illustrates particles and flakes, including dimensions, in accordance with aspects of the present disclosure.', '; FIG.', '2 illustrates shapes of perforation tunnels, in accordance with aspects of the present disclosure.', '; FIG.', '3 illustrates particles size distribution for reducing plug permeability, in accordance with aspects of the present disclosure.', '; FIG.', '4 illustrates a near wellbore diversion pack, in accordance with aspects of the present disclosure.', '; FIG.', '5 depicts a laboratory setup for creating a plug, in accordance with aspects of the present disclosure.', '; FIG.', '6 depicts dissolution studies of butenediol vinyl alcohol copolymer in accordance with aspects of the present disclosure.']

US11898227

Hard nickel-chromium-aluminum alloy for oilfield services apparatus and methods

Oct 11, 2019

Manuel Marya

Schlumberger Technology Corporation

Ul-Hamid, TEM Study of the Effect of Y on the Scale Microstructures of Cr2O3- and Al2O3-Forming Alloys, 2002, Plenum Publishing Corporation, Oxidation of Metals vol. 58, p. 23-40 (Year: 2002).; Kuboki, Grain Refinement and Superplasticity in Ni—30Cr—5Al Alloy, 1988, J-STAGE, Tetsu-to-Hagane vol. 74, p. 87 (Year: 1988).; Kay, Thermal spray applications in the steel industry, 2013, ASM Handbook vol. 5A, ASM International, p. 324-327 (Year: 2013).; Ueta et al., (2010) Influence of Al on Kinetics of Discontinuous Precipitation in Ni—38Cr Alloy, ISIJ International, vol. 50, No. 11, pp. 1676-1682.; Ustinovshchikov, (2013) Structures of Ni40Cr60 and Ni68Cr32 Alloys after Heat Treatment at Various Temperatures, Russian Metallurgy (Metally), vol. 2013, No. 9, pp. 691-698.; International Search Report and Written Opinion of the International Patent Application No. PCT/US2020/070640 dated Jan. 29, 2021, 12 pages.

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3441489; February 2019; EP; 2002069557; March 2002; JP; 2003253362; September 2003; JP; 2005015853; January 2005; JP; 2011001606; January 2011; JP; 2011068961; April 2011; JP

['An environmentally resistant alloy is disclosed having a transition metal that upon being included in the Ni Cr Al alloy causes no liquid phases below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310° C., creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., and wherein the gamma prime phase is characterized by a formula (Ni,Co)x(Cr,Al,Mo)y wherein x and y are integers.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nNone.\n \nFIELD OF THE DISCLOSURE\n \nAspects of the disclosure relate to hydrocarbon Exploration and Production.', 'More specifically, aspects of the disclosure relate to hard, wear, and corrosion resistant metallic materials, referred as nickel-chromium-aluminum alloys in use for oilfield service work.', 'BACKGROUND INFORMATION', 'In hydrocarbon Exploration and Production, hard materials are commonly in use for oilfield service operations that will see or experience wear.', 'For example, these hard materials are used to combat abrasion, erosion, and other forms of component surface damage.', 'Tungsten carbide cermets (carbide-metal composites) are often by default the materials of choice, finding practical applications in flow control (valves, actuators, chokes, well heads, blow out preventers, manifolds), drilling equipment (drill bits, LWD/MWD, mud motors, turbines, rotary steerable, reamers), as well as fishing tools, junk mills, coring tools, gears, wheels, among others.', 'These materials provide several advantages to common materials, however, cermets have other distinct drawbacks.', 'Cermets such as tungsten carbide with nickel or cobalt-rich metal binders are macroscopically harder and more wear resistant than conventional metals and alloys, while softer than typical ceramics and as such are more limited in hardness and pure abrasive wear.', 'However, cermets can be commonly engineered to offer satisfactory compromises in hardness, wear resistance, and toughness.', 'Both hard alloys and cermets are extensively used in the oilfields for both drilling applications and production applications, namely to increase abrasive wear and/or minimize erosion.', 'FIG.', '1\n illustrates a prior-art laser deposition of a hard alloy material, comprising nickel, chromium, boron, among other alloying elements that in-situ form carbide and boride hard particles.', 'Such hard alloys are frequently used for wear bands in drilling application, precisely to reduce wear on drill pipes and collars.', 'As can be seen in \nFIG.', '1\n, the deposit is subject to significant cracking due to its high hardness (in excess of 55 HRC, Hardness Rockwell Scale), a characteristic that inherently limits use of this hard material and other similar hard materials in many oilfield applications, especially for long-term production applications.', 'In other embodiments, tungsten carbide cermets, combining some of the best mechanical properties of carbide ceramics and metals or alloys, are used.', 'These tungsten carbide cermets, however, share similar major technical deficiencies for oilfield applications as the hard alloy of \nFIG. \n1\n.', 'A short list of limitations for cermets (including tungsten carbide cermets) is provided below: \n \n \n \n(1) These materials are not readily fusible and applied onto a part, unless the ceramic phase (carbide phase) is less than approximately 60% and complemented by a highly fusible metallic binder, itself representing a minimum of 40% of the total material;\n \n(2) These materials are highly subject to internal cracking when applied by a fusible process; these cracks may not be critical for erosion service, but may be inadequate for certain surfaces (e.g. sealing surface of static and dynamic seals);\n \n(3) These materials may lack general corrosion resistance because of the binders usually in use.', 'These often include a cobalt along chromium carbides.', 'Due to insufficient chromium and molybdenum in solid-solution, corrosion resistance may be limited for some applications, especially long-term;\n \n(4) These materials are not available to many additive manufacturing (AM) processes such as direct energy deposition or powder bed fusion;\n \n(5) These materials are brittle, therefore may require special precautions for their handling.', 'Further, these materials may not be compatible with thermal cycling, including rapid cooling, as may be required while manufacturing components with such materials.', 'Co—Cr alloys and cast-irons offer other advantages, namely for casting, but are fusible only with restricted hardness values to approximately 40 in order to remain crack free.', 'Tool steels offer proper hardness, but also lack toughness, and cracking resistance, including during sour service (in the presence of H\n2\nS).', 'Above 40 to 50 Rockwell Hardness rating, approximately, fusible alloys have a strong tendency towards cracking.', 'In summary, such hard materials can develop visible cracking as early as when manufactured (\nFIG.', '1\n), or during service, as when exposed to corrosive environments (for instance with H\n2\nS).', 'As the conventional materials above have deficiencies, there is a need to provide a material that may be used in oilfield service work that can withstand the expected service loads present in oilfield service environments.', 'There is a further need to provide a material that is economical to manufacture compared to conventional materials, and implicitly this material is fusible and crack-resistant at the time it is produced.', 'There is a further need to provide a material that is easy to produce in volume to satisfy the needs of oilfield service operators.', 'There is a still further need to provide a material that may be formed into required shapes using casting, additive manufacturing, welding, among other processes, for eventual use in oilfield service applications.', 'SUMMARY\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized below, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted that the drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments without specific recitation.', 'Accordingly, the following summary provides just a few aspects of the description and should not be used to limit the described embodiments to a single concept.', 'In one example embodiment, an environmentally or corrosion resistant alloy is disclosed.', 'The material comprises a transition metal that upon being included in a Ni Cr Al alloys causes no liquid phase below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310° C., and creates over 30% of a gamma prime phase between 450° C. and 600° C., wherein the gamma prime phase is characterized by a formula (Ni,Co)\nx\n(Cr,Al,Mo)\ny \nwherein x and y are integers.', 'In another example embodiment, a cermet material is disclosed.', 'The cermet material comprises one or more ceramics, generally in the form of particulates.', 'The cermet material also comprises a Ni Cr Al alloy binder placed within the particulates, the alloy binder may comprise a transition metal that upon being included in the Ni Cr Al alloy causes no liquid phase below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310', '° C., and creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., wherein the gamma prime phase is characterized by a formula (Ni,Co)\nx\n(Cr,Al,Mo)', 'y \nwherein x and y are integers.', 'In another example embodiment, a cermet is disclosed.', 'The cermet comprises tungsten carbides, generally provided as particulates.', 'The cermet material also comprises a Ni Cr Al alloy binder placed within the particulates, the alloy binder may comprise a transition metal that upon being included in the Ni Cr Al alloy causes no liquid phase below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310', '° C., and creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., wherein the gamma prime phase is characterized by a formula (Ni,Co)\nx\n(Cr,Al,Mo)', 'y \nwherein x and y are integers.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are therefore not be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.\n \nFIG.', '1\n is a depiction of a prior art laser deposited hard alloy used in conventional applications.\n \nFIG.', '2\n is a comparison of major material properties.\n \nFIG.', '3\nA\n illustrates blocks of material produced by additive manufacturing.\n \nFIG.', '3\nB\n illustrates an interface between an aspect of the disclosure and a low alloy steel substrate.\n \nFIG.', '3\nC\n is a graph of an equilibrium phase diagram for an aspect of the disclosure described.\n \nFIG.', '4\n is a list of alloys in accordance with one example embodiment of the disclosure.\n \nFIG.', '5\n is a list of the alloys of \nFIG.', '4\n with the addition of Mo and the physical effects of this placement.\n \nFIG.', '6\n is a list of alloys that investigates the role of W, as partial substitute or complementary to Mo.\n \nFIG.', '7\n is a graph of weight percent phase vs. temperature of alloys in accordance with an example embodiment of the disclosure.', 'While the embodiments described herein are susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and will be described in detail herein.', 'The embodiments described herein are not intended, however, to be limited to the particular forms disclosed.', 'Rather, the instant disclosure covers all modifications, equivalents, and alternatives falling within the scope of the appended claims.', 'DETAILED DESCRIPTION', 'In the following, reference is made to embodiments of the disclosure.', 'It should be understood, however, that the disclosure is not limited to specific described embodiments.', 'Instead, any combination of the following features and elements, whether related to different embodiments or not, is contemplated to implement and practice the disclosure.', 'Furthermore, although embodiments of the disclosure may achieve advantages over other possible solutions and/or over the prior art, whether or not a particular advantage is achieved by a given embodiment is not limiting of the disclosure.', 'Thus, the following aspects, features, embodiments and advantages are merely illustrative and are not considered elements or limitations of the claims except where explicitly recited in a claim.', 'Likewise, reference to “the disclosure” shall not be construed as a generalization of inventive subject matter disclosed herein and shall not be considered to be an element or limitation of the claims except where explicitly recited in a claim.', 'Although the terms first, second, third, etc., may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms.', 'These terms may be only used to distinguish one element, component, region, layer or section from another element, component, region, layer or section.', 'Terms such as “first”, “second” and other numerical terms, when used herein, do not imply a sequence or order unless clearly indicated by the context.', 'Thus, a first element, component, region, layer or section discussed herein could be termed a second element, component, region, layer or section without departing from the teachings of the example embodiments.', 'When an element or layer is referred to as being “on,” “engaged to,” “connected to,” or “coupled to” another element or layer, it may be directly on, engaged to, connected to, coupled to the other element or layer, or interleaving elements or layers may be present.', 'In contrast, when an element is referred to as being “directly on,” “directly engaged to,” “directly connected to,” or “directly coupled to” another element or layer, there may be no interleaving elements or layers present.', 'Other words used to describe the relationship between elements should be interpreted in a like fashion.', 'As used herein, the term “and/or” includes any and all combinations of one or more of the associated listed terms.', 'Some embodiments will now be described with reference to the figures.', 'Like elements in the various figures will be referenced with like numbers for consistency.', 'In the following description, numerous details are set forth to provide an understanding of various embodiments and/or features.', 'It will be understood, however, by those skilled in the art, that some embodiments may be practiced without many of these details, and that numerous variations or modifications from the described embodiments are possible.', 'As used herein, the terms “above” and “below”, “up” and “down”, “upper” and “lower”, “upwardly” and “downwardly”, and other like terms indicating relative positions above or below a given point are used in this description to more clearly describe certain embodiments.', 'Abnormally hard, wear and corrosion resistant fusible alloys for casting, welding, powder metallurgy, and additive manufacturing tailored to oilfield Exploration & Production environments are disclosed.', 'The novel alloys are hardened by gamma prime (Ni,Co)\nx\n(Cr\na\n,Al\nb\n,M\nc\n) intermetallic phases upon low-temperature heat treatments to ensure unusual crack-free deposits with highly unusual hardness (typically 50 to 65 HRC).', 'These alloys can replace the Co—Cr alloys and in applications can compete with the carbide-metal cermets, yet are normally carbide-free, non-magnetic and exhibit superior corrosion resistance.', 'The alloys, when shaped by the disclosed processes, can be used in flow diverters, pump stages (impellers, diffusers), turbines, blenders, chokes, valve trunnions, cages, seats, ICDs, pads, bushings, bearings, stabilizers, wear bands, as well as claddings to low-alloy steels and normal corrosion-resistant alloys (CRAs), for instance for the internal and external surfaces of pressure housings.', 'These alloys may also be applied as binder to ceramics, including tungsten carbides (e.g., 60% WC+40% of the novel alloy), for instance for drilling bearing applications.', 'Claimed are inventive alloys of nickel (Ni) with 28.0 to 36.0 wt. % chromium (Cr), 3.10 to 5.10 wt. % aluminum (Al), 0.25 to 3.50 wt', '. % molybdenum (Mo), optionally up to 2.0 wt. % cobalt (Co) and 2.0 wt.', '% tungsten (W), and their methods of use in oilfield parts and products.', 'Aspects of the disclosure provide crack-free fusible alloys with unusual hardness values compared to commercially available materials after heat-treatment.', 'The alloys have been designed per a set of criteria derived from computational materials design first, then reduced order regression models.', 'The following was used as criteria: \n \n \n \nMinimal number of intermetallic phases between 450 to 600° C., with a preference for \n \n450 to 600° C. is a proprietary heat-treatment, not detailed in the herein disclosure\n \n \n \n% Gamma Prime:', 'Measures the percentage of the gamma prime intermetallic phase forming under equilibrium (vert slow cooling) conditions between 450 and 600° C., with an inclination for values between 30% and 70%\n \nSigma and Mu phases: A strong preference for a total absence of Sigma and Mu intermetallic phases in the 450 to 600° C.\n \n% Gamma prime at 900° C.:', 'Measures the percentage of Gamma phase at 900° C., with a preference for less than 30%', '%', 'Gamma at 900° C.:', 'Measures the percentage of gamma phase at 900° C., with an inclination for values more than 70%', '%', 'Beta Cr at 900° C.: Relates to the percentage the chromium bcc phase forming under equilibrium with values at a temperature of 900° C., with a preference for less than 25 wt.', '%\n \nNi\n2\nM onset temperature in ° C.:', 'Relates to the temperature at which the Ni\n2\nM intermetallic phase forms, with a preference for onset temperature below 550° C.\n \nLiquidus and solidus temperatures: Preference to have them as possible to each other to promote a narrow freezing range\n \n \n \n \n \nFIG.', '2\n shows a laser deposited & fused alloy that is fulfilling many of the above criteria.', 'It may be seen on the left that the deposit, from additive manufacturing, is crack-free.', 'Upon heat-treatment, the alloy is also seen to harden from less than 22 to 58 Rockwell hardness, and still maintain a crack-free microstructure, including along the interface with the base material (right picture).', 'Referring to \nFIG.', '3\nA\n, blocks of alloy material satisfying the requirements of the disclosures, is illustrated.', 'In this figure, the blocks of material were prepared using an additive manufacturing process.', 'Referring to \nFIG.', '3\nB\n, an interface between alloy material and a low-alloy steel substrate is illustrated.', 'In this illustration, cracks are not present.', 'Referring to \nFIG.', '3\nC\n, a plot showing an equilibrium phase diagram is presented.', 'Phases are shown that are present between ambient and melting.', 'Designated by circles are some of the above design criteria, with the above alloy establishing a “benchmark” that has been successfully constructed.\n \nFIG.', '4\n is a list of inventive alloys largely designed based on a first experimental trial, then strict criteria as earlier described, and various iterations of Design of Experiments utilizing computational thermodynamics (full factorial DOE).', 'The results presented in the next tables are solely computational, and rely on key attributes from the successful manufacturing and testing of the alloy of \nFIG.', '2\n.', 'Unlike prior-art, this invention uses Mo and W as mean to specifically improve corrosion resistance for oilfield services, while Cr and Al are still in use in the disclosed ratio to promote the hard gamma prime phase.', 'Experimental trials on alloys herein disclosed are ongoing, with results later available for inclusion if needed.\n \nFIG.', '5\n is a list of the alloys of \nFIG.', '4\n with the addition of Mo and the physical effects of this placement.\n \nFIG.', '6\n is a list that investigates the role of W, as partial substitute or complementary to Mo, and aims at also reducing the Ni\n2\nM onset temperature below 500° C.\n \nFIG.', '7\n is a semi-optimized figure of alloys per the disclosed criteria; i.e., offers increased gamma prime at lower temperature, has reduced Mu phase formation temperature (i.e., more heat-treatable, as desired), offers a wide range of high-temperature gamma phase, and has a composition that comprises Mo and W.\n \nBoth Mo and W are well known to contribute to corrosion resistance.', 'Their inclusion as an Ni Cr Al composition is novel, and simply driven by the oilfield methods of use.', 'Super-alloys have traditionally been developed for the aerospace, where corrosion is not a primary concern.', 'In this figure, a graph of weight percentage vs temperature is illustrated, with highlighted areas, indicating where example embodiments of the disclosure are present.', 'In one example embodiment, an environmentally resistant alloy material, is disclosed.', 'The material may comprise a transition metal that upon being included in the Ni Cr Al alloy causes no liquid phases below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310° C., creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., and wherein the gamma prime phase is characterized by a formula (Ni,Co)\nx\n(Cr,Al,Mo)\ny \nwherein x and y are integers.', 'In another example embodiment, the material may be configured wherein the transition metal is cobalt.', 'In another example embodiment, the material may be configured wherein the transition metal is molybdenum.', 'In another example embodiment, the material may be configured wherein the transition metal is tungsten.', 'In another example embodiment, the material may be configured wherein the Ni is greater than or equal to 55 weight percent, the Cr is greater than or equal to 28 weight percent and up to 36 weight percent; the Al is greater than or equal to 3.1 weight percent and up to 5.1 weight percent, and the Mo is up to 3.5 weight percent.', 'In another example embodiment, the material may be configured wherein the W is up to 2.0 weight percent.', 'In another example embodiment, the material may be configured wherein the Ni is greater than or equal to 61 weight percent, the Cr is greater than or equal to 30 weight percent and up to 34 weight percent; the Al is greater than or equal to 4 weight percent and up to 5.1 weight percent, the Mo is up to 3.5 weight percent and the W is up to 3.5 weight percent.', 'In another example embodiment, the material may be configured wherein the alloy is less than 35 HRC in hardness before heat treatment.', 'In another example embodiment, the material may be configured wherein the alloy is greater than 50 HRC in hardness after a heat treatment.', 'In another example embodiment, a cermet material is disclosed comprising a ceramic matrix and a Ni Cr Al alloy binder placed within the ceramic matrix, the alloy binder may comprise a transition metal that upon being included in the Ni Cr Al alloy causes no liquid phase below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310', '° C., and creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., wherein the gamma prime phase is characterized by a formula (Ni,Co)\nx\n(Cr,Al,Mo)', 'y \nwherein x and y are integers.', 'In another example embodiment, the alloy binder may be configured wherein the transition metal is cobalt.', 'In another example embodiment, the alloy binder may be configured wherein the transition metal is molybdenum.', 'In another example embodiment, the alloy binder may be configured wherein the transition metal is tungsten.', 'In another example embodiment, the alloy binder may be configured wherein the Ni is greater than or equal to 55 weight percent, the Cr is greater than or equal to 28 weight percent and up to 36 weight percent, the Al is greater than or equal to 3.1 weight percent and up to 5.1 weight percent, and the Mo is up to 3.5 weight percent.', 'In another example embodiment, an alloy is disclosed comprising a tungsten carbide matrix and a Ni Cr Al alloy binder placed within the tungsten carbide matrix, the alloy binder may comprise a transition metal that upon being included in the Ni Cr Al alloy causes no liquid phases below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310', '° C., and creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., wherein the gamma prime phase is characterized by a formula (Ni,Co)\nx\n(Cr,Al,Mo)', 'y \nwherein x and y are integers.', 'In another example embodiment, the alloy binder may be configured wherein the transition metal is cobalt.', 'In another example embodiment, the alloy binder may be configured wherein the transition metal is molybdenum.', 'In another example embodiment, the alloy binder may be configured wherein the transition metal is tungsten.', 'In another example embodiment, the alloy binder may be configured wherein the Ni is greater than or equal to 55 weight percent, the Cr is greater than or equal to 28 weight percent and up to 36 weight percent; the Al is greater than or equal to 3.1 weight percent and up to 5.1 weight percent, and the Mo is up to 3.5 weight percent.', 'The foregoing description, for purpose of explanation, has been described with reference to specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or to limit the disclosure to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'The embodiments were chosen and described in order to best explain the principles of the present systems and methods and their practical applications, to thereby enable others skilled in the art to best utilize the present systems and methods and various embodiments with various modifications as may be suited to the particular use contemplated.']

['1.', 'A cermet material, comprising:\na ceramic material; and\nan alloy material comprising a transition metal included in a Ni Cr Al alloy that causes no liquid phase below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310° C., and creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., and the gamma prime phase is characterized by a formula (Ni,Co)x(Cr,Al,Mo)y, wherein x and y are integers, wherein an amount of the Al in the alloy material is 3.1 weight percent to 5.1 weight percent, wherein the transition metal comprises at least one of Co, Mo, and W, wherein a weight percent of the alloy material in the cermet material is 40%, and wherein a ratio of an amount of the ceramic material to an amount of the alloy material is less than 1.5.\n\n\n\n\n\n\n2.', 'The cermet material of claim 1, wherein:\nthe transition metal comprises Mo,\nan amount of the Ni in the alloy material is greater than or equal to 55 weight percent,\nan amount of the Cr in the alloy material is greater than or equal to 28 weight percent and up to 36 weight percent,\nan amount of the Mo in the alloy material is up to 3.25 weight percent, and the alloy material is free of W.\n\n\n\n\n\n\n3.', 'The cermet material of claim 1, wherein:\nthe transition metal comprises Mo and W,\nan amount of the Ni in the alloy material is greater than or equal to 55 weight percent,\nan amount of the Cr in the alloy material is greater than or equal to 28 weight percent and up to 36 weight percent,\nan amount of the Mo in the alloy material is up to 2 weight percent, and\nan amount of the W in the alloy material is up to 2 weight percent.', '4.', 'The cermet material of claim 1, wherein the alloy material is 300 HVN in hardness before heat treatment, and wherein the alloy material is greater than 500 HVN in hardness after the heat treatment.', '5.', 'A cermet material comprising:\nceramic particulates; and\nan alloy binder placed within the ceramic particulates, the alloy binder comprising a transition metal included in a Ni Cr Al alloy causes no liquid phase below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310', '° C., and creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., wherein the gamma prime phase is characterized by a formula (Ni,Co)x(Cr,Al,Mo)y wherein x and y are integers, wherein an amount of the Al in the alloy binder is 3.1 to 5.1 weight percent, wherein the transition metal comprises at least one of Co, Mo and W, wherein a weight percent of the alloy binder in the cermet material is 40%, and wherein a weight ratio of the ceramic particulates to the alloy binder is 1.5 or less.', '6.', 'The cermet material of claim 5, wherein:\nthe transition metal comprises Mo,\nan amount of the Ni in the alloy binder is greater than or equal to 55 weight percent,\nan amount of the Cr in the alloy binder is greater than or equal to 28 weight percent and up to 36 weight percent,\nan amount of the Mo in the alloy binder is up to 3.25 weight percent, and\nthe alloy binder is free of W.\n\n\n\n\n\n\n7.', 'A cermet material, comprising:\ntungsten carbide particulates; and\nan alloy binder placed within the tungsten carbide particulates, the alloy binder comprising a transition metal included in a Ni Cr Al alloy that causes no liquid phase below 1310° C., creates over 45% of a gamma phase above 900° C. up to 1310° C., and creates over 30% comprised of a gamma prime phase between 450° C. and 600° C., wherein the gamma prime phase is characterized by a formula (Ni,Co)x(Cr,Al,Mo)y wherein x and y are integers, wherein an amount of the Al in the alloy binder is 3.1 to 5.1 weight percent, wherein the transition metal comprises at least one of Co, Mo, and W, wherein a weight percent of the alloy binder in the cermet material is 40%, and wherein a weight ratio of the tungsten carbide particulates to the alloy binder is 1.5 or less.', '8.', 'The cermet material of claim 7, wherein:\nthe transition metal comprises Mo,\nan amount of the Ni in the alloy binder is greater than or equal to 55 weight percent,\nan amount of the Cr in the alloy binder is greater than or equal to 28 weight percent and up to 36 weight percent,\nan amount of the Mo is up to 3.25 weight percent, and the alloy binder is free of W.\n\n\n\n\n\n\n9.', 'The cermet material of claim 1, wherein an amount of the Ni in the alloy material is 61 weight percent to 63.65 weight percent.', '10.', 'The cermet material of claim 1, wherein an amount of the Cr in the alloy material is 32 weight percent to 36 weight percent.', '11.', 'The cermet material of claim 1, wherein:\nthe transition metal comprises Mo and W,\nan amount of the Mo in the alloy material is up to 2.25 weight percent, and\nan amount of the W in the alloy material is up to 2 weight percent.', '12.', 'The cermet material of claim 1, wherein:\nthe alloy material is free of W,\nthe transition metal comprises Mo, and\nan amount of the Mo in the alloy material is up to 3.25 weight percent.', '13.', 'The cermet material of claim 1, wherein:\nthe alloy material is free of W,\nthe transition metal comprises Mo, and\nan amount of the Mo in the alloy material is up to 3 weight percent.', '14.', 'The cermet material of claim 1, wherein:\nthe alloy material is free of W,\nthe transition metal comprises Mo, and\nan amount of the Mo in the alloy material is up to 2.5 weight percent.', '15.', 'The cermet material of claim 1, wherein:\nthe transition metal comprises Mo and optionally W,\nan amount of the Cr in the alloy material is 32 weight percent to 36 percent,\nan amount of the Mo in the alloy material is up to 2.5 weight percent, and\nif the W is present in the alloy material, an amount of the W in the alloy material is up to 2 weight percent.', '16.', 'The cermet material of claim 1, wherein:\nthe transition metal comprises Co and Mo,\nthe alloy material is free of W,\nan amount of the Co in the alloy material is up to 2 weight percent, and\nan amount of the Mo in the alloy material is up to 3.25 weight percent.', '17.', 'The cermet material of claim 1, wherein:\nthe transition metal comprises Co, Mo, and W,\nan amount of the Co in the alloy material is up to 2 weight percent,\nan amount of the Mo in the alloy material is up to 2.25 weight percent, and\nan amount of the W in the alloy material is up to 2 weight percent.', '18.', 'The cermet material of claim 5, wherein a weight percent of the ceramic particulates in the cermet material is 60% or less.', '19.', 'The cermet material of claim 7, wherein a weight percent of the tungsten carbide particulates in the cermet material is 60% or less.', '20.', 'The cermet material of claim 1, wherein a weight percent of the ceramic material is 60%.']

['FIG.', '1 is a depiction of a prior art laser deposited hard alloy used in conventional applications.; FIG.', '2 is a comparison of major material properties.;', 'FIG.', '3A illustrates blocks of material produced by additive manufacturing.; FIG.', '3B illustrates an interface between an aspect of the disclosure and a low alloy steel substrate.; FIG.', '3C is a graph of an equilibrium phase diagram for an aspect of the disclosure described.', '; FIG.', '4 is a list of alloys in accordance with one example embodiment of the disclosure.', '; FIG.', '5 is a list of the alloys of FIG.', '4 with the addition of Mo and the physical effects of this placement.;', 'FIG. 6 is a list of alloys that investigates the role of W, as partial substitute or complementary to Mo.; FIG. 7 is a graph of weight percent phase vs. temperature of alloys in accordance with an example embodiment of the disclosure.; FIG.', '2 shows a laser deposited & fused alloy that is fulfilling many of the above criteria.', 'It may be seen on the left that the deposit, from additive manufacturing, is crack-free.', 'Upon heat-treatment, the alloy is also seen to harden from less than 22 to 58 Rockwell hardness, and still maintain a crack-free microstructure, including along the interface with the base material (right picture).;', 'FIG. 4 is a list of inventive alloys largely designed based on a first experimental trial, then strict criteria as earlier described, and various iterations of Design of Experiments utilizing computational thermodynamics (full factorial DOE).', 'The results presented in the next tables are solely computational, and rely on key attributes from the successful manufacturing and testing of the alloy of FIG.', '2.', 'Unlike prior-art, this invention uses Mo and W as mean to specifically improve corrosion resistance for oilfield services, while Cr and Al are still in use in the disclosed ratio to promote the hard gamma prime phase.', 'Experimental trials on alloys herein disclosed are ongoing, with results later available for inclusion if needed.; FIG.', '5 is a list of the alloys of FIG.', '4 with the addition of Mo and the physical effects of this placement.;', 'FIG. 6 is a list that investigates the role of W, as partial substitute or complementary to Mo, and aims at also reducing the Ni2M onset temperature below 500° C.; FIG. 7 is a semi-optimized figure of alloys per the disclosed criteria; i.e., offers increased gamma prime at lower temperature, has reduced Mu phase formation temperature (i.e., more heat-treatable, as desired), offers a wide range of high-temperature gamma phase, and has a composition that comprises Mo and W.']

US11919087

Hot isostatic pressing (HIP) fabrication of multi-metallic components for pressure-controlling equipment

May 24, 2021

Micah Threadgill, Terry Clancy, Herman Ernesto Amaya, Christopher Nault

SCHLUMBERGER TECHNOLOGY CORPORATION

ASM (Ultrahigh-Strength Steels, ASM Handbook, vol. 1990) (Year: 1990).; Azom (“W1 Tool Steel-Water-Hardenino Tool Steel (UNS -72301)” Jul. 16, 2013, AZoNetwork. Accessed Aug. 22, 2022) (Year: 2013).; Butrim et al. (“Experience in HIP diffusion welding of dissimilar metals and alloys.” Proceedings of 12th International Conference on Hot Isostatic Pressing—HIP. vol. 17. 2019.) (Year: 2019).; Lindwall et al., “Experimental and Theoretical Investigations of Hot Isostatically Pressed-Produced Stainless Steel/High Alloy Tool Steel Compound Materials”, Metallurgical and Materials Transactions, vol. 42A, May 2011, pp. 1165-1172.; International Search Report and Written Opinion issued in International Patent application PCT/US2021/072935 dated Apr. 11, 2022, 10 pages.; Jacobs, “Surface engineering of materials”, Materials & Design, Jan. 1, 1993, vol. 14, No. 1, pp. 33-37.; International Preliminary Report on Patentability issued in PCT Application No. PCT/US2021/072935 dated Jun. 29, 2023, 7 pages.

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['A multi-metallic pressure-controlling component and a hot isostatic pressure (HIP) manufacturing process and system are disclosed.', 'An example multi-metallic ram includes a first portion formed from a first metal alloy, a second portion formed from a second metal alloy, and a diffusion bond at an interface between the first metal alloy and the second metal alloy that joins the first metal alloy to the second metal alloy within the multi-metallic ram.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application is a continuation of U.S. application Ser.', 'No. 17/123,186, filed on Dec. 16, 2020, and entitled “HOT ISOSTATIC PRESSING (HIP) FABRICATION OF MULTI-METALLIC COMPONENTS FOR PRESSURE-CONTROLLING EQUIPMENT,” which is hereby incorporated by reference in its entirety for all purposes.', 'BACKGROUND\n \nThis section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'A blowout preventer (BOP) is installed on a wellhead to seal and control an oil and gas well during various operations.', 'For example, during drilling operations, a drill string may be suspended from a rig through the BOP into a wellbore.', 'A drilling fluid is delivered through the drill string and returned up through an annulus between the drill string and a casing that lines the wellbore.', 'In the event of a rapid invasion of formation fluid in the annulus, commonly known as a “kick,” the BOP may be actuated to seal the annulus and to contain fluid pressure in the wellbore, thereby protecting well equipment positioned above the BOP.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein:\n \nFIG.', '1\n is a block diagram of a drilling system for mineral extraction, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\n is a cross-sectional top view of a portion of a blowout preventer (BOP) that may be used in the drilling system of \nFIG.', '1\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '3\n is a front isometric view of a component, namely an upper ram, that may be used in the BOP of \nFIG.', '2\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '4\n is a front isometric view of another component, namely a lower ram, that may be used in conjunction with the upper ram of \nFIG.', '3\n and the BOP of \nFIG.', '2\n, in accordance with an embodiment of the present disclosure;\n \nFIGS.', '5\n, \n6\n, \n7\n, and \n8\n are cross-sectional views of the components of \nFIGS.', '3\n and \n4\n, in accordance with various embodiments of the present disclosure;\n \nFIG.', '9\n is a block diagram of a hot isostatic pressure (HIP) manufacturing system that is configured to carry out a HIP manufacturing process to fabricate the components of \nFIGS.', '3\n and \n4\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '10\n is a flow diagram of the HIP manufacturing process, in accordance with an embodiment of the present disclosure; and\n \nFIGS.', '11\nA, \n11\nB, and \n11\nC\n are cross-sectional views of portions of a loaded canister prior to a HIP process of the HIP manufacturing process, in accordance with an embodiment of the present disclosure.', 'DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS\n \nOne or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only exemplary of the present disclosure.', 'Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Present embodiments are generally directed to systems and methods for the hot isostatic pressing (HIP) fabrication of components for use in the oil field services industry, which may relate generally to any activities (e.g., drilling, producing, monitoring, and/or maintaining) that facilitate access to and/or extraction of natural resources (e.g., hydrocarbons) from the earth.', 'The components may be any of a variety of components for use in equipment, such as pressure-containing and/or pressure-controlling equipment.', 'Present embodiments enable the production of multi-metallic (e.g., bimetallic, trimetallic) components, such as pressure-containing components and/or pressure-controlling components.', 'An example embodiment includes a HIP-fabricated multi-metallic ram of a blowout preventer (BOP).', 'A traditional BOP ram is fabricated using a subtractive manufacturing technique in which a forged block of a particular metal alloy is precisely machined into a complex shape, and then a number of conventional and unconventional heat treatments are performed to impart different material properties to different portions of the part.', 'As used herein, the term metal alloy refers to either a pure metal or a metallic solid solution including a number of different metallic and/or non-metallic chemical elements.', 'In contrast, present embodiments involve the use of a HIP-fabrication process in which different metal alloys (e.g., different metal alloy powders, different metal alloy boundary layers) are combined and sealed in a canister before being heated and pressurized during a HIP process (e.g., in an autoclave) to form a multi-metallic pressure-controlling component (e.g., a BOP ram).', 'As a result, the different metal alloys are disposed in different portions of the part to impart different material properties to these portions of the part (e.g., higher strength and hardness in a blade area of the ram, higher toughness in the body of the ram).', 'Additionally, a finite (e.g., narrow) diffusion bond forms at the interface between different metal alloys, yielding a dense, seamless pressure-controlling component.', 'It is presently recognized that the disclosed HIP manufacturing process enables substantially greater freedom of design by enabling the joining of metal alloys that may be chemically incompatible using traditional joining methods (e.g., welding).', 'Additionally, by using different metal alloys in different portions of the part, a greater range of material properties (e.g., strength, toughness, ductility, hardness, corrosion resistance) is available compared to the range of material properties achievable using a traditional, single metal alloy ram with multiple thermal processing steps.', 'Within the HIP manufacturing process, a HIP process chemically bonds powder metal into a solid part under “extreme” temperature and pressure.', 'After the HIP process is complete, the final part may be achieved with reduced processing time, compared with the traditional manufacturing techniques.', 'For example, after the HIP process has been applied to join the metal powders of the multi-metallic part, the final part may be realized with reduced machining time, with little or no welding, and without special heat treatment processes of traditional manufacturing techniques, thereby reducing manufacturing time and cost relative to traditional manufacturing techniques.', 'Furthermore, the disclosed HIP manufacturing process generally provides the capability to efficiently construct pressure-controlling equipment components having a complex shape while avoiding or reducing time-consuming and/or costly complex thermal processing, welding, and/or machining steps.', 'While the present embodiments are described in the context of a ram of a BOP for a drilling system to facilitate discussion, it should be appreciated that the systems and methods for HIP fabrication of multi-metallic components may be adapted for fabrication of other equipment, such as another component of the BOP for the drilling system and/or another component of another device for any type of system (e.g., drilling system, production system).', 'With the foregoing in mind, \nFIG.', '1\n is a block diagram of an embodiment of a drilling system \n10\n for mineral extraction.', 'The drilling system \n10\n may be configured to drill (e.g., circulate drilling mud and take drilling cuttings up to surface) for the eventual extraction of extract various minerals and natural resources, including hydrocarbons (e.g., oil and/or natural gas), from the earth and/or to inject substances into the earth.', 'The drilling system \n10\n may be a land-based system (e.g., a surface system) or an offshore system (e.g., an offshore platform system).', 'As shown, a BOP stack \n12\n may be mounted to a wellhead \n14\n, which is coupled to a mineral deposit \n16\n via a wellbore \n18\n.', 'The wellhead \n14\n may include or be coupled to any of a variety of other components such as a spool, a hanger, and a “Christmas” tree.', 'The wellhead \n14\n may return drilling fluid or mud toward a surface during drilling operations, for example.', 'Downhole operations are carried out by a conduit \n20\n (e.g., drill string) that extends through a central bore \n22\n of the BOP stack \n12\n, through the wellhead \n14\n, and into the wellbore \n18\n.', 'As discussed in more detail below, the BOP stack \n12\n may include one or more BOPs \n24\n (e.g., ram BOPs), and component (e.g., rams) of the one or more BOPs \n24\n may be manufactured using systems and methods for HIP fabrication disclosed herein.', 'To facilitate discussion, the BOP stack \n12\n and its components may be described with reference to a vertical axis or direction \n30\n, an axial axis or direction \n32\n, and/or a lateral axis or direction \n34\n.', 'FIG.', '2\n is a cross-sectional top view of a portion of an embodiment of the BOP \n24\n that may be used in the drilling system \n10\n of \nFIG.', '1\n, in accordance with an embodiment of the present disclosure.', 'As shown, the BOP \n24\n includes opposed rams \n50\n, including upper ram \n50\nA and lower ram \n50\nB, also generally referred to herein as pressure-controlling components \n26\n or multi-metallic pressure-controlling components \n26\n of the BOP \n24\n.', 'In the illustrated embodiment, the opposed rams \n50\n are in an open configuration \n54\n of the BOP \n24\n in which the opposed rams \n50\n are withdrawn from the central bore \n22\n, do not contact the conduit \n20\n, and/or do not contact one another.', 'As shown, the BOP \n24\n includes a bonnet flange \n56\n surrounding the central bore \n22\n.', 'The bonnet flange \n56\n is generally rectangular in the illustrated embodiment, although the bonnet flange \n56\n may have any cross-sectional shape, including any polygonal shape and/or annular shape.', 'Bonnet assemblies \n60\n are mounted on opposite sides of the bonnet flange \n56\n (e.g., via threaded fasteners).', 'Each bonnet assembly \n60\n includes an actuator \n62\n, which may include a piston \n64\n and a connecting rod \n66\n.', 'The actuators \n62\n may drive the opposed rams \n50\n toward one another along the axial axis \n32\n to reach a closed position in which the opposed rams \n50\n are positioned within the central bore \n22\n, contact and/or shear the conduit \n20\n to seal the central bore \n22\n, and/or contact one another to seal the central bore \n22\n.', 'Each of the opposed rams \n50\n may include a body section \n68\n (e.g., ram body), a leading surface \n70\n (e.g., side, portion, wall) and a rearward surface \n72\n (e.g., side, portion, wall, rearmost surface).', 'The leading surfaces \n70\n may be positioned proximate to the central bore \n22\n and may face one another when the opposed rams \n50\n are installed within the housing \n56\n.', 'The rearward surfaces \n72\n may be positioned distal from the central bore \n22\n and proximate to a respective one of the actuators \n62\n when the opposed rams \n50\n are installed within the housing \n56\n.', 'The leading surfaces \n70\n may be configured to couple to and/or support sealing elements (e.g., elastomer or polymer seals) that are configured to seal the central bore \n22\n in the closed position, and the rearward surfaces \n72\n may include an attachment interface \n74\n (e.g., recess) that is configured to engage with the connecting rod \n66\n of the actuator \n62\n.', 'The body section \n68\n also includes lateral surfaces \n76\n (e.g., walls) that are on opposite lateral sides of the body section \n68\n and that extend along the axial axis \n32\n between the leading surface \n70\n and the rearward surface \n72\n.', 'In \nFIG.', '2\n, the opposed rams \n50\n have a generally rectangular shape to facilitate discussion; however, it should be appreciated that the opposed rams \n50\n may have any of a variety of shapes or features (e.g., curved portions to seal against the conduit \n20\n, edges to shear the conduit \n20\n).', 'FIG.', '3\n is a front isometric view of an embodiment of the upper ram \n50\nA, and \nFIG.', '4\n is a front isometric view of an embodiment of the lower ram \n50\nB, which may be used together as pressure-controlling components \n26\n in the embodiment of BOP \n24\n of \nFIG.', '2\n.', 'As illustrated in \nFIGS. \n3\n and \n4\n, the pressure-controlling components \n26\n each include the body section \n68\n and a blade section \n69\n.', 'Each blade section \n69\n includes the leading surface \n70\n, while the body section \n68\n includes the rearward surface \n72\n of the rams \n50\n.', 'Because the rams \n50\n of \nFIGS.', '3\n and \n4\n are shear rams, each blade section \n69\n includes a respective edge portion \n77\n that is formed in the leading surface \n70\n and that extends along the lateral axis \n34\n of each of the rams \n50\n.', 'In a closed configuration, the respective edge portions \n77\n of the upper ram \n50\nA and the lower ram \n50\nB are configured to shear the conduit \n20\n and/or support the seal elements that seal against the central bore \n22\n of the BOP illustrated in \nFIG.', '2\n.', 'However, it should be appreciated that the rams \n50\n may have any of a variety of other configurations (e.g., the rams \n50\n may be pipe rams that lack the respective edge portions \n77\n).', 'The blade section \n69\n of each of the rams \n50\n of \nFIGS.', '3\n and \n4\n also includes a leading cutout \n78\n formed in the leading surfaces \n70\n (e.g., positioned above and below the respective edge portion \n77\n along the vertical axis \n30\n).', 'The leading surface \n70\n, the rearward surface \n72\n, the lateral surfaces \n76\n, a top surface \n82\n (e.g., top-most surface), and a bottom surface \n84\n (e.g., bottom-most surface) may be considered the respective outer surfaces of the rams \n50\n.', 'For the illustrated rams \n50\n, the outer surfaces include grooves or channels \n86\n.', 'In certain embodiments, at least a portion of these grooves may be sealing grooves designed to receive or interface with a polymeric material (e.g., an elastomeric seal), while a portion of these grooves may be sliding grooves designed to receive a slide along a metallic extension during operation of the BOP.', 'For the pressure-controlling components \n26\n illustrated in \nFIGS.', '3\n and \n4\n, at least the body section \n68\n and the blade section \n69\n have a different metal alloy composition (e.g., a different chemical composition).', 'For example, in certain embodiments, the body section \n68\n of the rams \n50\n may be made of a first metal alloy, while at least a portion of the blade section \n69\n (e.g., an outer surface) is made of a second metal alloy.', 'The various metal alloys of the pressure-controlling components \n26\n may be selected for desirable material properties, including but not limited to: toughness, percent elongation, percent reduction of area, tensile strength, yield strength, impact strength, ductility, hardness, and corrosion resistance.', 'A non-limiting list of example metal alloys includes, but is not limited to: chromium-molybdenum (Cr—Mo) steels (e.g., Unified Numbering System (UNS) G41300, UNS G41400, UNS K21590); chromium-nickel-molybdenum (Cr—Ni—Mo) steels (e.g., UNS G43400); maraging (also known as martensitic-aged) steels (e.g., UNS K91973, UNS K44220, UNS K93120); super martensitic stainless steels (e.g., Euronorm (EN) 1.4418, UNS S41425, UNS S41426, UNS S41427); precipitation-hardened nickel alloys (e.g., UNS N07718, UNS N09946); precipitation-hardened martensitic steels (e.g., UNS S35000, UNS S17400); solution-annealed nickel alloys (e.g., UNS N06625, UNS N08825); tool steels (e.g., UNS T41907, UNS T30402, UNS T20813); cobalt or nickel-bound tungsten-carbides, nickel-cobalt (Ni—Co) alloys (e.g. UNS R30035); and cobalt-chromium (Co—Cr) alloys (e.g. UNS R30006).', 'In certain embodiments, one or more of the metal alloys of the pressure-controlling components \n26\n may be compliant with the National Association of Corrosion Engineers (NACE) MR0175 standard (also referred to as ISO 15156), which is a materials standard intended to assess the suitability of materials for oil and gas applications in which where sulfide stress corrosion cracking may be a risk in hydrogen sulfide-rich (sour) environments.\n \nFIG.', '5\n is a cross-sectional view of an embodiment of the upper ram \n50\nA illustrated in \nFIG.', '3\n.', 'For the illustrated embodiment, the blade section \n69\n of illustrated upper ram \n50\nA is made of a first metal alloy \n94\n.', 'The body section \n68\n includes a first portion \n68\nA that is made of a second metal alloy \n96\n and a second portion \n68\nB that is made of a third metal alloy \n98\n, resulting in a substantially trimetallic upper ram \n50\nA.', 'In some embodiments, both portions of the body section \n68\n may only include a single metal alloy, resulting in a substantially bimetallic upper ram \n50\nA, in which the blade section \n69\n and the body section \n68\n each are made entirely of a different respective metal alloy.', 'The metal alloys of the pressure-controlling component \n26\n (e.g., metal alloys \n94\n, \n96\n, \n98\n) may be selected based on a number of criteria.', 'For example, for the embodiment illustrated in \nFIG.', '5\n, it may be desirable for the blade section \n69\n to have a greater strength (e.g., a tensile and/or yield strength that is at least 5 percent greater, at least 10 percent greater, at least 20 percent greater, 200 percent greater, 250 percent greater, 300 percent greater) than that of the body section \n68\n.', 'Additionally or alternatively, it may be desirable for the body section \n68\n to have a greater toughness (e.g., a percent elongation and/or percent reduction in area that is at least 5 percent greater, at least 10 percent greater, at least 20 percent greater, 200 percent greater, 250 percent greater, 300 percent greater) than that of the blade section \n69\n.', 'This can result in the formation of rams \n50\n having a stronger blade section \n69\n, while also having a tougher, more ductile, and more resilient body section \n68\n.', 'As such, for the embodiment illustrated in \nFIG.', '5\n, the first metal alloy \n94\n that forms the blade section \n69\n may be selected based on having a suitably higher strength relative to the second metal alloy \n96\n that forms at least a substantial portion of the body section \n68\n.', 'For embodiments that include the second boundary and the third metal alloy \n98\n, the third metal alloy may be selected based on having a higher corrosion resistance relative to the second metal alloy \n96\n.', 'For example, in an example embodiment, the blade section \n69\n may be formed using a high-alloy steel alloy \n94\n, which has relatively higher strength; the first portion \n68\nA of body section \n68\n may be formed using low-alloy steel \n96\n, which has a relatively higher toughness; and the second portion \n68\nB of the body section \n68\n may be formed using a high-chrome or high-nickel steel \n98\n, which has relatively higher corrosion resistance.', 'While corrosion resistance may be desirable when the second portion \n68\nB of the body section \n68\n will contact a elastomer or polymer seal, for embodiments in which the second portion \n68\nB will contact and slide against a metallic surface during operation, the second portion \n68\nB may instead be formed from a metal alloy having a relatively greater hardness (e.g., at least 5 percent greater hardness, at least 10 percent greater hardness), which can improve sliding against the metallic part (e.g., reducing or preventing galling, reducing wear).', 'Additionally, the selected metal alloys should be compatible with one another for the HIP process.', 'In other words, in certain embodiments, certain material properties of the selected metal alloys (e.g., melting point, sintering point) should be similar (e.g., within a predetermined threshold), such that simultaneous, preferential microstructural develops in each material during a single HIP process, as discussed below.', 'Additionally, the embodiment of the upper ram \n50\nA illustrated in \nFIG.', '5\n includes planar (e.g., straight, flat) boundaries or interfaces \n100\n, at which the two different metal alloys meet and join via a narrow (e.g., less than 5 millimeter, less than 3 millimeter, about 1 millimeter) diffusion bond, which may also be referred to as the diffusion bond zone.', 'For the embodiment of \nFIG.', '5\n, these boundaries \n100\n include a first boundary \n100\nA disposed between the blade section \n69\n and the first portion \n68\nA of the body section \n68\n, as well as a second boundary \n100\nB disposed between the first portion \n68\nA and the second portion \n68\nB of the body section \n68\n.', 'For the illustrated embodiment, the boundaries \n100\n are aligned with planes oriented in the vertical and lateral directions (e.g., along a plane defined by axes \n30\n and \n34\n).', 'In certain embodiments, as discussed below, a thin boundary layer may be present along the interface \n100\n and be made of a metal alloy that is the same as or different from the metal alloys present on either side of the boundaries \n100\n.', 'For clarity, since the boundary layer contributes little to the overall composition of the upper ram \n50\nA, the upper ram \n50\nA illustrated in \nFIG.', '5\n may be described herein as being “substantially trimetallic,” meaning that it predominantly includes only metal alloys \n94\n, \n96\n, and \n98\n, even when boundary layers are used having different compositions relative to the metal alloys \n94\n, \n96\n, and \n98\n.', 'It may be appreciated that, for certain embodiments of pressure-controlling components \n26\n, it may be desirable for the diffusion bonds at the boundaries \n100\n to demonstrate certain features or material properties.', 'For example, in certain embodiments, the strength (e.g., tensile strength, yield strength) at each interface \n100\n between different metal alloys is greater than the strength of the material that is used to form at least a substantial portion of the body \n68\n.', 'For the embodiment of \nFIG.', '5\n, this would mean that the diffusion bond at the boundary \n100\n between the blade section \n69\n and the body section \n68\n would have a greater strength than that of the metal alloy \n96\n that forms the bulk of the body section \n68\n.', 'It may also be desirable, in certain embodiments, for the sintering of the metal alloys at and/or near the boundary \n100\n, and therefore the resulting grain structure, to be substantially homogenous.', 'In certain embodiments, it may be desirable that the integrity of the body between the different metal alloys to be stable and maintained through any heating and quenching processes used in the fabrication of the pressure-controlling components \n26\n.', 'In some embodiments, the boundaries \n100\n that define the diffusion bonds between the different metal alloys of the pressure-controlling components \n26\n may not be planar boundaries.', 'For example, \nFIGS.', '6\n and \n7\n are cross-sectional views of embodiments of substantially bimetallic lower rams \n50\nB having a curved boundary \n100\n (e.g., a curved diffusion bond) disposed between a first metal alloy \n94\n and a second metal alloy \n96\n that form the lower ram \n50\nB.', 'In \nFIG.', '6\n, the curved boundary \n100\n results in the blade section \n69\n having both the first and the second metal alloys, while the curved boundary in \nFIG. \n7\n results in the body section \n68\n having both the first and the second metal alloys.', 'In certain embodiments, it may be desirable to use the curved boundary \n100\n, as opposed to the planar boundaries discussed above, to reduce the amount of the first alloy \n94\n or the second alloy \n96\n used to make the pressure-controlling component \n26\n.', 'In some embodiments, it may be desirable to include the curved boundary \n100\n increase the surface area of the interface \n100\n (e.g., the surface area of the diffusion bond) between the first and second metal alloys \n94\n, \n96\n to enhance the material properties (e.g., strength, toughness) of the pressure-controlling component \n26\n at the interface \n100\n.', 'Additionally, while regular curved boundaries are illustrated, in some embodiments, the boundaries \n100\n may have substantial irregularity (e.g., ripples, undulations) without departing from the techniques disclosed herein.', 'In some embodiments, the boundaries that define the diffusion bonds between different metal alloys may be complex and correspond to (e.g., follow, match) one or more contours in the outer surface of the pressure-controlling components \n26\n.', 'For example, \nFIG.', '8\n is a cross-sectional view of an embodiment of a substantially trimetallic lower ram \n50\nB having boundaries \n100\n that follow along features defined in the outer surface of the part.', 'In particular, a layer of the first metal alloy \n94\n defines the outer surface of the blade section \n69\n of the part, while the second metal alloy \n96\n fills the interior of the blade section \n69\n and defines the outer surface of the body section \n68\n of the ram \n50\nB. Additionally, for the illustrated embodiment, the third metal alloy \n98\n (e.g., a corrosion resistant alloy) defines the outer surface of a seal region \n102\n in the body section \n68\n of the ram \n50\nB.', 'It should be appreciated that any of the boundaries \n100\n (e.g., planar, curved, complex) may be used in the upper ram \n50\nA, the low ram \n50\nB, or both in any suitable combination (e.g., all planar, all curved, at least one planar and at least one curved).', 'For certain embodiments of the lower ram \n50\nB illustrated in \nFIG. \n8\n, at least a portion of the first metal alloy \n94\n or the third metal alloy \n98\n may be disposed on the second metal alloy \n96\n to form the outer surfaces of the pressure-controlling components \n26\n using a welding-based deposition process (e.g., an overlay, inlay, or cladding process) after the formation of the remainder of the part using the HIP manufacturing process set forth below.', 'However, in some embodiments, all of the metal alloys (e.g., metal alloys \n94\n, \n96\n, and \n98\n) of the pressure-controlling component \n26\n are joined together during the HIP manufacturing process discussed below.', 'For example, the layer of the first metal alloy \n94\n may have a defined first thickness \n104\n in the blade section \n69\n of the part, while the third metal alloy \n98\n may have a second thickness \n106\n in the seal region \n102\n of the ram \n50', 'B. Using the disclosed HIP manufacturing process, the first and second thicknesses \n104\n and \n106\n may be independently controlled to any suitable thickness, such as 0.125 inch (in) (0.3157 centimeter (cm), about 3 millimeters (mm)) or greater, 0.25 in (0.635 cm, about 6 mm) or greater, 0.375 in (0.9525 cm, about 10 mm) or greater, between 0.125 in (0.3157 cm, about 3 mm) and 1 in (2.54 cm, about 25 mm), between 0.25 in (0.635 cm, about 6 mm) and 1 in (2.54 cm, about 25 mm), 1 in (2.54 cm, about 25 mm) or greater.', 'As such, it may be appreciated that, for embodiments in which the metal alloys of the pressure-controlling components \n26\n are joined during HIP process in the disclosed HIP manufacturing process, there is an advantageous reduction in manufacturing time and cost by avoiding the welding-based deposition processes, as well as any subsequent post-welding activity (e.g., clean-up, analysis, inspection).', 'By using the disclosed HIP manufacturing process, the thicknesses \n104\n and \n106\n of the metal alloy layers \n94\n and \n98\n can also reach substantially greater thicknesses than can be suitably deposited using welding-based deposition processes.', 'Additionally, since the HIP manufacturing process does not require depositing the metal alloys \n94\n and \n98\n via a welding-based process, metal alloys \n94\n, \n96\n, and \n98\n may be metal alloys that are less conducive or completely incompatible with welding-based processes.', 'Furthermore, by avoiding the welding-based processes, the potential to introduce issues in the part as a side-effect of the welding-based deposition processes (e.g., unintended thermally-induced changes in the grain structure at or near the weld deposit, unintended introduction of stress or strain in the part, unintended imperfections in the fusion zone) can also be advantageously avoided.\n \nFIG.', '9\n is a block diagram of an embodiment of a HIP manufacturing system \n110\n that may be used to construct the multi-metallic pressure-controlling component \n26\n (e.g., the upper ram \n50\nA, the lower ram \n50\nB, other components of the BOP \n24\n).', 'For the illustrated embodiment, the HIP manufacturing system \n110\n includes a controller \n112\n, a user interface \n114\n, a canister \n116\n, a heat source \n118\n, and a pressure source \n120\n, which, as discussed below, may be used to carry out the steps of the manufacturing process \n130\n of \nFIG.', '10\n to form the pressure-controlling component \n26\n.', 'In certain embodiments, the controller \n112\n is an electronic controller having electrical circuitry configured to process data from various components of the system \n110\n, for example.', 'In the illustrated embodiment, the controller \n112\n includes a processor \n122\n and a memory device \n124\n.', 'The controller \n112\n may also include one or more storage devices and/or other suitable components.', 'By way of example, the processor \n122\n may be used to execute software, such as software for controlling the user interface \n114\n, controlling the heat source \n118\n, the pressure source \n120\n, and so forth.', 'Moreover, the processor \n122\n may include multiple microprocessors, one or more “general-purpose” microprocessors, one or more special-purpose microprocessors, and/or one or more application specific integrated circuits (ASICS), or some combination thereof.', 'For example, the processor \n122\n may include one or more reduced instruction set (RISC) processors.', 'The memory device \n124\n may include a volatile memory, such as random access memory (RAM), and/or a nonvolatile memory, such as read-only memory (ROM).', 'The memory device \n124\n may store a variety of information and may be used for various purposes.', 'For example, the memory device \n124\n may store processor-executable instructions (e.g., firmware or software) for the processor \n122\n to execute, such as instructions for controlling the user interface \n114\n, the heat source \n118\n, the pressure source \n120\n, and so forth.', 'The storage device(s) (e.g., nonvolatile storage) may include read-only memory (ROM), flash memory, a hard drive, or any other suitable optical, magnetic, or solid-state storage medium, or a combination thereof.', 'The user interface \n114\n may include suitable input and output devices communicatively coupled to the controller \n112\n.', 'The user interface \n114\n is configured to receive user input defining parameters of the HIP manufacturing process (e.g., temperature/pressure programs).', 'The controller \n112\n may store received inputs in the memory device \n124\n until used by the processor \n122\n to perform portions of the HIP manufacturing process.', 'During the HIP manufacturing process, information about the state of the controller \n112\n, the heat source \n118\n, the pressure source \n120\n, and measurements from various sensors (e.g., temperature sensors, pressure sensors, displacement sensors) of the HIP manufacturing system \n110\n may be suitably presented on a display device of the user interface \n114\n.', 'The canister \n116\n is generally a sacrificial metal alloy (e.g., steel) container that serves as a mold during the HIP processing.', 'As such, the canister \n116\n includes an internal cavity that generally corresponds to the shape of the pressure-controlling component \n26\n being manufactured, although notably larger due to the reduction in volume experienced during HIP process.', 'As discussed below, the canister \n116\n is designed to receive multiple metal alloy powders, and potentially receive metal alloy foil boundary layers (e.g., nickel foil boundary layers) that are disposed between each layer of distinct metal alloy powder.', 'During HIP processing of the canister \n116\n, the pressure provided by the pressure source \n120\n and the heat provided by the heat source \n118\n condenses the materials (e.g., metal alloy powders, boundary layers) within the canister \n116\n into an integral, dense, multi-metallic pressure-controlling component \n26\n.', 'In certain embodiments, the heat source \n118\n and the pressure source \n120\n are integrated into a single element (e.g., an autoclave furnace).', 'With the foregoing in mind, \nFIG.', '10\n is a flow diagram of a process \n130\n for manufacturing the pressure-controlling component \n26\n (e.g., the upper ram \n50\nA, the lower ram \n50\nB, other components of the BOP \n24\n).', 'In particular, the process \n130\n includes steps for constructing the pressure-controlling component \n26\n using the HIP manufacturing system \n110\n illustrated in \nFIG.', '9\n.', 'In certain embodiments, at least a portion of the steps of the process \n130\n (e.g., loading of the canister) may be performed by a human operator, while at least a portion of the steps of the process \n130\n (e.g., HIP processing) may be performed by the controller \n112\n based on instructions stored in the memory device \n124\n and/or input received from the user interface \n114\n.', 'It may be appreciated that the process \n130\n is merely provided as an example, and in some embodiments, the process \n130\n may include additional steps, omitted steps, repeated steps, and so forth, in accordance with the present disclosure.', 'For the embodiment illustrated in \nFIG. \n10\n, the process \n130\n begins with depositing (block \n132\n) a first metal alloy powder into the canister \n116\n.', 'The first metal alloy may be any of a variety of suitable materials, including those mentioned above.', 'In certain embodiments, the first metal alloy added to the canister \n116\n may correspond to the metal alloy that forms at least a substantial portion of the body section \n68\n of the rams \n50\n (e.g., metal alloy \n96\n in \nFIGS.', '6\n and \n7\n).', 'In some embodiments, the first metal alloy powder added into the canister \n116\n may correspond to the metal alloy that will be disposed nearest the rearward surface \n72\n of the part (e.g., metal alloy \n98\n in \nFIG.', '5\n) or nearest the leading surface \n70\n of the part (e.g., metal alloy \n94\n in \nFIG.', '5\n), depending on the orientation of the part in the canister \n116\n.', 'In certain embodiments, adding the first metal alloy powder into the canister \n116\n may include packing or shaping the powder, for example, using vibration, tamping, or other suitable methods.', 'In certain embodiments, the metal alloy powder may be stored under inert atmosphere (e.g., nitrogen, helium, argon, an oxygen-depleted atmosphere) and/or the canister may be loaded under an inert atmosphere to block oxidation of the surface of the metal alloy powder.', 'Continuing through the embodiment illustrated in \nFIG.', '10\n, the process \n130\n continues with disposing (block \n134\n) a boundary layer on top of the first metal alloy layer in the canister \n116\n.', 'Subsequently, a second metal alloy powder is deposited (block \n136\n) into the canister \n116\n, above the first metal alloy layer in the canister \n116\n and above the boundary layer (when present).', 'In certain embodiments, a boundary layer may not be used and the actions of block \n134\n may be skipped.', 'As mentioned, the boundary layer is a thin piece of a metal alloy (e.g., a metallic foil, a flat sheet) that may be disposed between layers of different metal alloy powders to prevent mixing of the powders during placement within the canister prior to carrying out the HIP processing and/or in the part after the HIP processing, which may enable a sharp and well-defined boundary between the different metal alloy powders and/or facilitate bonding.', 'In certain embodiments, the boundary layer may have a composition that is the same as, or similar to, one of the metal alloy powders it separates.', 'In some embodiments, the boundary layer may have a composition that is different than the composition of the metal alloy powders separated by the boundary layer.', 'For example, the boundary layer may serve as a “butter layer” to facilitate the formation of a strong bond between the metal alloy powder layers.', 'That is, the boundary layer may be a metal alloy that is more conducive towards bonding with the first and second metal alloy powders than the first and second metal alloy powders are toward bonding directly with each other.', 'In some embodiments, the actions of blocks \n134\n and \n136\n may be repeated to add a third metal alloy, a fourth metal alloy, etc., to the canister \n116\n as desired.', 'The actions of blocks \n132\n, \n134\n, and \n136\n may be better understood by way of \nFIGS.', '11\nA-C\n.', 'These figures illustrate cross-sectional views of portions of the canister \n116\n loaded with a first layer \n138\n of a first metal alloy powder (as set forth in block \n132\n), a boundary layer \n140\n (as set forth in block \n134\n), and a second layer \n142\n of a second metal alloy powder (as set forth in block \n136\n).', 'As shown in \nFIG.', '11\nA\n, in certain embodiments, the boundary layer \n140\n may provide a substantially flat interface separating the two planar layers of metal alloy powder \n138\n and \n142\n, which results in a flat planar boundary \n100\n in the pressure-controlling component \n26\n, as illustrated and discussed above with respect to \nFIG. \n5\n.', 'As shown in \nFIG. \n11\nB\n, in certain embodiments, the boundary layer \n140\n may provide a curved interface separating the two layers of metal alloy powder \n138\n and \n142\n, which would result in a curved boundary \n100\n in the pressure-controlling component \n26\n, as illustrated and discussed above with respect to \nFIGS. \n5\n and \n6\n.', 'As shown in \nFIG.', '11\nC\n, in certain embodiments, the boundary layer \n140\n may have a shape that corresponds to one or more features of the canister \n116\n (and eventually to the features on an outer surface of the pressure-controlling component \n26\n) to provide a complex interface separating the two layers of metal alloy powder \n138\n and \n140\n, which would result in a complex boundary \n100\n in the pressure-controlling component \n26\n, as illustrated and discussed above with respect to \nFIG. \n8\n.', 'Returning to \nFIG.', '10\n, the process \n130\n continues with sealing the canister \n116\n (block \n144\n).', 'For example, in certain embodiments, the canister \n116\n is placed under vacuum (e.g., to remove ambient oxygen) and then welded closed.', 'Once sealed, heat and pressure are applied (block \n146\n) to the materials (e.g., metal alloy powders, metal alloy boundary layers) disposed within the canister to consolidate the materials to form the pressure-controlling component \n26\n in a HIP process.', 'For example, heat and pressure may be applied to the canister \n116\n via the heat source \n118\n and the pressure source \n120\n (e.g., an autoclave furnace), and the walls of the canister \n116\n impart the desired heat and pressure to the materials within the canister \n116\n.', 'The heat and pressure cause the materials within the canister \n116\n to condense and bond to one another.', 'More specifically, each of the powdered metal alloys may sinter together to form portions of the component \n26\n, while narrow (e.g., 1 millimeter or less) diffusion bonds form at the boundaries \n100\n between the different metal alloys.', 'In other words, there is only a limited amount of mixing of the metal alloys of the two metal alloy powders and/or mixing of the metal alloys with the boundary layer at the interfaces \n100\n, and there is no substantial mixing of the metal alloys and/or the boundary layer a short distance (e.g., 1 millimeter) outside of each of these boundaries.', 'In certain embodiments, the materials sealed within the canister \n116\n may be heated to approximately 1050 to 1100 degrees Celsius, and the hydrostatic pressure within the canister may be approximately 400 to 450 Megapascals.', 'However, any suitable temperature and/or pressure may be utilized to cause formation of the pressure-controlling component \n26\n.', 'For example, in some embodiments, the temperature may be between approximately 900 to 1200, 950 to 1150, or 1000 to 1100 degrees Celsius and/or the pressure may be approximately 300 to 600, 350 to 550, or 400 to 500 Megapascals.', 'In certain embodiments, the temperature and/or the pressure may be varied at different times during HIP processing as part of a temperature/pressure program, for example, with various ramps to increase or decrease the temperature and/or pressure over predefined time windows, and with various holds times during which the temperature and/or pressure are held substantially constant.', 'It may be appreciated that the particular temperatures and pressures used in the HIP process of block \n146\n may be selected based on the material properties (e.g., melting point, sintering point) of the powder metal alloys and boundary layers disposed within the canister \n116\n.', 'It may be noted that there is a substantial reduction in volume (e.g., between 15 percent and 25 percent, about 20 percent) of the materials disposed within the canister \n116\n during this HIP process.', 'Upon completion of the HIP process of block \n146\n, the pressure-controlling component \n26\n is subsequently removed from the canister \n116\n.', 'The resulting pressure-controlling component \n26\n may have a substantially uniform density (e.g., plus or minus 10 percent, plus or minus 5 percent) and/or the various regions of the component \n26\n with different metal alloys may be coupled to one another via narrow diffusion bonds.', 'In certain embodiments, the pressure-controlling component \n26\n may undergo additional processing steps (e.g., machining, welding overlays, thermal treatment) to yield the final part.', 'The disclosed techniques enable the HIP fabrication of multi-metallic (e.g., bimetallic, trimetallic) pressure-controlling components for pressure-controlling equipment used in oil and gas applications.', 'The disclosed HIP manufacturing process enables multiple, distinct metal alloys to be used to form particular portions of a pressure-controlling component, wherein the different metal alloys can be joined using a single HIP process.', 'Compared with traditional subtractive manufacturing techniques, the disclosed HIP manufacturing process reduces the manufacturing time and cost, enables greater freedom of design in the selection of metal alloys, and enables a broader range of different material properties (e.g., strength, toughness, corrosion resistance) in different portions of the pressure-controlling component.', 'Additionally, the disclosed HIP manufacturing technique can enable the formation of surface layers of metal alloy at thicknesses not achievable using weld-based processes (e.g., inlaying, overlaying, cladding) and using metal alloys that are not conducive to welding-based processes.', 'While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein.', 'However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed.', 'Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims.']

['1.', 'A multi-metallic ram for a blowout preventer (BOP), the multi-metallic ram comprising:\na first portion formed from a first metal alloy;\na second portion formed from a second metal alloy;\na metal boundary layer present along an interface between the first metal alloy and the second metal alloy to enable the first metal alloy to form opposed exterior surfaces of a first section of the multi-metallic ram, and to enable the second metal alloy to form an interior in the first section between the opposed exterior surfaces of the first section of the multi-metallic ram, wherein the second metal alloy defines an outer surface of a second section of the multi-metallic ram; and\na diffusion bond at the interface between the first metal alloy and the second metal alloy that joins the first metal alloy to the second metal alloy within the multi-metallic ram.', '2.', 'The multi-metallic ram of claim 1, wherein the first metal alloy and the second metal alloy are independently selected from the group consisting of: chromium-molybdenum (Cr—Mo) steels, chromium-nickel-molybdenum (Cr—Ni—Mo) steels, maraging steels, super martensitic stainless steels, precipitation-hardened nickel alloys, precipitation-hardened martensitic steels, solution-annealed nickel alloys, tool steels, cobalt-bound tungsten-carbides, nickel-bound tungsten-carbides, nickel-cobalt (Ni—Co) alloys, and cobalt-chromium (Co—Cr) alloys.', '3.', 'The multi-metallic ram of claim 1, wherein the diffusion bond has a thickness of 1 millimeter or less, and there is no substantial mixing of the first metal alloy and the second metal alloy outside of the diffusion bond.', '4.', 'The multi-metallic ram of claim 1, wherein a grain structure of the first metal alloy and of the second metal alloy is substantially homogenous near the diffusion bond.', '5.', 'The multi-metallic ram of claim 1, wherein the interface between the first metal alloy and the second metal alloy is planar.', '6.', 'The multi-metallic ram of claim 1, wherein the interface between the first metal alloy and the second metal alloy is curved.', '7.', 'The multi-metallic ram of claim 1, wherein the interface between the first metal alloy and the second metal alloy has contours that correspond to non-planar features disposed on an outer surface of the multi-metallic ram.', '8.', 'The multi-metallic ram of claim 1, wherein each of the opposed exterior surfaces formed from the first metal alloy has a thickness greater than about 3 millimeters.', '9.', 'The multi-metallic ram of claim 1, wherein the multi-metallic ram is devoid of welds between the first metal alloy and the second metal alloy.', '10.', 'A multi-metallic ram for a blowout preventer (BOP), comprising:\na blade section formed from a first metal alloy;\na body section formed from a second metal alloy;\na metal boundary layer present along an interface between the first metal alloy and the second metal alloy to enable the first metal alloy to form opposed exterior surfaces of a first section of the multi-metallic ram, and to enable the second metal alloy to form an interior in the first section between the opposed exterior surfaces of the first section of the multi-metallic ram, wherein the second metal alloy defines an outer surface of a second section of the mulit-metallic ram; and\na diffusion bond disposed at the interface between the first metal alloy and the second metal alloy that joins the first metal alloy to the second metal alloy within the multi-metallic ram.', '11.', 'The multi-metallic ram of claim 10, wherein the blade section has a tensile strength, a yield strength, or a combination thereof, that is at least 5 percent greater than that of the body section of the multi-metallic ram.', '12.', 'The multi-metallic ram of claim 11, wherein the tensile strength, the yield strength, or a combination thereof, of the blade section is at least 200 percent greater than that of the body section of the multi-metallic ram.', '13.', 'The multi-metallic ram of claim 10, wherein the body section has a percent elongation or a percent reduction in area at least 5 percent greater than that of the blade section of the multi-metallic ram.', '14.', 'The multi-metallic ram of claim 10, wherein the body section comprises a region formed from a third metal alloy, and the multi-metallic ram comprises a second diffusion bond disposed along a respective interface between the second metal alloy and the third metal alloy that joins the second metal alloy to the third metal alloy within the multi-metallic ram.\n\n\n\n\n\n\n15.', 'The multi-metallic ram of claim 14, wherein the region comprises a seal region of the multi-metallic ram configured to contact an elastomer seal, and the third metal alloy has a higher corrosion resistance than the second metal alloy.', '16.', 'The multi-metallic ram of claim 14, wherein the region comprises a slide region of the multi-metallic ram configured to contact and slide against another metal component of the BOP during operation, and the third metal alloy has a hardness that is at least 5 percent greater than that of the second metal alloy.', '17.', 'A multi-metallic ram for a blowout preventer (BOP), the multi-metallic ram comprising:\na blade portion formed from a first metal alloy;\na body portion formed from a second metal alloy and coupled to the first portion;\na metal boundary layer present along an interface between the first metal alloy and the second metal alloy to enable the first metal alloy to form opposed exterior surfaces of a first section of the multi-metallic ram, and to enable the second metal alloy to form an interior in the first section between the opposed exterior surfaces of the first section of the multi-metallic ram, wherein the second metal alloy defines an outer surface of a second section of the multi-metallic ram; and\nwherein the interface that joins the first metal alloy to the second metal alloy within the multi-metallic ram is devoid of welds.']

['FIG.', '1 is a block diagram of a drilling system for mineral extraction, in accordance with an embodiment of the present disclosure;; FIG.', '2 is a cross-sectional top view of a portion of a blowout preventer (BOP) that may be used in the drilling system of FIG.', '1, in accordance with an embodiment of the present disclosure;; FIG.', '3 is a front isometric view of a component, namely an upper ram, that may be used in the BOP of FIG.', '2, in accordance with an embodiment of the present disclosure;; FIG. 4 is a front isometric view of another component, namely a lower ram, that may be used in conjunction with the upper ram of FIG.', '3 and the BOP of FIG.', '2, in accordance with an embodiment of the present disclosure;; FIGS.', '5, 6, 7, and 8 are cross-sectional views of the components of FIGS.', '3 and 4, in accordance with various embodiments of the present disclosure;; FIG.', '9 is a block diagram of a hot isostatic pressure (HIP) manufacturing system that is configured to carry out a HIP manufacturing process to fabricate the components of FIGS.', '3 and 4, in accordance with an embodiment of the present disclosure;; FIG.', '10 is a flow diagram of the HIP manufacturing process, in accordance with an embodiment of the present disclosure; and; FIGS.', '11A, 11B, and 11C are cross-sectional views of portions of a loaded canister prior to a HIP process of the HIP manufacturing process, in accordance with an embodiment of the present disclosure.', '; FIG.', '2 is a cross-sectional top view of a portion of an embodiment of the BOP 24 that may be used in the drilling system 10 of FIG.', '1, in accordance with an embodiment of the present disclosure.', 'As shown, the BOP 24 includes opposed rams 50, including upper ram 50A and lower ram 50B, also generally referred to herein as pressure-controlling components 26 or multi-metallic pressure-controlling components 26 of the BOP 24.', 'In the illustrated embodiment, the opposed rams 50 are in an open configuration 54 of the BOP 24 in which the opposed rams 50 are withdrawn from the central bore 22, do not contact the conduit 20, and/or do not contact one another.; FIG.', '3 is a front isometric view of an embodiment of the upper ram 50A, and FIG.', '4 is a front isometric view of an embodiment of the lower ram 50B, which may be used together as pressure-controlling components 26 in the embodiment of BOP 24 of FIG.', '2.', 'As illustrated in FIGS.', '3 and 4, the pressure-controlling components 26 each include the body section 68 and a blade section 69.', 'Each blade section 69 includes the leading surface 70, while the body section 68 includes the rearward surface 72 of the rams 50.', 'Because the rams 50 of FIGS.', '3 and 4 are shear rams, each blade section 69 includes a respective edge portion 77 that is formed in the leading surface 70 and that extends along the lateral axis 34 of each of the rams 50.', 'In a closed configuration, the respective edge portions 77 of the upper ram 50A and the lower ram 50B are configured to shear the conduit 20 and/or support the seal elements that seal against the central bore 22 of the BOP illustrated in FIG.', '2.', 'However, it should be appreciated that the rams 50 may have any of a variety of other configurations (e.g., the rams 50 may be pipe rams that lack the respective edge portions 77).', 'The blade section 69 of each of the rams 50 of FIGS. 3 and 4 also includes a leading cutout 78 formed in the leading surfaces 70 (e.g., positioned above and below the respective edge portion 77 along the vertical axis 30).', 'The leading surface 70, the rearward surface 72, the lateral surfaces 76, a top surface 82 (e.g., top-most surface), and a bottom surface 84 (e.g., bottom-most surface) may be considered the respective outer surfaces of the rams 50.', 'For the illustrated rams 50, the outer surfaces include grooves or channels 86.', 'In certain embodiments, at least a portion of these grooves may be sealing grooves designed to receive or interface with a polymeric material (e.g., an elastomeric seal), while a portion of these grooves may be sliding grooves designed to receive a slide along a metallic extension during operation of the BOP.; FIG.', '5 is a cross-sectional view of an embodiment of the upper ram 50A illustrated in FIG.', '3.', 'For the illustrated embodiment, the blade section 69 of illustrated upper ram 50A is made of a first metal alloy 94.', 'The body section 68 includes a first portion 68A that is made of a second metal alloy 96 and a second portion 68B that is made of a third metal alloy 98, resulting in a substantially trimetallic upper ram 50A. In some embodiments, both portions of the body section 68 may only include a single metal alloy, resulting in a substantially bimetallic upper ram 50A, in which the blade section 69 and the body section 68 each are made entirely of a different respective metal alloy.; FIG.', '9 is a block diagram of an embodiment of a HIP manufacturing system 110 that may be used to construct the multi-metallic pressure-controlling component 26 (e.g., the upper ram 50A, the lower ram 50B, other components of the BOP 24).', 'For the illustrated embodiment, the HIP manufacturing system 110 includes a controller 112, a user interface 114, a canister 116, a heat source 118, and a pressure source 120, which, as discussed below, may be used to carry out the steps of the manufacturing process 130 of FIG.', '10 to form the pressure-controlling component 26.']

US11933927

Seismic sensor assembly overvoltage protection circuitry

Mar 3, 2023

Ole Oeverland

Schlumberger Technology Corporation

International Search Report and Written Opinion issued in PCT application PCT/US2017/039369, dated Oct. 27, 2017 (16 pages).; International Preliminary Report on Patentability issued in PCT application PCT/US2017/039369, dated Jan. 10, 2019 (13 pages).; Search and Exam Report issued in United Arab Emirates Patent Application No. P6001812/2018 dated Nov. 8, 2023, 10 pages.

3688251; August 1972; Morris; 4967400; October 30, 1990; Woods; 5369626; November 29, 1994; Carroll; 6301195; October 9, 2001; Faber; 6786297; September 7, 2004; Menard; 8923095; December 30, 2014; Pettersen; 9291729; March 22, 2016; Pichot; 20020024791; February 28, 2002; Whitney; 20080008041; January 10, 2008; Pettersen; 20100053391; March 4, 2010; Huang; 20140126329; May 8, 2014; Guyton; 20150218913; August 6, 2015; Cooley; 20160091940; March 31, 2016; Oh; 20160380451; December 29, 2016; Pan; 20190250290; August 15, 2019; Oeverland

102419451; April 2012; CN; 1166595; January 2002; EP

['A seismic sensor assembly can include a housing that defines a longitudinal axis; a sensor; sensor circuitry operatively coupled to the sensor; and overvoltage protection circuitry electrically coupled to the housing.']

['Description\n\n\n\n\n\n\nRELATED APPLICATION', 'This application is a Continuation of U.S. application Ser.', 'No. 16/310,662 filed 17 Dec. 2018, which is a National Stage Entry of International Application having Serial No.', 'PCT/US2017/039369, filed 27 Jun. 2017 and claims priority to and the benefit of a U.S. Provisional Application Ser.', 'No. 62/356,653, filed 30 Jun. 2016, which is incorporated by reference herein.\n \nBACKGROUND\n \nReflection seismology finds use in geophysics, for example, to estimate properties of subsurface formations.', 'As an example, reflection seismology may provide seismic data representing waves of elastic energy (e.g., as transmitted by P-waves and S-waves, in a frequency range of approximately 1 Hz to approximately 100 Hz).', 'Seismic data may be processed and interpreted, for example, to understand better composition, fluid content, extent and geometry of subsurface rocks.', 'SUMMARY\n \nA seismic sensor assembly can include a housing that defines a longitudinal axis; a sensor; sensor circuitry operatively coupled to the sensor; and overvoltage protection circuitry electrically coupled to the housing.', 'A method can include mounting an overvoltage protection circuit board to a subassembly of a seismic sensor assembly that includes a sensor circuit board and a housing cover; electrically coupling a wire of the overvoltage protection circuit board to a ground shield via a coupling mechanism that couples the ground shield to a housing; and securing the housing cover to the housing.', 'An overvoltage protection circuitry unit kit for a seismic sensor assembly can include a board that includes a first side, a second side and mounting features that correspond to features of a subassembly of a seismic sensor assembly, that comprises a seismic sensor circuit board, to face the first side toward the seismic sensor circuit board; and circuitry mounted to the second side of the board where the circuitry includes at least one lightning protection circuit component.', 'Various other assemblies, components, kits, methods, systems, etc. are also disclosed.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFeatures and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.\n \nFIG.', '1\n illustrates an example of a geologic environment and an example of a technique;\n \nFIG.', '2\n illustrates an example of a survey technique and associated examples of equipment;\n \nFIG.', '3\n illustrates examples of equipment deployed in an example of a field installation;\n \nFIG.', '4\n illustrates examples of lightning and an example of a lightning strike as to equipment deployed in a field;\n \nFIG.', '5\n illustrates an example of a sensor unit, which may be referred to as a sensor assembly;\n \nFIG.', '6\n illustrates an example of a portion of an assembly;\n \nFIG.', '7\n illustrates an example of an assembly;\n \nFIG.', '8\n illustrates an example of a plot and an example of a diagram;\n \nFIG.', '9\n illustrates a portion of the assembly of \nFIG.', '7\n;\n \nFIG.', '10\n illustrates, in a cutaway view, the assembly of \nFIG.', '7\n;\n \nFIG.', '11\n illustrates, in a plan view, an example of a board; and\n \nFIG.', '12\n illustrates example components of a system and a networked system.', 'DETAILED DESCRIPTION', 'The following description includes embodiments of the best mode presently contemplated for practicing the described implementations.', 'This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.', 'As mentioned, reflection seismology finds use in geophysics, for example, to estimate properties of subsurface formations.', 'As an example, reflection seismology may provide seismic data representing waves of elastic energy (e.g., as transmitted by P-waves and S-waves, in a frequency range of approximately 1 Hz to approximately 100 Hz or optionally less than 1 Hz and/or optionally more than 100 Hz).', 'Seismic data may be processed and interpreted, for example, to understand better composition, fluid content, extent and geometry of subsurface rocks.', 'FIG.', '1\n shows an example of a geologic environment \n100\n (e.g., an environment that includes a sedimentary basin, a reservoir \n101\n, a fault \n103\n, one or more fractures \n109\n, etc.)', 'and an example of an acquisition technique \n140\n to acquire seismic data (see, e.g., data \n160\n).', 'As an example, a system may process data acquired by the technique \n140\n, for example, to allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment \n100\n.', 'In turn, further information about the geologic environment \n100\n may become available as feedback (e.g., optionally as input to the system).', 'As an example, an operation may pertain to a reservoir that exists in the geologic environment \n100\n such as, for example, the reservoir \n101\n.', 'As an example, a technique may provide information (e.g., as an output) that may specify one or more location coordinate of a feature in a geologic environment, one or more characteristics of a feature in a geologic environment, etc.\n \nAs an example, the geologic environment \n100\n may be referred to as or include one or more formations.', 'As an example, a formation may be a unit of lithostratigraphy, for example, a body of rock that is sufficiently distinctive and continuous that it can be mapped.', 'As an example, in stratigraphy, a formation may be a body of strata of predominantly one type or combination of types, for example, where multiple formations form groups, and subdivisions of formations are members.', 'As an example, a sedimentary basin may be a depression in the crust of the Earth, for example, formed by plate tectonic activity in which sediments accumulate.', 'Over a period of geologic time, continued deposition may cause further depression or subsidence.', 'With respect to a petroleum systems analysis, if rich hydrocarbon source rocks occur in combination with appropriate depth and duration of burial, hydrocarbon generation may possibly occur within a basin.', 'Exploration plays and prospects may be developed in basins or regions in which a complete petroleum system has some likelihood of existing.', 'The geologic environment \n100\n of \nFIG.', '1\n may include one or more plays, prospects, etc.', 'As an example, a system may be implemented to process seismic data, optionally in combination with other data.', 'Processing of data may include generating one or more seismic attributes, rendering information to a display or displays, etc.', 'A process or workflow may include interpretation, which may be performed by an operator that examines renderings of information and that identifies structure or other features within such renderings.', 'Interpretation may be or include analyses of data with a goal to generate one or more models and/or predictions (e.g., about properties and/or structures of a subsurface region).', 'As an example, a system may include features of a commercially available framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Texas).', 'The PETREL® framework provides components that allow for optimization of exploration and development operations.', 'The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of simulating a geologic environment, decision making, operational control, etc.).', 'As an example, a system may include add-ons or plug-ins that operate according to specifications of a framework environment.', 'For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Texas) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow.', 'The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user-friendly interfaces for efficient development.', 'In an example embodiment, various components (e.g., modules, blocks, etc.) may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'As an example, seismic data may be processed using a framework such as the OMEGA® framework (Schlumberger Limited, Houston, TX).', 'The OMEGA® framework provides features that can be implemented for processing of seismic data, for example, through prestack seismic interpretation and seismic inversion.', 'A framework may be scalable such that it enables processing and imaging on a single workstation, on a massive compute cluster, etc.', 'As an example, one or more techniques, technologies, etc. described herein may optionally be implemented in conjunction with a framework such as, for example, the OMEGA® framework.', 'A framework for processing data may include features for 2D line and 3D seismic surveys.', 'Modules for processing seismic data may include features for prestack seismic interpretation (PSI), optionally pluggable into a framework such as the OCEAN® framework.', 'A workflow may be specified to include processing via one or more frameworks, plug-ins, add-ons, etc.', 'A workflow may include quantitative interpretation, which may include performing pre- and poststack seismic data conditioning, inversion (e.g., seismic to properties and properties to synthetic seismic), wedge modeling for thin-bed analysis, amplitude versus offset (AVO) and amplitude versus angle (AVA) analysis, reconnaissance, etc.', 'As an example, a workflow may aim to output rock properties based at least in part on processing of seismic data.', 'As an example, various types of data may be processed to provide one or more models (e.g., earth models).', 'For example, consider processing of one or more of seismic data, well data, electromagnetic and magnetic telluric data, reservoir data, etc.', 'In the example of \nFIG.', '1\n, the geologic environment \n100\n includes an offshore portion and an on-shore portion.', 'As an example, a geologic environment may be or include one or more of an offshore geologic environment, a seabed geologic environment, an ocean bed geologic environment, etc.', 'As an example, the geologic environment \n100\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n102\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n105\n.', 'Such information may include information associated with downhole equipment \n104\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n106\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n105\n that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n100\n as optionally including equipment \n107\n and \n108\n associated with a well that includes a substantially horizontal portion that may intersect with one or more of the one or more fractures \n109\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n107\n and/or \n108\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As an example, a system may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a system may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable in the PETREL® software, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, a workflow may be a process implementable in the OCEAN® framework.', 'As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).', 'As an example, a workflow may include rendering information to a display (e.g., a display device).', 'As an example, a workflow may include receiving instructions to interact with rendered information, for example, to process information and optionally render processed information.', 'As an example, a workflow may include transmitting information that may control, adjust, initiate, etc. one or more operations of equipment associated with a geologic environment (e.g., in the environment, above the environment, etc.).', 'In \nFIG.', '1\n, the technique \n140\n may be implemented with respect to a geologic environment \n141\n.', 'As shown, an energy source (e.g., a transmitter) \n142\n may emit energy where the energy travels as waves that interact with the geologic environment \n141\n.', 'As an example, the geologic environment \n141\n may include a bore \n143\n where one or more sensors (e.g., receivers) \n144\n may be positioned in the bore \n143\n.', 'As an example, energy emitted by the energy source \n142\n may interact with a layer (e.g., a structure, an interface, etc.) \n145\n in the geologic environment \n141\n such that a portion of the energy is reflected, which may then be sensed by one or more of the sensors \n144\n.', 'Such energy may be reflected as an upgoing primary wave (e.g., or “primary” or “singly” reflected wave).', 'As an example, a portion of emitted energy may be reflected by more than one structure in the geologic environment and referred to as a multiple reflected wave (e.g., or “multiple”).', 'For example, the geologic environment \n141\n is shown as including a layer \n147\n that resides below a surface layer \n149\n.', 'Given such an environment and arrangement of the source \n142\n and the one or more sensors \n144\n, energy may be sensed as being associated with particular types of waves.', 'As an example, a “multiple” may refer to multiply reflected seismic energy or, for example, an event in seismic data that has incurred more than one reflection in its travel path.', 'As an example, depending on a time delay from a primary event with which a multiple may be associated, a multiple may be characterized as a short-path or a peg-leg, for example, which may imply that a multiple may interfere with a primary reflection, or long-path, for example, where a multiple may appear as a separate event.', 'As an example, seismic data may include evidence of an interbed multiple from bed interfaces, evidence of a multiple from a water interface (e.g., an interface of a base of water and rock or sediment beneath it) or evidence of a multiple from an air-water interface, etc.', 'As shown in \nFIG.', '1\n, the acquired data \n160\n can include data associated with downgoing direct arrival waves, reflected upgoing primary waves, downgoing multiple reflected waves and reflected upgoing multiple reflected waves.', 'The acquired data \n160\n is also shown along a time axis and a depth axis.', 'As indicated, in a manner dependent at least in part on characteristics of media in the geologic environment \n141\n, waves travel at velocities over distances such that relationships may exist between time and space.', 'Thus, time information, as associated with sensed energy, may allow for understanding spatial relations of layers, interfaces, structures, etc. in a geologic environment.\n \nFIG.', '1\n also shows various types of waves as including P, SV an SH waves.', 'As an example, a P-wave may be an elastic body wave or sound wave in which particles oscillate in the direction the wave propagates.', 'As an example, P-waves incident on an interface (e.g., at other than normal incidence, etc.) may produce reflected and transmitted S-waves (e.g., “converted” waves).', 'As an example, an S-wave or shear wave may be an elastic body wave, for example, in which particles oscillate perpendicular to the direction in which the wave propagates.', 'S-waves may be generated by a seismic energy sources (e.g., other than an air gun).', 'As an example, S-waves may be converted to P-waves.', 'S-waves tend to travel more slowly than P-waves and do not travel through fluids that do not support shear.', 'In general, recording of S-waves involves use of one or more receivers operatively coupled to earth (e.g., capable of receiving shear forces with respect to time).', "As an example, interpretation of S-waves may allow for determination of rock properties such as fracture density and orientation, Poisson's ratio and rock type, for example, by crossplotting P-wave and S-wave velocities, and/or by other techniques.", 'As an example of parameters that may characterize anisotropy of media (e.g., seismic anisotropy), consider the Thomsen parameters ε, δ and γ.', 'The Thomsen parameter δ describes depth mismatch between logs (e.g., actual depth) and seismic depth.', 'As to the Thomsen parameter ε, it describes a difference between vertical and horizontal compressional waves (e.g., P or P-wave or quasi compressional wave qP or qP-wave).', 'As to the Thomsen parameter γ, it describes a difference between horizontally polarized and vertically polarized shear waves (e.g., horizontal shear wave SH or SH-wave and vertical shear wave SV or SV-wave or quasi vertical shear wave qSV or qSV-wave).', 'Thus, the Thomsen parameters ε and γ may be estimated from wave data while estimation of the Thomsen parameter δ may involve access to additional information.', 'As an example, seismic data may be acquired for a region in the form of traces.', 'In the example of \nFIG. \n1\n, the technique \n140\n may include the source \n142\n for emitting energy where portions of such energy (e.g., directly and/or reflected) may be received via the one or more sensors \n144\n.', 'As an example, energy received may be discretized by an analog-to-digital converter that operates at a sampling rate.', 'For example, acquisition equipment may convert energy signals sensed by a sensor to digital samples at a rate of one sample per approximately 4 ms.', 'Given a speed of sound in a medium or media, a sample rate may be converted to an approximate distance.', 'For example, the speed of sound in rock may be of the order of around 5 km per second.', 'Thus, a sample time spacing of approximately 4 ms would correspond to a sample “depth” spacing of about 10 meters (e.g., assuming a path length from source to boundary and boundary to sensor).', 'As an example, a trace may be about 4 seconds in duration; thus, for a sampling rate of one sample at about 4 ms intervals, such a trace would include about 1000 samples where latter acquired samples correspond to deeper reflection boundaries.', 'If the 4 second trace duration of the foregoing example is divided by two (e.g., to account for reflection), for a vertically aligned source and sensor, the deepest boundary depth may be estimated to be about 10 km (e.g., assuming a speed of sound of about 5 km per second).', 'As an example, seismic data acquisition can include, for example, 3D and/or 4D land seismic data acquisition, such as during exploration for underground hydrocarbon-bearing reservoirs, or monitoring existing reservoirs.', 'As an example, electromagnetic signals may be used to transfer data to and/or from the sensor units, to transmit power, and/or to receive instructions to operate the sensor units.', 'An example of a simplified schematic view of a land seismic data acquisition system is illustrated in \nFIG.', '2\n.', 'As shown, an area \n202\n to be surveyed may or may not have physical impediments to direct wireless communication between, for example, a recording station \n214\n (which may be a recording truck) and a vibrator \n204\n.', 'A plurality of vibrators \n204\n may be employed, as well as a plurality of sensor unit grids \n206\n, each of which may have a plurality of sensor units \n208\n.', 'As illustrated in the example of \nFIG.', '2\n, for example approximately 24 to about 28 sensor units \n208\n may be placed in a vicinity (e.g., a region) around a base station \n210\n.', 'The number of sensor units \n208\n associated with each base station \n210\n may vary, for example, a survey.', 'Circles \n212\n indicate an approximate range of reception for each base station \n210\n.', 'In the system of \nFIG.', '2\n, the plurality of sensor units \n208\n may be employed in acquiring and/or monitoring land-seismic sensor data for the area \n202\n and transmitting the data to the one or more base stations \n210\n.', 'Communications between the vibrators \n204\n, the base stations \n210\n, the recording station \n214\n, and the seismic sensors \n208\n may be wireless (e.g., at least in part via air for a land-based system; or, e.g., optionally at least in part via water for a sea-based system).', 'FIG.', '2\n also shows an example of equipment with respect to a wireless data network where the wireless data network can include the seismic sensors \n208\n transmitting at least a portion of seismic data they sense to the one or more base stations \n210\n via a first wireless link \n209\n, which in turn can transmit at least some data they receive to the recording station \n214\n via a second wireless link \n216\n.', 'As an example, commands may be sent from recording station \n214\n to the vibrators \n204\n via the wireless link \n218\n, and, to the extent data is exchanged between the vibrators \n204\n and the recording station \n214\n, the wireless links \n218\n may be considered part of the wireless data network.', 'FIG.', '3\n shows an example of a geologic environment \n300\n, example equipment \n310\n and \n320\n, an example of downgoing energy \n327\n, an example of upgoing energy \n329\n where the equipment \n310\n can include one or more cables \n330\n and a plurality of sensor units \n340\n-\n1\n, \n340\n-\n2\n to \n340\n-N as, for example, nodes in an array or grid.', 'The equipment \n310\n and \n320\n can be part of a field installation where the equipment \n310\n that includes an array of sensor units for performing a seismic survey where the equipment \n320\n includes one or more seismic energy emission vehicles that can emit seismic energy to be sensed by the array of sensors where data can be collected, for example, by a receiver vehicle that may be as operatively coupled to the array of sensors.', 'In the example of \nFIG.', '3\n, the geologic environment \n300\n may be a desert such that the cable \n330\n that includes the individual sensor units \n340\n for deployment by an individual as that individual walks along paths, which may be, for example, inline or crossline paths associated with a seismic survey.', 'For example, the individual may carry a rod where hooks may allow for looping the cable \n330\n and where the hooks may be slide off an end of the rod as the individual positions the individual sensor units \n340\n.', 'For example, the individual sensor units \n340\n can include spikes that can be inserted into sand of a desert environment or, for example, tripod or other style base(s).', 'As an example, the spikes may be of a length of the order of about 10 cm and be capable of conducting seismic energy to circuitry of the individual sensor units \n340\n.', 'The equipment \n310\n represents a deployed line of sensor units \n340\n-\n1\n, \n340\n-\n2\n to \n340\n-N. As mentioned, such a line of sensors may be an inline or a crossline of a seismic survey.', 'As an example, a sensor unit may be a UNIQ™ sensor unit (Schlumberger Limited, Houston, Texas) or another type of sensor unit.', 'As an example, a sensor unit can include an accelerometer or accelerometers.', 'As an example, a sensor may be a geophone.', 'As an example, a sensor may include circuitry for 1 C acceleration measurement, 2 C acceleration measurement and/or 3 C acceleration measurement.', 'As an example, a sensor may be self-testing and/or self-calibrating.', 'As an example, a sensor unit can include memory, for example, to perform data buffering and optionally retransmission.', 'As an example, a sensor unit can include short circuit isolation circuitry, open circuit protection circuitry and earth-leakage detection and/or isolation circuitry.', 'As an example, a sensor unit may include location circuitry (e.g., GPS, etc.).', 'As an example, a sensor unit can include temperature measurement circuitry.', 'As an example, a sensor unit can include humidity measurement circuitry.', 'As an example, a sensor unit can include circuitry for automated re-routing of data and/or power (e.g., as to supply, connection, etc.).', 'As an example, a sensor unit may weigh about 0.40 kg (e.g., about 0.85 lb).', 'As an example, a sensor unit may have a height of about 90 mm (e.g., about 3.5 in), a width of about 90 mm (e.g., about 3.5 in) and a depth of about 75 mm (e.g., about 3 in).', 'As an example, a sensor unit may include one or more base options.', 'For example, while a spike is mentioned, other options may include a tripod, an Artic base, etc.', 'As an example, a sensor unit may be suitable for use in shallow water (e.g., up to a depth of several meters).', 'As an example, a sensor unit may include a temperature operational range of about −40 degrees C. to about 70 degrees C. (e.g., about −40 degrees F. to about 160 degrees F.).', 'As an example, a sensor unit may be rated to operate at voltages from about 5 volts to about 100 volts or more.', 'As an example, consider a sensor that operates in a range of about 25 volts to about 40 volts (e.g., plus voltage or minus voltage).', 'As mentioned, sensor units may be cabled to form a sensor string.', 'As an example, consider a string of about 10 sensors where a lead-in length is about 7 meters, a mid-section length is about 14 meters and a weight is about 15 kg.', 'As another example, consider a string of about 5 sensor units where a lead-in length is about 15 meters and a mid-section length is about 30 meters and a weight is about 12 kg.', 'Such examples may be utilized to understand dimensions of an array of sensors and, for example, how far a sensor unit is from one or more neighbors, to which it may be operatively coupled (e.g., via one or more conductors, conductive materials, etc.).', 'As to a power insertion unit (PIU), such a unit can be utilized for power and/or data routing.', 'For example, such a unit may provide power for a few sensor units to tens of sensor units to hundreds of sensor units (e.g., consider a PIU that can power 500 or more sensors).', 'As an example, a PIU may include lightening and/or emergency shutdown protection (e.g., ESD).', 'As an example, a PIU can include communication and/or location circuitry.', 'As an example, an installation can include a fiber-optic exchanger unit (FOX).', 'For example, such a unit may be a router that can communicate with a PIU.', 'As an example, fiber optic cables may be included in an installation.', 'For example, consider FOX and PIU fiber optic couplings.', 'As an example, an installation may include over a thousand sensor units.', 'As an example, an installation may include tens of thousands of sensor units.', 'As an example, an installation may include over one hundred thousand sensor units.\n \nFIG.', '4\n shows an example of lightning (e.g., lightening) generation and discharge \n400\n and an example of deployed sensor units \n410\n being struck by lightning.', 'A lightning flash is composed of a series of strokes with an average of about four.', 'The length and duration of each lightning stroke vary, but may average about 30 microseconds (e.g., consider an average peak power per stroke of about 10\n12 \nwatts).', 'Sound is generated along the length of the lightning channel as the atmosphere is heated by the electrical discharge to the order of 20,000 degrees C. This compresses the surrounding clear air producing a shock wave, which then decays to an acoustic wave as it propagates away from the lightning channel.', 'While some types of lightning are illustrated in \nFIG.', '4\n, there are numerous names and descriptions of various types and forms of lightning.', 'Some identify subcategories, and others may arise from optical illusions, appearances, or myths.', 'Some popular terms include: ball lightning, heat lightning, bead lightning, sheet lightning, silent lightning, black lightning, ribbon lightning, colored lightning, tubular lightning, meandering lightning, cloud-to-air lightning, stratospheric lightning, red sprites, blue jets, and elves.', 'As to lightning discharge, with the initial breakdown of air in a region of strong electric fields, a streamer may begin to propagate downward toward the Earth.', 'It may move in discrete steps of about 50 meters each and be called a stepped leader.', 'As it grows, it can create an ionized path depositing charge along the channel, and as the stepped leader nears the Earth, a large potential difference can be generated between the end of the leader and the Earth.', 'As an example, a streamer may be launched from the Earth and intercept the descending stepped leader just before it reaches the ground.', 'Once a connecting path is achieved, a return stroke flies up the already ionized path at close to the speed of light.', 'This return stroke releases tremendous energy, bright light and thunder.', 'Occasionally, where a thunderstorm grows over a tall Earth grounded object, such as a radio antenna, an upward leader may propagate from the object toward the cloud.', 'This “ground-to-cloud” flash generally transfers a net positive charge to Earth and is characterized by upward pointing branches.', 'A so-called “dry” thunderstorm is a thunderstorm that produces thunder and lightning, but its precipitation largely evaporates before reaching the ground.', '“Dry” lightning is a term that may be used to refer to lightning strikes occurring in such scenarios; noting that “dry” lightning is a technical misnomer since lightning itself is neither wet nor dry.', 'Dry thunderstorms can occur in deserts or places where atmospheric water vapor is low.', 'Because dry air tends to absorb liquid water, causing it to change phase into vapor, most of it is absorbed before reaching the ground and form virga.', 'In the example of \nFIG.', '4\n, a lightning strike can cause energy to travel along a cable or cables where it may impact one or more other sensor units.', 'As an example, a land sensor unit can include one or more lightning mitigation components.', 'For example, the sensor unit \n340\n-\n1\n of \nFIG. \n3\n may include one or more lightning mitigation components, which may be, as an example, one or more optional components that can be fit to the sensor unit \n340\n-\n1\n (e.g., by an individual, etc.).', 'As an example, a land sensor unit can optionally include grounding ability that is increased, for example, by way of a conductive bracket, which may be a substantially U-shaped metal part.', 'As mentioned and illustrated in \nFIG.', '4\n, the cabled land sensor units \n410\n can spread energy from lightning strikes.', 'For example, energy from a single strike can travel via a cable or cables and damage a relatively large number of sensor units.', 'Such damage may be quantified as being in a radius, a block, etc. as to a strike location associated with a strike and sensor units within the effected region.', 'As an example, one or more lightning mitigation components can help to minimize a damage dimension (e.g., a damage radius).', 'For example, by increasing the grounding of sensors, the number of sensor units that are damaged can be reduced.', 'FIG.', '5\n shows an example of an assembly \n500\n (e.g., a sensor unit) that includes cable connectors \n505\n-\n1\n and \n505\n-\n2\n, a housing \n510\n, a cover \n515\n, a ground shield \n520\n, a base \n530\n or a spike \n531\n, a sensor driver \n540\n, a sensor assembly \n545\n, and a circuitry board \n550\n.', 'As an example, the assembly \n500\n can include one or more clocks (e.g., sensor clocks, etc.).', 'As an example, the circuitry board \n550\n can be a geophone accelerometer circuitry board (a GAC board), which can include or be operatively coupled to a clock of the assembly \n500\n.', 'As an example, the assembly \n500\n can include a seismic system geophone accelerometer (a seismic system GAC) as the sensor assembly \n545\n that can sense motion (e.g., as operatively coupled to the sensor driver \n540\n) where circuitry may be utilized to reduce signal distortion and/or increase bandwidth (e.g., consider an approximately 18 Hz geophone with additional electronic circuitry).', 'As an example, consider the example simplified circuitry diagram \n555\n of \nFIG.', '5\n where a geophone element (GE) can be connected across an input of an operational amplifier (OpAmp, labeled OA) circuit.', 'In such an example, a feedback resistor (R) can connect the OpAmp circuit output to the geophone element.', 'In such an example, if a GAC coil moves within its magnetic field, the voltage it generates is detected by the OpAmp circuit, which responds by sending a current back through the feedback resistor (R), which can act to damp coil movement.', 'In such an example, as force to hold the coil stationary can be proportional to the coil acceleration, the output voltage of the circuitry represents earth motion expressed as acceleration.', 'As an example, as coil movement is reduced by more than an order of magnitude, the associated signal distortion may also be reduced by more than an order of magnitude.', 'As an example, a negative feedback loop can widen the pass-band of a signal that it controls.', 'As an example, an 18 Hz tilt-indifferent geophone may be utilized as an accelerometer with an about −3 dB point below about 2 Hz.', 'In such an example, choice of an about 18 Hz geophone may be suitable due to stiffness of springs and reduced coil displacement.', 'As an example, such an arrangement may allow for operation in various orientations while achieving some amount of optimization as to characteristics of a pass-band.', 'As an example, the assembly \n500\n can include electrical shock protection circuitry, for example, the assembly can include conductive and/or non-conductive structural features and/or circuitry that can mitigate effects of lightning strikes (e.g., at or near the assembly \n500\n, etc.).', 'As an example, an assembly can include one or more gas discharge tubes (GDTs) and/or one or more thyristor surge protection devices (TSPDs) as part of a protection system.', 'As an example, the assembly \n500\n may be utilized in a field where a plurality of such assemblies is positioned according to a grid plan, etc., to form an array.', 'As an example, various assemblies may be operatively coupled via one or more cables.', 'For example, a cable or cables may be coupled to the cable connectors \n505\n-\n1\n and/or \n505\n-\n2\n.', 'As an example, in a field system, an individual assembly or sensor unit may be considered to be a node (e.g., a node of a grid, a node of an array, etc.).', 'As an example, the assembly \n500\n of \nFIG.', '5\n may be a UniQ™ sensor unit (Schlumberger Limited, Houston, Texas).', 'As an example, an assembly or sensor unit may include circuitry that can output samples at intervals of 1 ms, 2 ms, 4 ms, etc.', 'As an example, an assembly or sensor unit can include an analog to digital converter (ADC) such as, for example, a 24-bit sigma-delta ADC.', 'As an example, an assembly or sensor unit can include synchronization circuitry such as, for example, GPS synchronization circuitry with an accuracy of about plus or minus 12.5 microseconds.', 'As an example, an assembly or sensor unit can include circuitry for sensing of real-time and optionally continuous tilt, temperature, humidity, leakage, etc.', 'As an example, an assembly or sensor unit can include calibration circuitry, which may be self-calibration circuitry.', 'As an example, the assembly \n500\n of \nFIG.', '5\n may be about 90 mm in height, about 90 mm in width and about 80 mm in depth.', 'As an example, a base may be a spike, a tripod or other type of base.', 'As an example, the assembly \n500\n of \nFIG.', '5\n may have a mass of about 0.4 kg.', 'As an example, the assembly \n500\n of \nFIG.', '5\n may have a power consummation of the order of about 100 mW and an operating voltage in a range of about plus or minus 25 V to about plus or minus 40 V.\n \nAs an example, a field system that includes assemblies such as the assembly \n500\n of \nFIG.', '5\n may include one or more power insertion units (PIUs) such as, for example, the UniQ™ PIU (Schlumberger Limited, Houston, Texas).', 'Such a unit may provide for power and/or data routing for a plurality of sensor units (e.g., up to hundreds of sensor units) and, for example, timing synchronization (e.g., via a clock and/or GPS).', 'As an example, such a unit may include data capacity of about 75 channels or more (e.g., for sampling intervals of about 1 ms, 2 ms, 4 ms, etc.).', 'As an example, a field system that includes assemblies such as the assembly \n500\n of \nFIG.', '5\n may include a source control unit such as, for example, an integrated source control (ISC) or integrated point-receiver land seismic system unit (e.g., consider the UniQ™ ISC, Schlumberger Limited, Houston, Texas).', 'As an example, a source control unit can directly and/or indirectly provide for control of seismic energy sources.', 'As an example, a source control unit may be operatively coupled to a plurality of seismic energy sources (e.g., tens or hundreds of seismic energy sources).', 'In the example of \nFIG.', '5\n, the assembly \n500\n includes the cable connectors \n505\n-\n1\n and \n505\n-\n2\n disposed at about 180 degrees from each other.', 'As mentioned, a cable can include a plurality of such assemblies.', 'As an example, cables may come into opposite points on a sensor unit, which may facilitate fitting the sensor with a substantially U-shaped grounding part.', 'In such an example, where a spike is optionally employed, the grounding part can be electrically coupled to the spike (see, e.g., the spike \n531\n).', 'As an example, where a base such as the base \n530\n is optionally employed, the grounding part may be electrically coupled to the base.', 'As an example, the base \n530\n can be made at least in part of an electrically conductive material.', 'As an example, a base and/or a spike may be in contact with ground (e.g., earth).', 'As an example, a base and/or a spike may support and help orient a sensor unit on the ground.', 'As an example, where lightning strikes a sensor unit and/or a cable operatively coupled to a sensor unit or units, the energy of the lightning may be dissipated at least in part via a base and/or a spike.', 'As an example, one or more grounding components may be included that are made at least in part of electrically conductive material that can route energy associated with a lightning strike to a base and/or a spike.', 'As an example, a kit can include one or more components to retrofit a sensor unit where the one or more components can help to reduce impact of lightning strikes.', 'As an example, a kit can optionally include a plurality of components, optionally including circuitry.', 'For example, a kit may include a grounding component and may include protection circuitry, which may be provided as a protection circuitry board.', 'As mentioned, some relatively arid environments can be prone to lightning; whereas, other environments may be less prone.', 'Thus, a kit can provide options for use where lightning may be likely.', "Such a kit may be usable without impacting a sensor unit's ability to sense seismic energy.", 'For example, a sensor unit can function with or without a grounding retrofit kit and/or a protection circuitry kit.', 'As an example, a kit may be relatively easy to install and/or remove, making transition or transitions minimal with respect to amount of time involved.', 'As an example, a kit may be suitable for use with a base and/or a spike.', 'As an example, a kit or kits may be provided with features that may optionally allow for tool-less installation.', 'In such an example, a sensor unit may include one or more features that are already installed that allow for tool-less installation of a kit or kits.', 'As an example, a tool-less installation kit or kits may allow for expedited installation and/or removal of one or more kit components.', 'In such an example, tool-less installation may allow for on-site choices to be made, for example, depending on environmental and/or other conditions.\n \nFIG.', '6\n shows an example of an assembly \n600\n that can be fit to a sensor unit such as, for example, the sensor unit \n550\n of \nFIG.', '5\n.', 'As shown, the assembly \n600\n includes a lightning protection unit \n620\n and a grounding clamp \n640\n.', 'As an example, a midsection portion of a sensor unit can includes cable connections and locking pins where the lightning protection unit \n620\n can include screws for tightening the lightning protection unit \n620\n to the sensor unit and where the grounding clamp \n640\n can be a substantially U-shaped electrically conductive component that can be operatively coupled to the lightning protection unit \n620\n at its open end (e.g., upper end of “U”) and operatively coupled to a base plate (e.g., and/or a spike, etc.).', 'As an example, a kit may include the lightning protection unit \n620\n and the grounding clamp \n640\n.', 'In such an example, lighting protection of a sensor unit can be enhanced as such a kit can help ground the sensor (e.g., assembly).', 'In such a manner, a number of sensor units in an array may include such kits where, the larger the number, the fewer the number of sensor units may be damaged near a strike.', 'As an example, grounding protection can be provided via a kit where the components of the kit provide a convenient and reliable physical path in metal (e.g., alloy, etc.) for connecting at least a portion of a sensor unit to a grounding point of the sensor.', 'As an example, a kit may be a single component such as, for example, the grounding clamp \n640\n of the example assembly \n600\n of \nFIG.', '6\n.', 'For example, a sensor may be provided with the lightning protection unit \n620\n and without the grounding clamp \n640\n where the grounding clamp \n640\n may be added on for use in an environment where risks exist as to lightning strikes.', 'As an example, a sensor unit can include circuitry that can help to protect the sensor unit from overvoltage as may be associated with electrical activity such as, for example, lightning.', 'As an example, a sensor unit can include a piggyback overvoltage protection (POP) board that may be operatively coupled within a sensor unit, for example, over an existing main electronics board of the sensor unit.', 'As an example, various types of circuitry of an assembly may be electrically connected to a common ground.', 'As an example, one or more circuits may optionally be coupled to different grounds where such grounds may at some point be operatively coupled to earth.', 'As an example, circuitry such as overvoltage protection circuitry may be utilized with one or more types of land surface equipment where electrical assemblies can benefit from protection against lightning strikes.', 'As an example, an electro-mechanical design of an overvoltage protection circuitry unit (e.g., a board, etc.) can provide added protection optionally without direct modification of existing electronics.', 'For example, an overvoltage protection circuitry unit may be provided as part of a kit, which can be a kit that can help to protect a sensor unit from the effects of electricity such as, for example, lightning.', 'As an example, a POP board may be insertable for additional protection in a region (e.g., a chamber, etc.) where existing electronics of a device may also be positioned.', 'In such an example, the POP board may be inserted and operatively coupled without making changes to existing electronics.\n \nFIG.', '7\n shows an example of an assembly \n700\n that includes a housing \n710\n, a housing insert \n715\n, a ground shield \n720\n, a first circuitry board \n750\n and a second circuitry board \n760\n.', 'In the example of \nFIG.', '7\n, a Cartesian coordinate system is shown that can be used to describe one or more features of the assembly \n700\n.', 'In the example of \nFIG.', '7\n, dashed vertical lines represent how features may be aligned and brought together during an assembly process.', 'For example, consider an assembly process that includes installing or removing the second circuitry board \n760\n.', 'As shown, the housing \n710\n includes openings \n712\n-\n1\n and \n712\n-\n2\n that can receive bolts or screws \n713\n-\n1\n and \n713\n-\n2\n that can pass through openings \n717\n-\n1\n and \n717\n-\n2\n of the housing insert \n715\n to couple the housing insert \n715\n to the housing \n710\n.', 'The housing insert \n715\n is shown as including connectors \n718\n-\n1\n and \n718\n-\n2\n for cables where each connector \n718\n-\n1\n and \n718\n-\n2\n includes electrical connectors \n719\n-\n1\n and \n719\n-\n2\n that can make electrical connections to wires of the cables as coupled to the connectors \n718\n-\n1\n and \n718\n-\n2\n.', 'As a cable or cables can be utilized for transmission of power, signals, commands, etc., the electrical connectors \n719\n-\n1\n and/or \n719\n-\n2\n are electrically coupled to the first circuitry board \n750\n.', 'Thus, where a cable or cables are subjected to energy from a lightning strike, such energy can travel through the cable or cables to the assembly \n700\n where such energy can be transferred to the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n.', 'As an example, the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n can be groups of pins, which may be, for example, copper pins.', 'For example, each group can include two or more pins.', 'As an example, consider four pins per group, which may be arranged in a rectangular manner (e.g., as a square, etc.).', 'As shown in the example of \nFIG.', '7\n, the second circuitry board \n760\n includes an upper side \n761\n that faces the first circuitry board \n750\n, optionally one or more pads \n766\n-\n1\n and \n766\n-\n2\n (e.g., insulating and resilient so as to absorb shock, etc.), a conductive wire or wires \n767\n and sockets \n769\n-\n1\n and \n769\n-\n2\n where electrical connections can be made between the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n and the second circuitry board \n760\n and where the second circuitry board \n760\n can be electrically connected to the housing \n710\n via the conductive wire or wires \n767\n, which can be in contact with the ground shield \n720\n via a bolt or screw \n722\n-\n1\n that can pass through or otherwise couple to a connector of the conductive wire or wires \n767\n (see, e.g., end connector with a washer-like conductive feature that can receive a shaft of the bolt or screw \n722\n-\n1\n).', 'In the example of \nFIG.', '7\n, a bolt or screw \n722\n-\n2\n is shown as a mechanism that secures the ground shield \n720\n to the housing \n710\n.', 'As an example, the bolts or screws \n722\n-\n1\n and \n722\n-\n2\n can help to assure electrical contact between the ground shield \n720\n and the housing \n710\n.', 'As an example, a path of energy from a lightning strike can be from a cable to an electrical connector \n719\n and to the second circuitry board \n760\n and, for example, to ground via one or more pathways that may include the ground shield \n720\n and/or the housing \n710\n.', 'In such an example, the second circuitry board \n760\n can include circuitry that can route energy applied at the electrical connector \n719\n-\n1\n and/or \n719\n-\n2\n to arresting circuity that can arrest the energy to reduce risk of damage to the first circuitry board \n750\n and/or one or more other components of the assembly \n700\n.', 'As an example, the first circuitry board \n750\n can be a geophone accelerometer circuitry board (a GAC board).', 'For example, the assembly \n700\n can include a seismic system geophone accelerometer (a seismic system GAC) as the sensor assembly \n545\n as in \nFIG.', '5\n that can sense motion (e.g., as operatively coupled to the sensor driver \n540\n as in \nFIG.', '5\n) where circuitry may be utilized to reduce signal distortion and/or increase bandwidth (e.g., consider an approximately 18 Hz geophone with additional electronic circuitry).', 'As to the second circuitry board \n760\n, it can include circuitry that acts to protect against overvoltage.', 'As an example, the second circuitry board \n760\n may be a POP board.', 'Such a board may be configured as a printed circuit board (PCB) with various components operatively coupled thereto.', 'As an example, such a board can include components such as one or more gas discharge tubes (GDTs) and/or one or more thyristor surge protection devices (TSPDs) and/or one or more metal oxide varistors (MOVs).', 'As an example, such a board can include the conductive wire or other electrical conductor \n767\n that can be electrically coupled to the ground shield \n720\n.', 'In the example of \nFIG.', '7\n, the relatively large gauge conductive wire \n767\n is screwed or bolted to the ground shield \n720\n while also being in electrical contact with the board \n760\n (e.g., via a solder, a weld or other coupling mechanism).', 'In the example of \nFIG.', '7\n, the ground shield \n720\n is disposed internally in the housing \n710\n and screwed, bolted, etc., to the housing \n710\n.', 'Further, the housing \n710\n can be supported by a base (see, e.g., the base \n530\n and the spike \n531\n of \nFIG.', '5\n), which can be in contact with earth, etc. (e.g., ground).', 'As mentioned, an assembly process can include installing or removing the second circuitry board \n760\n.', 'For example, consider loosening the bolts or screws \n713\n-\n1\n and \n713\n-\n2\n, lifting the housing insert \n715\n, coupling the board \n760\n to an underside of the housing insert \n715\n and board \n750\n (e.g., as a subassembly), connecting the conductive wire \n767\n to the bolt or screw \n722\n-\n1\n and securing the bolt or screw \n722\n-\n1\n to the ground shield \n720\n (e.g., and/or to the housing \n710\n).', 'In such an example, the housing insert \n715\n may be repositioned such that the bolts or screws \n713\n-\n1\n and \n713\n-\n2\n can be tightened.', 'As an example, coupling the board \n760\n can include press-fitting and/or soldering to electrically connect the board \n760\n to the electrical connectors \n719\n-\n1\n and/or \n719\n-\n2\n (e.g., depending on whether a single cable or two cables are to be operatively coupled to the connectors \n718\n-\n1\n and \n718\n-\n2\n of the assembly \n700\n.', 'As an example, such a process may optionally be performed on-site where, for example, a risk of lightning exists.', 'For example, during a storm and/or lightning season, a crew may install boards such as a plurality of the boards \n760\n in sensor units of a sensor unit array for acquisition of seismic energy as part of a seismic survey.', 'As an example, the board \n760\n can include a plurality of GDTs, which may be selected as to size, shape, number, ratings, etc.', 'A GDT can be a surge arrester device that include features to help arrest relatively high voltage transients induced by one or more phenomena such as, for example, one or more of lightning, inductive switching, electrostatic discharge, etc.', 'As an example, a GDT can be a hermetically sealed gas filled ceramic tube with metal electrodes.', 'As an example, a GDT may function such that its gas tube begins conduction when an electron within the GDT gains sufficient energy to initiate ionization of gas.', 'In such an example, complete ionization of the gas can take place through electron collision.', 'Events leading up to this phenomenon occur when a gas tube is subjected to a rising voltage potential.', 'Once the gas is ionized, breakdown occurs and the gas tube changes from a high impedance state to a virtual short circuit and thus, a transient can be diverted from circuitry to be protected.', 'As an example, arrester technology may be classified as crowbar or clamp.', 'For example, crowbar can include air gap, carbon block, GDT, silicon controlled rectifier (SCR), etc.; while, for example, clamp can include Zener (avalanche) diode, metal oxide varistor (MOV), etc.', 'As an example, an overvoltage protection unit or assembly may optionally implement one or more types of arresting technology.', 'As an example, a GDT may offer relatively high levels of performance on fast rising transients, for example, in a domain of about 100 V/μS to about 1 KV/μS, which includes at least some of those likely to be induced by one or more types of lightning disturbances (e.g., lightning strikes, etc.).', 'As an example, a GDT may feature a relatively low capacitance (e.g., optionally about 1 pF or less) and may include an optimized internal geometry that provides low insertion loss at high frequencies (e.g., for broadband equipment).', 'As an example, a GDT may be relatively robust, for example, able to divert a pulse of about 10,000 A pulse without destruction.', 'As an example, a GDT may provide about a 20,000 A single shot surge capability (e.g., per an 8 μs rise/20 decay μs pulse as defined by IEC 61000-4-5).', 'As an example, a GDT may be provided with a thermal failsafe option.', 'As an example, the board \n760\n can include a plurality of thyristor surge protective devices (TSPDs), which may be selected as to size, shape, number, ratings, etc.', 'As an example, TSPDs may be arranged to be avalanche triggered components to help protect vulnerable circuits from electrical overstress such as, for example, overstress due to a lightning strike or strikes.', 'TSPDs can protect by switching to a low on-state voltage (VT) of a few volts, thus providing a crowbar effect with high current capability.', 'As an example, TSPDs may be included in multidirectional and/or unidirectional configurations.', 'As an example, for unidirectional, the opposite direction (quadrant) from the switching mode may be specified either forward conducting or reverse blocking.', 'As an example, after triggering, a TSPD(s) clamping voltage can allow for large current surges to flow while limiting heat dissipation.\n \nFIG.', '8\n shows an example plot \n810\n and an example diagram \n830\n as related to arresting voltage transients.', 'In the plot \n810\n, voltage is shown with respect to time for a transient that is arrested by clamping.', 'For example, an operating voltage can be VO and a transient voltage can give rise toward a failure voltage VF to a peak voltage VP.', 'Where protection circuitry is included in an assembly, as the voltage rises due to the transient, protection circuitry can crowbar to on-state to at least partially arrest the transient (e.g., via a clamping mechanism).', 'In the diagram \n830\n, the transient is shown as traveling along a conductive pathway that includes circuitry \n832\n where protection circuitry \n834\n diverts current toward ground to help protect the circuitry \n832\n.', 'In the example of \nFIG. \n8\n, the diagram \n830\n shows a residual or clamped transient that may reach the circuitry \n832\n but be of a level that is less than a failure voltage (V\nF\n) of the circuitry \n832\n.', 'As an example, the board \n750\n may not experience an effect of board \n760\n due to high impedance of the board \n760\n and, for example, when voltage reaches a certain level, the board \n760\n can operate to arrest the voltage and, for example, provide an electrical path from a conductor to ground (e.g., via a shield and/or a housing).', 'As an example, the second circuitry board \n760\n can include one or more types of protection circuitry.', 'As an example, the second circuitry board \n760\n can include crowbar circuitry.', 'As an example, a crowbar circuit is an electrical circuit that can protect to varying extent (e.g., based on design, etc.) against an overvoltage condition, for example, to help reduce risk of damage to circuits attached to a transient pathway.', 'As an example, a crowbar circuit can provide a short circuit or low resistance path across a voltage path (e.g., akin to dropping a crowbar across the output terminals of a power supply).\n \nFIG.', '9\n shows a view of a portion of the assembly \n700\n of \nFIG.', '7\n where the board \n760\n is positioned proximate to the board \n750\n, for example, in a piggyback configuration or arrangement.', 'As shown, the board \n760\n includes a lower side \n763\n that faces away from the board \n750\n and can optionally include one or more pads \n766\n-\n3\n (e.g., insulating and resilient to absorb shock, etc.).', 'As an example, an overvoltage protection circuitry board can include opposing sides where an upper side faces a sensor circuitry board that includes circuitry associated with a seismic energy sensor and where a lower side faces a direction of a sensor unit (e.g., sensor assembly) that includes a seismic energy sensor that is electrically coupled to the circuitry associated therewith as carried by the sensor circuitry board.', 'In such an example, the overvoltage protection circuitry board can be electrically coupled via pins received in sockets of the overvoltage protection circuitry board and via one or more grounding wires (e.g., coupled to a housing, a ground shield, etc. of a sensor unit).', 'As mentioned, the board \n760\n may be provided as a unit.', 'In such an example, the unit may be readily inserted and operatively coupled to a sensor unit.', 'As an example, the board \n760\n may be in contact with the board \n750\n or may be spaced apart from the board \n750\n, for example, via one or more spacers.', 'As shown in the example of \nFIG.', '9\n, the board \n750\n can be oriented via one or more features \n716\n (e.g., pegs) of the housing insert \n715\n, for example, to assure alignment with the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n, which may be electrically connected to one or more cables.', 'As an example, the board \n760\n can be coupled to the board \n750\n, for example, consider coupling the board \n760\n to the board \n750\n via one or more of the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n and/or corresponding pin connectors of the board \n750\n (e.g., one or more four pin connectors, etc.).', 'As an example, the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n may pass through the board \n750\n while being in electrical contact with circuitry of the board \n750\n and also being in electrical contact with circuitry of the board \n760\n.', 'For example, the electrical connectors \n719\n-\n1\n can be received via the socket \n769\n-\n1\n of the board \n760\n and the electrical connectors \n719\n-\n2\n can be received via the socket \n769\n-\n2\n of the board \n760\n where the electrical connectors \n719\n-\n1\n and/or \n719\n-\n2\n are electrically coupled to the board \n750\n (e.g., via contacts, solder, etc.).', 'As an example, one or more mechanisms may be utilized to electrically couple the electrical connectors \n719\n-\n1\n and/or \n719\n-\n2\n to the board \n760\n (e.g., contacts, solder, clips, etc.).', 'As an example, the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n may be structural supports for the board \n760\n.', 'For example, the board \n760\n may be secured via receipt of the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n in the sockets \n769\n-\n1\n and \n769\n-\n2\n.', 'As an example, the sockets \n769\n-\n1\n and \n769\n-\n2\n may be slightly undersized such that an amount of force is applied upon receipt of the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n, which may be pins.', 'As an example, an interference fit (e.g., press-fit) may be achieved between sizing and spacing of the sockets \n769\n-\n1\n and \n769\n-\n2\n with respect to the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n.', 'As an example, such a fit may be secured, for example, via solder (e.g., soldering the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n to conductive pads, etc., of the board \n760\n).', 'As an example, solder may be a type of material that allows for assembly and disassembly of the board \n760\n from the sensor unit \n700\n where, for example, the board \n760\n is carried by the housing insert \n715\n and where the board \n750\n is disposed between the housing insert \n715\n and the board \n760\n.', 'For example, the housing insert \n715\n, the board \n750\n and the board \n760\n may be substantially planar structures that form a sandwich assembly where the board \n750\n is disposed at least in part between the housing insert \n715\n and the board \n760\n.', 'As an example, an interference fit (e.g., press-fit) may be may be achieved between sizing and spacing of the sockets \n769\n-\n1\n and \n769\n-\n2\n with respect to the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n.', 'In such an example, physical and electrical connections may be made for the board \n760\n with respect to the pins \n719\n-\n1\n and \n719\n-\n2\n optionally in a tool-less manner.', 'As mentioned below, the bolt or screw \n722\n-\n1\n may be provided with one or more features for tool-less installation and removal (e.g., optionally as a wing nut on a stud set in the housing, etc.).', 'As an example, the insert \n715\n may be installable and removable in a tool-less manner.', 'As an example, various components of a sensor unit may be installable and removable in a tool-less manner to allow, for example, for installation of the board \n760\n in a tool-less manner.', 'In the example of \nFIG.', '9\n, the board \n760\n is shown as including one or more protection circuitry components \n765\n that are in one or more electrical circuits of the board \n760\n as electrically coupled to the pins \n719\n-\n1\n and \n719\n-\n2\n (e.g., directly and/or indirectly).', 'FIG.', '10\n shows an approximate cutaway view of the assembly \n700\n.', 'In the view of \nFIG. \n10\n, dashed lines represent a seismic system geophone accelerometer or accelerometers (a seismic system GAC) as a sensor assembly \n745\n that can sense motion, for example, as operatively coupled to a sensor driver \n740\n, which is also illustrated in dashed lines.', 'In the example of \nFIG.', '10\n, the board \n760\n is arranged to be positioned between the sensor driver \n740\n (e.g., a GAC) and the electronics of the board \n750\n.', 'In such an arrangement, the conductive wire \n767\n (e.g., solid, stranded, etc.) can run beneath the board \n760\n such that it may avoid contact with the board \n750\n.', 'As shown, the conductive wire \n767\n (e.g., ground wire or wires) is insulated with electrical insulation and includes a coupling that is also partially insulated by electrical insulation.', 'The coupling may include an eye (e.g., an aperture) such that it can be electrically coupled to the ground shield \n720\n, for example, via the bolt or screw \n722\n-\n1\n, etc.', 'As shown in \nFIG. \n10\n, the bolt or screw \n722\n-\n1\n may include a feature or features that allow for hand tightening and loosening via fingers of a hand to allow for tool-less installation.', 'As an example, a bolt may be set in the housing \n710\n and include a wing nut that can allow for finger tightening and loosening for tool-less installation.', 'In the example of \nFIG.', '10\n, the protection circuitry components \n765\n are oriented downwardly toward the base of the housing \n710\n (e.g., toward the bottom of the housing \n710\n).', 'In such an example, the components \n765\n are positioned within a recess defined by the ground shield \n720\n and further separated from the board \n750\n via the substrate of the board \n760\n.', 'Thus, where damage, heating, etc., may occur to one or more of the components \n765\n, the effects thereof with respect to the board \n750\n may be reduced.', 'As an example, depending on couplings, features, etc., the board \n750\n may be operable in various circumstances where one or more of the components of the board \n760\n are inoperable, damaged, etc.\n \nIn the example of \nFIG.', '10\n, the assembly \n700\n may include a component \n751\n that is disposed between the ground shield \n720\n and the board \n750\n.', 'In such an example, the component \n751\n may be an insulator that electrically insulates the board \n750\n from the ground shield \n720\n.', 'As an example, the component \n751\n may be optional and, for example, the board \n750\n may be electrically coupled to the ground shield \n720\n at an upper rim of the ground shield \n720\n (e.g., via lower electrical contact pads of the board \n750\n).', 'In \nFIG. \n10\n, arrows illustrate an electrical pathway from the pins \n719\n-\n1\n to the socket \n769\n-\n1\n to the conductive wire \n767\n to the bolt or screw \n722\n-\n1\n and to ground via the housing \n710\n or a component coupled to the housing \n710\n.', 'As mentioned, circuitry of the board \n760\n (e.g., including the components \n765\n) can act in a crowbar manner to protect circuitry of the board \n750\n.', 'Such circuitry can be part of the electrical pathway from the socket \n769\n-\n1\n (e.g., and optionally one or more other sockets) to one or more of the components \n765\n.', 'As an example, where a field installation includes a sensor unit that is operatively coupled to two cables via two sets of pins, a lightning strike that imparts energy to either of the two cables can be handled via an overvoltage protection circuitry board such as, for example, the board \n760\n.', 'In various examples, a single board can handle energy transmitted via two cables.', 'As an example, a sensor unit may be fit with a single board or a plurality of boards to handle energy transmitted via one or more cables.', 'As an example, a board can include a single set of components (e.g., GDTs, TSPDs, etc.) that can handle energy transmitted by one or more of a set of cables coupled to a sensor unit (e.g., a sensor assembly).', 'As an example, a board can optionally include a plurality of sets of components that can handle energy transmitted by a plurality of cables where a one-to-one correspondence may exist between a set of components and each individual cable.', 'For example, a board such as the board \n760\n may include two sets of overvoltage protection circuitry, one for a first cable and one for a second cable.', 'In such an example, a common ground wire may be provided or, for example, two ground wires may be provided (e.g., one for each set of overvoltage protection circuitry).', 'As an example, each cable coupled to a sensor unit can have an associated set of overvoltage protection circuity.', 'In such an example, where a double-strike occurs (e.g., near simultaneous strikes to effecting each of two cables), the load may be handled separately for each cable.\n \nFIG. \n11\n shows a plan view (e.g., bottom side view) of the board \n760\n, which is shown as an example of a protection board.', 'As shown, the board \n760\n includes a plurality of TSPDs \n765\n; noting that one or more other suitable types of arresting features may optionally be utilized, additionally or alternatively. \nFIG.', '11\n also shows the board \n760\n as including the conductive wire \n767\n.', 'In the example of \nFIG. \n11\n, a damping member may be included, for example, consider the pad \n766\n-\n3\n that may provide for damping energy associated with mechanical and/or electrical shock (e.g., as may be associated with handling, seismic sensing, arresting overvoltage, etc.).', 'As an example, a damping member can be made of a polymeric material that is resilient and that is an insulator.', 'As an example, the sockets \n769\n-\n1\n and \n769\n-\n2\n can include castellated solder joints.', 'For example, the sockets \n769\n-\n1\n and \n769\n-\n2\n can be castellated mounting holes (e.g., castellated vias, castellations, etc.).', 'In the example of \nFIG. \n11\n, various dotted lines are shown to indicate that electrical connections exist for the board \n760\n, which may be a printed circuit board (PCB).', 'As an example, printed circuits can include copper that provide electrical connections between various features, components, etc., of the board \n760\n.', 'As an example, the board \n760\n may be shaped to accommodate one or more components of the board \n750\n.', 'As an example, the board \n760\n may include an axis that is perpendicular to the board \n760\n and that can be substantially aligned with an axis that is perpendicular to the board \n750\n.', 'As an example, the board \n760\n may rest on the board \n750\n and be electrically coupled to the board \n760\n (e.g., via the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n, etc.).', 'As an example, the board \n760\n may be oriented by the features \n716\n of the insert \n715\n.', 'As an example, the electrical connectors \n719\n-\n1\n and \n719\n-\n2\n may appropriately orient the board \n760\n with respect to the board \n750\n.', 'As shown in \nFIG.', '9\n, the board \n760\n may be of a smaller footprint than the board \n750\n.', 'For example, an area in a plan view of the board \n760\n can be less than an area in a plan view of the board \n750\n.', 'In the cutaway view of \nFIG.', '10\n, various protection circuitry components of the board \n760\n (e.g., the components \n765\n) are disposed in a recessed space defined at least in part by the ground shield \n720\n.', 'As an example, the housing insert \n715\n can be a cover that covers the boards \n750\n and \n760\n and where one or more of the screws or bolts \n722\n can be utilized to electrically couple the board \n760\n to the ground shield \n720\n via the conductive wire \n767\n and the ground shield \n720\n to the housing \n710\n.', 'As an example, the board \n750\n and/or the board \n760\n may be referred to as a PWA (e.g., a main PWA and a protective PWA).', 'As an example, energy associated with a lightning strike to a cable and/or a sensor unit (e.g., an assembly such as the assembly \n700\n) may travel to a grounding clamp, to a base and/or a spike of the sensor and into the earth.', 'In such an example, the sensor unit can include circuitry operatively coupled to one or more grounded components of the sensor unit.', 'As an example, such circuitry may provide for arresting transients such that, for example, other circuitry is protected.', 'As an example, protection circuitry may be provided at least in part as a board (e.g., a POP board).', 'As an example, a spike of a sensor unit can offer an amount of earth/spike contact area that acts to distribute the energy radially, for example, in about 360 degrees into the earth.', 'In such an example, the sensor unit may be considered to be a point source in a hemispherical medium where the energy can dissipate in a hemispherical manner that acts to reduce risk of energy traveling from one sensor to another sensor unit (e.g., via a cable or cables).', 'In such an example, a dimension of a strike impact area may be reduced.', 'As an example, various components may be nesting components.', 'For example, the board \n760\n can nest within the housing \n710\n of the assembly \n700\n (e.g., also consider the board \n760\n nesting within the ground shield \n720\n).', 'As an example, a coordinate system that can be used to describe one or more features of a sensor unit may be a cylindrical coordinate system that includes an angle such as an azimuthal angle (e.g., r, z, Θ).', 'As an example, various features of a sensor unit (e.g., a sensor assembly, etc.) and/or one or more grounding components (e.g., a board, a POP unit, a lightning protection unit, a grounding clamp, etc.) may be described with respect to a coordinate system such as, for example, a cylindrical coordinate system.', 'As an example, where a plurality of sensor assemblies include one or more protection and/or grounding components, the ability to handle and/or to ground lightning strike energy can increase for an array, which may lead to mitigation of lightning strike damage to the array.', 'For example, a dimension of impact may be reduced where sensor assemblies can individually ground lightning strike energy more effectively and/or arrest transients associated therewith.', 'As an example, a seismic sensor assembly can include a housing that defines a longitudinal axis; a sensor; sensor circuitry operatively coupled to the sensor; and overvoltage protection circuitry electrically coupled to the housing.', 'In such an example, the sensor circuitry can include circuitry mounted to a first board and the overvoltage protection circuitry can include circuitry mounted to a second board.', 'In such an example, the second board may be mounted to the first board or mounted to one or more connection features, such as, for example, electrical connectors that can be pins.', 'As an example, a seismic sensor assembly can include a first board and a second board where features that can be utilized to couple the two boards.', 'For example, consider pins that can be received by a socket or opening.', 'In such an example, the pins may be fixed to a board, for example, at a boundary of the board that defines the socket or opening.', 'As an example, boards may be provided with matching features for detachably coupling the boards, optionally in a tool-less manner such that a protection circuitry board (e.g., POP, etc.) can be installed in a relatively rapid manner.', 'As an example, a tool-less connection may be made between a wire and a component or components of a sensor assembly.', 'For example, a screw, bolt, etc. of a sensor assembly may be installed with a quick-connect coupling attached thereto such that installation of a protection circuitry board can be readily coupled to the quick-connect coupling via a matching or mating feature where such a feature can be electrically connected to a wire or other conductor that is in electrical contact with circuitry of the protection circuitry board.', 'As an example, an insulated wire can include an end or end feature that can be coupled to a component of a sensor assembly to establish a ground connection between a protection circuitry board and the component (e.g., or components).', 'As an example, the bolt or screw \n722\n-\n1\n as shown in \nFIG.', '10\n may include a wing feature or other type of feature that allows for hand tightening and/or loosening in a tool-less manner.', 'As an example, a footprint of a protection circuitry board (e.g., or protection circuit board) can be less than a footprint of a sensor circuitry board (e.g., or sensor circuit board).', 'As an example, a seismic sensor assembly can include an insert where sensor circuitry is mounted to the insert (e.g., a housing insert).', 'As an example, the insert may be a cover that covers a chamber defined at least in part by an inner surface of a housing (see, e.g., \nFIG.', '7\n).', 'As an example, a seismic sensor assembly can include a ground shield where sensor circuitry is disposed axially between an insert (e.g., a cover) and the ground shield.', 'In such an example, overvoltage protection circuitry can be disposed axially between the sensor circuitry and the ground shield.', 'As an example, a seismic sensor assembly can include a ground shield where overvoltage protection circuitry is electrically connected to the ground shield (see, e.g., \nFIG. \n7\n).', 'In such an example, a coupling mechanism can be included that connects an electrical coupling of the overvoltage protection circuitry to the ground shield.', 'As an example, such a coupling mechanism may also couple the ground shield to the housing (see, e.g., screws in \nFIG. \n7\n).', 'As an example, a seismic sensor assembly can include an electrical coupling that includes a wire that is electrically connected to overvoltage protection circuitry.', 'As an example, overvoltage protection circuitry can include at least one protection circuit component (e.g., TSPD, GDT, etc.).', 'For example, consider a plurality of protection circuit components, which may be arranged in a common circuit.', 'As an example, a board that includes one or more protection circuit components may include one or more monitor circuits that can be utilized to determine condition of the one or more protection circuit components.', 'For example, where a protection circuit component has been damaged, a monitor circuit can provide an indication of such damage.', 'As an example, a sensor assembly may include communication circuitry that can communicate a status of one or more components of overvoltage protection circuitry.', 'In such an example, a message may be formatted for communication via a communication mechanism that is utilized for communication of sensed seismic information.', 'For example, a message may be communicated prior to, during and/or after sensing of seismic information where the message includes information germane to the status of one or more components and/or, for example, an indication that the protection circuitry has been utilized to arrest a transient or transients.', 'In such an example, a sensor assembly may be identified (e.g., optionally via GPS, etc.) and serviced, for example, to replace its overvoltage protection circuitry and/or one or more components thereof.', 'As an example, a sensor circuitry board can include a trigger that is responsive to utilization of the overvoltage protection circuitry and that may, for example, include a counter that can be incremented responsive to actuation of the trigger.', 'In such an example, a number of arrests may be stored.', 'As an example, such stored information may be accessible, for example, as part of a health report of one or more components of a sensor assembly.', 'As an example, where protection circuitry includes one or more protection circuit components and where the protection circuitry is mounted to an insert (e.g., a cover), for example, via a sensor circuitry board, lifting of the insert may reveal the one or more protection circuit components for purposes of visual Inspection.', 'For example, a user may look for discoloration, blackening, melting, or one or more other signs of a surge event and resulting damage.', 'As an example, test circuitry may include applying a slow-rising DC voltage to a protection circuit component or protection circuit components to verify operation and, for example, a turn-on voltage.', 'Where replacement and/or removal of protection circuitry such as a protection circuitry board is desired, the protection circuitry may be removed and optionally replaced without removal of sensor circuitry (e.g., of a sensor circuitry board).', 'As an example, a seismic sensor assembly can include a chamber defined by a ground shield disposed within a housing where at least one protection circuit component is disposed within the chamber.', 'In such an example, overvoltage protection circuitry can include a board where the board can be disposed between the at least one protection circuit component and at least a portion of sensor circuitry, which can be oriented via features of an insert, which may be a cover that covers an interior space of the housing (e.g., a housing cover).', 'As an example, a method can include mounting an overvoltage protection circuit board to a sensor circuit board of a seismic sensor where the sensor circuit board is mounted to a housing cover; electrically coupling a wire of the overvoltage protection circuit board to a ground shield via a coupling mechanism that couples the ground shield to a housing; and securing the housing cover to the housing.', 'In such an example, the method can include arresting a voltage transient via circuitry of the overvoltage protection circuit board to protect circuitry of the sensor circuit board.', 'As an example, an overvoltage protection circuitry unit kit for a seismic sensor assembly can include a board that includes a first side, a second side and mounting features that correspond to features of a seismic sensor circuit board to face the first side toward the seismic sensor circuit board; and circuitry mounted to the second side of the board wherein the circuitry comprises at least one protection circuit component.', 'In such an example, the kit may include a wire electrically coupled to the circuitry and a coupling that includes a dimension that accommodates a ground shield-to-housing coupling mechanism.', 'For example, consider a wire with a end coupling that includes an opening that can be disposed at least in part about a diameter of a screw, a bolt, etc.', 'In such an example, the screw, the bolt, etc. may be tightened to secure the end coupling and, for example, to secure, at least in part, a ground shield to the housing.', 'As an example, a system may include one or more modules, which may be provided to analyze data, control a process, perform a task, perform a workstep, perform a workflow, etc.\n \nFIG.', '12\n shows components of an example of a computing system \n1200\n and an example of a networked system \n1210\n.', 'The system \n1200\n includes one or more processors \n1202\n, memory and/or storage components \n1204\n, one or more input and/or output devices \n1206\n and a bus \n1208\n.', 'In an example embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components \n1204\n).', 'Such instructions may be read by one or more processors (e.g., the processor(s) \n1202\n) via a communication bus (e.g., the bus \n1208\n), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device \n1206\n).', 'In an example embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc. (e.g., a computer-readable storage medium).', 'In an example embodiment, components may be distributed, such as in the network system \n1210\n.', 'The network system \n1210\n includes components \n1222\n-\n1\n, \n1222\n-\n2\n, \n1222\n-\n3\n, . . .', '1222\n-N.', 'For example, the components \n1222\n-\n1\n may include the processor(s) \n1202\n while the component(s) \n1222\n-\n3\n may include memory accessible by the processor(s) \n1202\n.', 'Further, the component(s) \n1222\n-\n2\n may include an I/O device for display and optionally interaction with a method.', 'The network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.', 'As an example, a device may be a mobile device that includes one or more network interfaces for communication of information.', 'For example, a mobile device may include a wireless network interface (e.g., operable via IEEE 802.11, ETSI GSM, BLUETOOTH®, satellite, etc.).', 'As an example, a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM slot, audio/video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery.', 'As an example, a mobile device may be configured as a cell phone, a tablet, etc.', 'As an example, a method may be implemented (e.g., wholly or in part) using a mobile device.', 'As an example, a system may include one or more mobile devices.', 'As an example, a system may be a distributed environment, for example, a so-called “cloud” environment where various devices, components, etc. interact for purposes of data storage, communications, computing, etc.', 'As an example, a device or a system may include one or more components for communication of information via one or more of the Internet (e.g., where communication occurs via one or more Internet protocols), a cellular network, a satellite network, etc.', 'As an example, a method may be implemented in a distributed environment (e.g., wholly or in part as a cloud-based service).', 'As an example, information may be input from a display (e.g., consider a touchscreen), output to a display or both.', 'As an example, information may be output to a projector, a laser device, a printer, etc. such that the information may be viewed.', 'As an example, information may be output stereographically or holographically.', 'As to a printer, consider a 2D or a 3D printer.', 'As an example, a 3D printer may include one or more substances that can be output to construct a 3D object.', 'For example, data may be provided to a 3D printer to construct a 3D representation of a subterranean formation.', 'As an example, layers may be constructed in 3D (e.g., horizons, etc.), geobodies constructed in 3D, etc.', 'As an example, holes, fractures, etc., may be constructed in 3D (e.g., as positive structures, as negative structures, etc.).', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words “means for” together with an associated function.']

['1.', 'A sensor assembly, comprising:\na housing unit associated with a longitudinal axis through the sensor assembly;\na housing insert comprising one or more electrical connectors configured to couple to one or more cables, wherein the housing insert is coupled to the housing unit;\na first circuitry board comprising sensor circuitry mounted to a first side of the housing insert;\na second circuitry board electrically coupled to the first circuitry board comprising overvoltage protection circuitry configured to arrest at least a first portion of energy associated with one or more overvoltage transients to a ground via a first electrically conductive pathway comprising the one or more cables, the one or more electrical connectors, and the overvoltage protection circuity; and\na ground shield conductively coupled to the housing unit and the second circuitry board, wherein the ground shield is configured to route at least a second portion of the energy associated with the one or more overvoltage transients to the ground via a second electrically conductive pathway comprising the one or more cables, the one or more electrical connectors, the ground shield, and the housing unit, wherein the at least the second portion is different from the at least the first portion of the energy.', '2.', 'The sensor assembly of claim 1, wherein the housing unit comprises:\na first space between the housing insert and the first circuitry board;\na second space between the second circuitry board and the ground shield; and\nan insulative component configured to electrically insulate the first circuitry board from the ground shield.', '3.', 'The sensor assembly of claim 2, wherein the second space is configured to limit heat dissipation associated with the one or more overvoltage transients.', '4.', 'The sensor assembly of claim 3, wherein the second space is larger than the first space.', '5.', 'The sensor assembly of claim 1, wherein the first circuitry board comprises a geophone accelerometer circuitry (GAC) board comprising a seismic system geophone accelerometer disposed inside the housing unit.', '6.', 'The sensor assembly of claim 1, wherein the second circuitry board comprises a printed circuit board (PCB) comprising one or more gas discharge tubes (GDTs), one or more thyristor surge protection devices (TSPDs), one or more metal oxide varistors (MOVs), or a combination thereof.', '7.', 'The sensor assembly of claim 1, wherein the first circuitry board comprises a first cross-sectional area that is larger than a second cross-sectional area of the second circuitry board.', '8.', 'The sensor assembly of claim 1, comprising a removable base configured to contact the ground and configured to support and orient the sensor assembly on the ground.', '9.', 'The sensor assembly of claim 8, wherein the removable base comprises a plate, a spike, or a tripod and is composed at least in part of electrically conductive material configured to route the energy associated with the one or more overvoltage transients to the ground.', '10.', 'The sensor assembly of claim 9, wherein the first electrically conductive pathway comprising the one or more cables, the one or more electrical connectors, the overvoltage protection circuity, and the removable base.', '11.', 'The sensor assembly of claim 9, wherein the second electrically conductive pathway comprising the one or more cables, the one or more electrical connectors, the ground shield, and the removable base.', '12.', 'The sensor assembly of claim 1, wherein the one or more overvoltage transients are associated with one or more lighting strikes.', '13.', 'An overvoltage protection kit, comprising:\na circuitry board comprising a first side, a second side, and mounting features corresponding to a sensor assembly, wherein the sensor assembly comprises a housing, a housing insert comprising one or more electrical connectors configured to couple to one or more cables, and sensor circuitry disposed on the first side of the circuitry board, wherein the first side is opposite of the second side;\novervoltage protection circuitry disposed on the second side of the circuitry board and configured to arrest at least a first portion of energy associated with one or more overvoltage transients to a ground via a first energy dissipation path comprising the one or more cables, the one or more electrical connectors, and the overvoltage protection circuity; and\na ground shield disposed inside the housing and conductively coupled to the housing, wherein the ground shield is configured to route at least a second portion of the energy associated with the one or more overvoltage transients to the ground via a second energy dissipation path comprising the one or more cables, the one or more electrical connectors, and the ground shield, wherein the at least the second portion is different from the at least the first portion of the energy.', '14.', 'The overvoltage protection kit of claim 13, comprising\na removable base composed at least in part of electrically conductive material and configured to: route the at least the first portion of the energy associated with the one or more overvoltage transients to the ground via the first energy dissipation path and the removable base; and route the at least the second portion of the energy associated with the one or more overvoltage transients to the ground via the second energy dissipation path and the removable base.', '15.', 'The overvoltage protection kit of claim 14, wherein the removable base comprises a plate, a spike, or a tripod conductively coupled to the housing.', '16.', 'The overvoltage protection kit of claim 15, comprising a grounding clamp conductively coupled to the removable base, wherein the grounding clamp comprises a substantially U-shaped electrically conductive component coupled to the sensor assembly at a first end and to the removable base at a second end.', '17.', 'The overvoltage protection kit of claim 16, wherein the overvoltage protection kit is configured to:\narrest the at least the first portion of the energy associated with the one or more overvoltage transients to the ground via the first energy dissipation path, the ground shield, and the removable base;\nroute the at least the second portion of the energy associated with the one or more overvoltage transients to the ground via the second energy dissipation path, the grounding clamp, and the removable base.', '18.', 'A method; comprising:\ndisposing a ground shield inside a housing of a sensor assembly, wherein the housing comprises a housing insert, seismic sensor circuitry, the ground shield, and overvoltage protection circuitry, wherein the housing insert comprises one or more electrical connectors configured to couple to one or more cables;\ndisposing the seismic sensor circuitry on a first side of a circuitry board;\ndisposing the overvoltage protection circuitry on a second side of the circuitry board, wherein the second side is opposite to the first side of the circuitry board;\nmounting the circuitry board to the housing insert, wherein the seismic sensor circuitry is disposed between the housing insert and the overvoltage protection circuitry;\nforming a first electrically conductive pathway by electrically coupling the one or more cables, the one or more electrical connectors, the seismic sensor circuitry, and the overvoltage protection circuity, wherein the first electrically conductive pathway is configured to arrest at least a first portion of energy associated with one or more overvoltage transients to a ground; and\nforming a second electrically conductive pathway by electrically coupling the ground shield to the one or more cables and the housing, wherein the second electrically conductive pathway is configured to route at least a second portion of the energy associated with the one or more overvoltage transients to the ground.', '19.', 'The method of claim 18, comprising a base composed at least in part of electrically conductive material, wherein the at least the first portion of the energy associated with the one or more overvoltage transients is routed to the ground via the first electrically conductive pathway and the base, and wherein the at least the second portion of the energy associated with the one or more overvoltage transients is routed to the ground via the second electrically conductive pathway and the base.', '20.', 'The method of claim 18, wherein the housing insert is configured to cover a chamber defined at least in part by an inner surface of the housing and the ground shield, wherein the overvoltage protection circuitry is positioned within a recess defined by the ground shield and separated from the seismic sensor circuitry via a substrate of the circuitry board, wherein the chamber is configured to limit heat dissipation associated with the one or more overvoltage transients.']

['FIG. 1 illustrates an example of a geologic environment and an example of a technique;; FIG.', '2 illustrates an example of a survey technique and associated examples of equipment;; FIG. 3 illustrates examples of equipment deployed in an example of a field installation;; FIG.', '4 illustrates examples of lightning and an example of a lightning strike as to equipment deployed in a field;; FIG.', '5 illustrates an example of a sensor unit, which may be referred to as a sensor assembly;; FIG.', '6 illustrates an example of a portion of an assembly;; FIG.', '7 illustrates an example of an assembly;; FIG. 8 illustrates an example of a plot and an example of a diagram;; FIG. 9 illustrates a portion of the assembly of FIG. 7;; FIG.', '10 illustrates, in a cutaway view, the assembly of FIG.', '7;; FIG.', '11 illustrates, in a plan view, an example of a board; and; FIG.', '12 illustrates example components of a system and a networked system.; FIG.', '1 shows an example of a geologic environment 100 (e.g., an environment that includes a sedimentary basin, a reservoir 101, a fault 103, one or more fractures 109, etc.)', 'and an example of an acquisition technique 140 to acquire seismic data (see, e.g., data 160).', 'As an example, a system may process data acquired by the technique 140, for example, to allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 100.', 'In turn, further information about the geologic environment 100 may become available as feedback (e.g., optionally as input to the system).', 'As an example, an operation may pertain to a reservoir that exists in the geologic environment 100 such as, for example, the reservoir 101.', 'As an example, a technique may provide information (e.g., as an output) that may specify one or more location coordinate of a feature in a geologic environment, one or more characteristics of a feature in a geologic environment, etc.; FIG. 1 also shows the geologic environment 100 as optionally including equipment 107 and 108 associated with a well that includes a substantially horizontal portion that may intersect with one or more of the one or more fractures 109.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 107 and/or 108 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG. 1 also shows various types of waves as including P, SV an SH waves.', 'As an example, a P-wave may be an elastic body wave or sound wave in which particles oscillate in the direction the wave propagates.', 'As an example, P-waves incident on an interface (e.g., at other than normal incidence, etc.) may produce reflected and transmitted S-waves (e.g., “converted” waves).', 'As an example, an S-wave or shear wave may be an elastic body wave, for example, in which particles oscillate perpendicular to the direction in which the wave propagates.', 'S-waves may be generated by a seismic energy sources (e.g., other than an air gun).', 'As an example, S-waves may be converted to P-waves.', 'S-waves tend to travel more slowly than P-waves and do not travel through fluids that do not support shear.', 'In general, recording of S-waves involves use of one or more receivers operatively coupled to earth (e.g., capable of receiving shear forces with respect to time).', "As an example, interpretation of S-waves may allow for determination of rock properties such as fracture density and orientation, Poisson's ratio and rock type, for example, by crossplotting P-wave and S-wave velocities, and/or by other techniques.; FIG.", '2 also shows an example of equipment with respect to a wireless data network where the wireless data network can include the seismic sensors 208 transmitting at least a portion of seismic data they sense to the one or more base stations 210 via a first wireless link 209, which in turn can transmit at least some data they receive to the recording station 214 via a second wireless link 216.', 'As an example, commands may be sent from recording station 214 to the vibrators 204 via the wireless link 218, and, to the extent data is exchanged between the vibrators 204 and the recording station 214, the wireless links 218 may be considered part of the wireless data network.; FIG.', '3 shows an example of a geologic environment 300, example equipment 310 and 320, an example of downgoing energy 327, an example of upgoing energy 329 where the equipment 310 can include one or more cables 330 and a plurality of sensor units 340-1, 340-2 to 340-N as, for example, nodes in an array or grid.; FIG.', '4 shows an example of lightning (e.g., lightening) generation and discharge 400 and an example of deployed sensor units 410 being struck by lightning.; FIG.', '5 shows an example of an assembly 500 (e.g., a sensor unit) that includes cable connectors 505-1 and 505-2, a housing 510, a cover 515, a ground shield 520, a base 530 or a spike 531, a sensor driver 540, a sensor assembly 545, and a circuitry board 550.', 'As an example, the assembly 500 can include one or more clocks (e.g., sensor clocks, etc.).', '; FIG.', '6 shows an example of an assembly 600 that can be fit to a sensor unit such as, for example, the sensor unit 550 of FIG.', '5.', 'As shown, the assembly 600 includes a lightning protection unit 620 and a grounding clamp 640.', 'As an example, a midsection portion of a sensor unit can includes cable connections and locking pins where the lightning protection unit 620 can include screws for tightening the lightning protection unit 620 to the sensor unit and where the grounding clamp 640 can be a substantially U-shaped electrically conductive component that can be operatively coupled to the lightning protection unit 620 at its open end (e.g., upper end of “U”) and operatively coupled to a base plate (e.g., and/or a spike, etc.).', '; FIG.', '7 shows an example of an assembly 700 that includes a housing 710, a housing insert 715, a ground shield 720, a first circuitry board 750 and a second circuitry board 760.', 'In the example of FIG. 7, a Cartesian coordinate system is shown that can be used to describe one or more features of the assembly 700.; FIG.', '8 shows an example plot 810 and an example diagram 830 as related to arresting voltage transients.', 'In the plot 810, voltage is shown with respect to time for a transient that is arrested by clamping.', 'For example, an operating voltage can be VO and a transient voltage can give rise toward a failure voltage VF to a peak voltage VP.', 'Where protection circuitry is included in an assembly, as the voltage rises due to the transient, protection circuitry can crowbar to on-state to at least partially arrest the transient (e.g., via a clamping mechanism).', '; FIG.', '9 shows a view of a portion of the assembly 700 of FIG.', '7 where the board 760 is positioned proximate to the board 750, for example, in a piggyback configuration or arrangement.', 'As shown, the board 760 includes a lower side 763 that faces away from the board 750 and can optionally include one or more pads 766-3 (e.g., insulating and resilient to absorb shock, etc.).', '; FIG.', '10 shows an approximate cutaway view of the assembly 700.', 'In the view of FIG.', '10, dashed lines represent a seismic system geophone accelerometer or accelerometers (a seismic system GAC) as a sensor assembly 745 that can sense motion, for example, as operatively coupled to a sensor driver 740, which is also illustrated in dashed lines.; FIG.', '11 shows a plan view (e.g., bottom side view) of the board 760, which is shown as an example of a protection board.', 'As shown, the board 760 includes a plurality of TSPDs 765; noting that one or more other suitable types of arresting features may optionally be utilized, additionally or alternatively.', 'FIG.', '11 also shows the board 760 as including the conductive wire 767.; FIG.', '12 shows components of an example of a computing system 1200 and an example of a networked system 1210.', 'The system 1200 includes one or more processors 1202, memory and/or storage components 1204, one or more input and/or output devices 1206 and a bus 1208.', 'In an example embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components 1204).', 'Such instructions may be read by one or more processors (e.g., the processor(s) 1202) via a communication bus (e.g., the bus 1208), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device 1206).', 'In an example embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc. (e.g., a computer-readable storage medium).']

US11732547

Methods, apparatus and systems for creating wellbore plugs for abandoned wells

May 24, 2018

Terizhandur S. Ramakrishnan, Hua Zhang, Quincy K. Elias, Albert Perez, Jr.

SCHLUMBERGER TECHNOLOGY CORPORATION

Abdelal et al., “Numerical simulation of a patent technology for sealing of deep-sea oil wells using nonlinear finite element method”, Journal of Petroleum Science and Engineering, vol. 133, pp. 192-200, 2015.; Search Report and Written Opinion of International Patent Application No. PCT/US2018/034422 dated Oct. 2, 2018; 16 pages.; Yili, “An Optimal Design for Millimeter-Wide Facture Plugging Zone”, Natural Gas Industry B., vol. 2(1), Jan. 2015, pp. 113-119.; Search Report and Written Opinion of International Patent Application No. PCT/US2018/034418 dated Sep. 28, 2018; 18 pages.; Ramakrishnan et al., “Measurement of ultralow permeability”, AIChE Journal, 62(4):1278{1293, 2016.; Search Report and Written Opinion of International Patent Application No. PCT/US2019/017274 dated Jun. 7, 2019; 18 pages.; Single Shear Test from Effect of Blade Thickness on Shear Strength, Appendix A, Department of Defense, 1973. MIL-STD-1312, Test No. 20, 28 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2019/017274 dated Oct. 15, 2020, 10 pages.; Exam Report under Section 18(3) issued in United Kingdom Patent Application No. GB2016858.9 dated Dec. 8, 2021, 7 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2018/034422 dated Oct. 15, 2020, 12 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2018/034418 dated Oct. 15, 2020, 10 pages.; Exam Report under Section 18(3) issued in United Kingdom Patent Application No. GB2016840.7 dated Jan. 21, 2022, 4 pages.; Exam Report under Section 18(3) issued in United Kingdom Patent Application No. GB2016845.6 dated Jan. 21, 2022, 4 pages.; Office Action issued in U.S. Appl. No. 17/045,313 dated Jul. 5, 2022, 22 pages.; Exam Report under Section 18(3) issued in United Kingdom Patent Application No. GB2016845.6 dated Jul. 19, 2022, 3 pages.; Preliminary Office Action issued in Brazilian patent application BR112020020435-8 dated Sep. 13, 2022, 6 pages with English Translation.; Office Action issued in U.S. Appl. No. 15/733,723 dated Oct. 27, 2022, 9 pages.; Office Action issued in Brazil Patent Application No. BR112020020447-1 dated Jan. 5, 2023, 6 pages with English translation.; Notice of Allowance issued in U.S. Appl. No. 17/045,313 dated Jan. 27, 2023, 8 pages.

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2017030806; February 2017; WO; 2018063829; April 2018; WO; 2018191158; October 2018; WO

['A wellbore is plugged using a bismuth alloy.', 'The wellbore is arranged so that a liquid bismuth alloy sets with an excess pressure of the plug relative to the borehole fluid pressure along a desired seal height distance.']

['Description\n\n\n\n\n\n\nTECHNICAL FIELD', 'The subject disclosure relates to methods, apparatus and systems for creating wellbore plugs for abandoned hydrocarbon wells.', 'BACKGROUND\n \nWells for the production of hydrocarbons such as oil are created by using a drill bit supported by a drill rig to drill a borehole into an earth formation.', 'After the borehole is drilled, sections of steel pipe, also referred to as casings, having diameters slightly smaller than the diameter of the borehole are placed in the borehole.', 'The casings are fixed in the borehole using cement which is pumped into an annulus between the casing and the formation.', 'The cement not only provides structural integrity to the casings, but isolates zones in the earth formation from one another.', 'After drilling and casing, the well is “completed” by making perforations in the casing through which the hydrocarbons can pass from the surrounding formation into production tubing.', 'Various techniques may then be used to produce the hydrocarbons from the formation.', 'Over the course of time, when the production of a hydrocarbon well declines to the extent that it no longer profitably produces hydrocarbons, it is common to abandon the well.', 'In abandoning the well, production tubing is removed, and a determination is made regarding the condition of the cement in the annulus.', 'If the cement is not deemed to be in excellent condition, it is common practice to remove the casing and the annulus cement and to fill or plug the remaining borehole with cement in order to prevent interzonal and surface communication, and contamination, as environmental factors are important, particularly in offshore settings.', 'The cost of removing the casing and the annulus cement can be significant, e.g., millions of U.S. dollars, particularly in offshore wellbores.', 'One reason for the significant cost is that removal of the casing and annulus cement is notoriously complicated and requires very heavy and expensive rig equipment for pulling the casing out of the wellbore.', 'The most common material used for plugging wells is Portland cement, which is placed in the well as a slurry that hardens in due time.', 'A cement plug consists of a volume of cement that fills a certain length of casing or open hole to prevent vertical migration of fluids.', 'Cement satisfies the essential criteria of an adequate plug; it is durable, has low permeability, and is inexpensive.', 'Furthermore, it is easy to pump in place, has a reasonable setting time and is capable of tight bonding to the formation and well casing surface.', 'It also has a sufficient mechanical strength under compression, although its tensile characteristics are its major weakness.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'According to one aspect, methods, apparatus and systems are provided for using a bismuth alloy as a plug in a wellbore and seating the plug so that it sets with an excess pressure on the alloy over the borehole fluid pressure along a desired seal height distance.', 'The desired seal height distance is generally either regulated or an established industry practice for a wellbore, and is typically from one to five meters in length.', 'In one embodiment, where the plug is to be set in a non-permeable portion of a formation (e.g., a shale layer), the formation-wellbore wall interface is first prepared by carving grooves into the wall that permit liquid to escape as the alloy sets.', 'More particularly, helical grooves may be carved, or vertical grooves connected by horizontal or angled grooves may be generated utilizing a laser.', 'A barrier or shot-catcher may then be installed just at or below the grooved area of the formation, and the bismuth alloy is then deployed with a thermite or other suitable reaction heater to below the top of the groove(s).', 'The heater is then initiated with electrical input sufficient to raise the temperature above the melting point of the alloy.', 'When the alloy cools, it expands and forces any borehole fluid away from the wall, pushing fluid up and out of the groove(s).', 'In addition, by deploying sufficient quantities of bismuth alloy, a pressure difference is established along the desired seal height distance.', 'By way of example, a pressure difference of 50 to 60 psi may be generated by having a plug of approximately five meters in height.', 'In another embodiment, where the plug is to be set in a porous layer of a formation (e.g., a sandstone), the location of a cap rock (impermeable layer) for that porous layer is found.', 'A barrier or shot-catcher may then be installed at a location in the porous layer and the bismuth alloy is deployed with a thermite or other suitable reaction heater.', 'The heater is then initiated with electrical input sufficient to raise the temperature above the melting point of the alloy, and pressure is applied which forces the alloy into the pores of the porous layer of the formation, thereby displacing any brine at the formation—borehole interface into the formation.', 'When the alloy cools, it expands and sets both in the pores of the porous layer and in the borehole.', 'Sufficient quantities of bismuth alloy are deployed so that the plug extends up into the cap rock layer, and a pressure difference is established along the desired seal height distance.', 'In one embodiment, a tool is provided to deliver the alloy and to pressurize the alloy as it cures.', 'The tool includes a packer that extends around a portion of the tool and engages the casing in the borehole, a fluid path including an inlet located above the packer, a pump, and a fluid outlet located below the packer, a bismuth alloy storage portion which may also store thermite or another suitable reaction heater and which is adapted to release the bismuth alloy and thermite into the target area of the borehole (e.g., an area spanning the porous layer and cap rock), and a liquid alloy position monitor whose output is used to stop the pump from pumping.', 'In some embodiments, the liquid alloy position monitor takes the form of electrodes extending from the bottom of the tool.', 'In some embodiments, the electrodes are mounted on a retraction arm or on arms with a sacrificial tension joint that may be broken.', 'In one aspect, the plugs generated using the described methods have particular structures that prevent displacement under differential pressures.', 'By way of example, the bismuth alloy plug generated in a non-permeable (e.g., shale) formation layer includes a first solid cylinder portion with one or more ribs extending along the outer surface of this cylinder, and a second solid cylinder portion of smaller diameter than the first solid cylinder portion.', 'In some embodiments, the first solid cylinder portion may taper at its top end toward the diameter of the second solid cylinder portion.', 'In some embodiments, the one or more ribs are helical, while in other embodiments, the one or more ribs include some vertical ribs with some horizontal or angled ribs connecting the vertical ribs.', 'The plug is typically at least five meters in length but less than half a meter in diameter.', 'The ribs are typically less than one centimeter in both width and radial height.', 'Also, by way of example, the bismuth alloy plug generated in a porous formation layer includes a first solid cylinder portions along with branched alloy structures (a dendritic web portion) that extend from the outer surface of the first cylinder and follow the pores of the formation, and a second solid cylinder portion of smaller diameter than the first cylinder portion.', 'Again, the top portion of the first solid cylinder portion may taper in diameter towards the diameter of the second solid cylinder portion.', 'The plug is typically at least five meters in length but less than half a meter in diameter.', 'The dendritic web portion of the plug may extend one, two, or even a few centimeters away from the first cylindrical portion depending on the squeezing pressure applied and the desired penetration distance required for achieving the requsite strength for preventing displacement of the plug under a differential pressure.', 'Additional aspects, embodiments, objects and advantages of the disclosed methods may be understood with reference to the following detailed description taken in conjunction with the provided drawings.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a diagram of a wellbore in a formation prepared for plugging at an impermeable layer.\n \nFIG.', '2\n is a flow chart of a method for plugging an abandoned wellbore at an impermeable layer.\n \nFIG.', '3\na \nis a diagram of a first solidified plug generated in a wellbore.\n \nFIG.', '3\nb \nis a diagram of a second solidified plug generated in a wellbore.\n \nFIG.', '3\nc \nis a diagram of a third solidified plug generated in a wellbore.\n \nFIG.', '4\n is a diagram of a wellbore in a formation prepared for plugging at the interface of a permeable layer and an impermeable layer.\n \nFIG.', '5\n is a flow chart of another method for plugging an abandoned wellbore at a permeable layer.\n \nFIG.', '6\na \nis a diagram of a first tool assembly located in a wellbore and adapted for plugging the wellbore.\n \nFIG.', '6\nb \nis a diagram of a second tool assembly located in a wellbore and adapted for plugging the wellbore.\n \nFIG.', '6\nc \nis a diagram of a third tool assembly located in a wellbore and adapted for plugging the wellbore.\n \nFIG.', '7\n is a diagram of a solidified plug generated in a wellbore located at the interface of a permeable layer and an impermeable layer.\n \nFIG.', '8\n is a schematic of a system for plugging an offshore well.', 'DETAILED DESCRIPTION', 'The present disclosure is directed to methods, apparatus and systems for using a bismuth alloy as a plug in a wellbore and seating the plug so that the plug sets with an excess pressure on the plug over the borehole fluid pressure along a desired seal height distance.', 'Generally, bismuth-tin (BiSn) alloys may be considered for use in plug-and-abandonment wells, such as offshore wells.', 'Alloy seals may be considerably shorter than cement plugs and may be set without rigs, thereby reducing well-abandonment costs.', 'Low melting point alloys such as those of BiSn have various advantages over cement: the alloys expand in volume during confined solidification, thereby forming a fluid-tight seal; they are inert to downhole fluids; and their strength can withstand expected compressive and tensile loads without material failure.', 'Solid bismuth based alloys may be deposited into the borehole over a preinstalled barrier or shot-catcher.', 'A thermite or other suitable reaction heater may be initiated with electrical input, sufficient to raise the temperature well above the melting point of the alloy.', 'The thermite heater core tube may or may not be removed, and the expansion of the bismuth alloy during solidification may provide a seal.', 'However, because bismuth-tin alloys have a contact angle of about 125° (in air) on porous rock or shale surfaces encountered in the oil-field and are therefore non-wetting, there is a tendency for borehole fluid to remain between the alloy plug and the formation.', 'More problematically, a chemical bond between the mineral rock surface and alloy does not form, and therefore a mechanical friction fit is relied upon.', 'Thus, under certain differential pressure conditions, the alloy plug may undergo undesirable displacement.', 'The methods, apparatus and systems of the present disclosure are directed towards two primary scenarios: a first scenario where the plug is to be set in an impermeable layer of a formation; and a second scenario where the plug is to be set in a permeable layer of a formation at a location to adjacent an impermeable cap rock in addition to its setting at the impermeable section.', 'According to one aspect, methods, apparatus and systems are provided for the plugging of an offshore wellbore.', 'The methods, apparatus and systems are directed to wireline (WL), slickline, or coiled tubing applications which may be deployed, e.g., from an offshore production platform or from a ship (boat).', 'For purposes herein, “wireline” is defined as a cabling technology used to lower equipment or measurement devices (also called “tools” or a “tool string”) from a surface into oil and gas wells, where signals (data) may be transmitted via the cable from the equipment or measurement device to the surface.', 'For purposes herein, “slickline” is defined as a non-electric cable, usually single-stranded, that is used to place, recover, or adjust wellbore equipment such as plugs, gauges and valves in oil and gas wells.', 'Typically, slicklines do not transmit data.', 'For purposes herein, “coiled tubing” is defined as a very long metal pipe which is supplied spooled on a large reel and used to carry out operations similar to wireline operations; i.e., to lower equipment or measurement devices (also called “bottom hole assemblies”) at the bottom of the tubing from a surface into oil and gas wells.', 'Slicklines, wirelines, and coiled tubing are raised and lowered in the well from a surface which may be a platform, a ship, or the formation itself and do not require the use of heavy rigs, such as might be required for removal of casing from a wellbore.', 'Thus, according to one aspect, the methods, apparatus and systems for plugging an offshore wellbore may be directed to “rigless” methods, apparatus, and systems, where for purposes of this document, the terms “rigless” or “without a rig” are defined as methods, apparatus and systems that are equipped to intervene in a well, but not designed for or capable of pulling hundreds of meters of casing out of a wellbore without using a rig.', 'A defining aspect of what is considered “rigless” or “without a rig” for purposes herein is the use of wireline or coiled tubing to relay an intervention tool into a well.', 'A defining feature of a coiled tubing or wireline, i.e., as meant herein for defining a “rigless” intervention, is the storage of the wireline or coiled tubing by way of spooling around a drum or other cylindrical storage device.', 'In contrast, a “rig” that is capable of pulling hundreds of meters of casing out of a hydrocarbon wellbore requires a structure such as a derrick, to sequentially add/remove long, heavy and rigid lengths of pipe, that are incapable of functionally being stored by being flexibly spooled around a drum or other cylindrical container.', 'Turning to \nFIG.', '1\n, an offshore abandoned wellbore \n100\n is seen extending downward from a sea floor \n101\n and having a wall \n104\n, a casing \n106\n along a portion of the wall, and cement \n108\n therebetween.', 'The wellbore \n100\n extends through a formation \n110\n having multiple layers.', 'An impermeable shale layer \n120\n is identified for receiving a plug.', 'A portion \n121\n of the shale layer \n120\n is shown prepared with the casing and cement removed and with one or more notches or grooves \n122\n which are etched into the wellbore wall \n104\n with a laser tool (e.g., a tool such as disclosed in U.S. Pat.', 'No. 8,627,901 to Underwood, et al., or in U.S. Pat.', 'No. 8,701,794 to Zediker et al.).', 'For purposes herein, the words “notch” and “groove” are used interchangeably and are to be broadly interpreted to include, but not be limited to a channel, trench, hollow, indentation, slot, and cleft.', 'The one or more notches \n122\n are continuous along at least a portion of the wall where a first cylindrical portion of the plug is to be located.', 'In one embodiment, the one or more notches are helical.', 'In another embodiment, the one or more notches include vertical notches which are connected by notches having a horizontal component such as horizontal or angled notches.', 'In one embodiment, in addition to the notches along the wellbore wall \n104\n, one or more additional notches \n123\n (continuous to notches \n122\n) in, e.g., a spiral form or in concentric circles connected by radial spokes are formed on a shoulder \n124\n between the cement and casing and the impermeable rock.', 'The spiral or concentric circular notch(es) is/are of increasing depth (height) with depth increasing towards the casing.', 'In another embodiment, the shoulder \n124\n between the cement and casing and the impermeable rock may be tapered.', 'The tapered shoulder \n124\n may include or define the notch(es) \n123\n.', 'A shot-catcher (or umbrella) \n129\n is shown located in the borehole.', 'Examples of plugs that may get generated as a result of the arrangement shown in \nFIG.', '1\n are seen in \nFIGS.', '3\na\n, \n3\nb\n, \n3\nc \nand discussed hereinafter.', 'A method for plugging a wellbore is shown in \nFIG.', '2\n.', 'At \n200\n, a non-porous portion of a formation (e.g., a shale layer) is identified.', 'The impermeable shale layer \n120\n may be identified by review of logs of the well and/or formation previously generated in order to explore and/or exploit the formation.', 'In one embodiment, the shale layer \n120\n that is identified is a relatively thick shale layer (e.g., tens of meters thick) that is closest to the surface of the formation (i.e., the seabed).', 'At \n210\n, the formation—wellbore wall interface is prepared by removing the casing and cement and carving one or more grooves into the wellbore wall for liquid escape as described hereinafter.', 'More particularly, one or more helical grooves may be carved, or vertical grooves connected by horizontal or angled grooves may be generated utilizing, e.g., a laser.', 'At \n220\n, a barrier, umbrella or shot-catcher may then be opened out (i.e., deployed using a barrier deployment tool) just at or below the grooved area of the formation.', 'At \n225\n, a determination is made as to the minimum amount of bismuth alloy (e.g., bismuth-tin alloy) required to obtain a desired sealing of the wellbore as discussed in more detail hereinafter.', 'At \n230\n, a tool containing at least the minimum amount of bismuth alloy and a thermite or other suitable reaction heater is situated in the borehole, e.g., using wireline, slickline or coiled tubing, and at \n240\n, the bismuth alloy and thermite is released to fill the borehole from the barrier up to the top of the prepared area and into a section of the cased portion of the borehole.', 'The heater is then initiated with an electrical input at \n250\n and is sufficient to raise the temperature above the melting point of the alloy, thereby melting the alloy.', 'As the alloy cools at \n260\n, due to a pressure difference and buoyancy, it forces any borehole fluid away from the wall, and pushes the fluid up and out of the groove(s).', 'The alloy also expands as it solidifies, but as it is not necessarily confined, the pressure difference and buoyancy are useful.', 'Any borehole fluid arriving at the shoulder is directed by the taper of the shoulder and/or by grooves in the shoulder to the cased section where it may float to the surface.', 'By deploying at least the minimum quantity of bismuth alloy, a pressure difference between the resident borehole fluid and the alloy is established along the desired seal height distance of the resulting plug.', 'In order to generate a pressure difference along the seal distance, it will be appreciated that the bismuth alloy pressure must be greater than the pressure in the brine (borehole fluid) below the bismuth alloy.', 'Since the formation at the location of the plug is impermeable, any brine trapped at the wall of the borehole will not naturally be pushed out by the bismuth alloy expansion during solidification.', 'Accordingly, the continuous grooves are provided, so that through buoyancy, an escape pathway for the brine is available.', 'Continuous pathway enables pressure continuity of the connected brine, so that the gravity head of the alloy over the brine provides the needed pressure difference to remove the resident brine.', 'Otherwise, any increase in the alloy pressure over the static pressure, i.e., ΔP\nA\n, will elevate both the alloy and the brine pressure.', 'Therefore, the gravity head for the alloy is relied upon as being larger over a given height compared to the brine in order to buoyantly remove the brine.', 'In order to achieve a desired ΔP\nA\n, a melted alloy height H is required according to:\n \n \n \n \n \n \n \n \nH\n \n≥\n \n \n \n \nΔ\n \n\u2062\n \n \n \n \n\u2062\n \n \nP\n \nA\n \n \n \n \n \n(\n \n \n \nρ\n \nA\n \n \n-\n \n \nρ\n \nw\n \n \n \n)\n \n \n\u2062\n \nℊ\n \n \n \n+\n \n \nH\n \nm\n \n \n \n \n \n \n \n(\n \n1\n \n)\n \n \n \n \n \n \n \n where ρ\nA \nand ρ\nw \nare the densities of the bismuth alloy and borehole brine respectively, g is the acceleration due to gravity, and H\nm \nis the minimum seal height desired.', 'In one embodiment, in order to be conservative, an alloy height of H\nc \nis added, where H\nc \nis the height of the area where the casing has been removed such that\n \n \n \n \n \n \n \n \nH\n \n=\n \n \n \n \nΔ\n \n\u2062\n \n \n \n \n\u2062\n \n \nP\n \nA\n \n \n \n \n \n(\n \n \n \nρ\n \nA\n \n \n-\n \n \nρ\n \nw\n \n \n \n)\n \n \n\u2062\n \nℊ\n \n \n \n+\n \n \nH\n \nm\n \n \n+\n \n \nH\n \nc\n \n \n \n \n \n \n \n(\n \n2\n \n)', 'By way of example, a pressure difference of approximately 50 psi may be generated by having a plug of approximately five meters in height.', 'The volumetric amount of bismuth alloy required to generate the desired plug height H (as determined by either equation (1) or equation (2)) is determined from \n \nV=πr\nc\n2\nH\n+π(\nr\nb\n2\n−r\nc\n2\n)\nH\nc\n+V\nC', '+V\nR\n+V\nu\n,\u2003\u2003(3) \n where r\nb \nis the radius of the prepared area (which may extend up to the borehole wall or beyond the borehole wall and into the formation) and is known, r\nc \nis the radius of the casing and is known, V\nC \nis the volume of the etched channel(s) and is known (and generally de minimis), V\nu \nis the volume in the umbrella and is known, and V\nR \nis the volume of the casing removed in the section above the cavity of radius r\nb\n, (if any, and is generally de minimis in any event) and is known.', 'For purposes herein, the volume V is said to “substantially equal” the first two terms of equation (3) plus V\nu \nas V\nC \nand V\nR \nare generally de minimis.', 'If the prepared area has a tapered portion, the V should be adjusted accordingly to include the taper volume.', 'Again, in one embodiment, that adjustment may be considered de minimis such that the volume V may still be said to “substantially equal” the first two terms of equation (3) plus V. \n \nIt is noted that the volume V may be calculated by hand or by or through the use of a processor.', 'With the bismuth alloy having been deployed into the wellbore, having been heated to make it liquid and then cooled so as to force out the brine, a solid plug is generated.', 'One example of such a solidified plug generated in a wellbore is seen in \nFIG.', '3\na \nwhere plug \n300\na \nis shown having a first cylindrical body portion \n310\na\n, a second cylindrical body portion \n312\na \nof smaller diameter than the first cylindrical body portion, a first end \n315\na \nshaped by the shape of the shot-catcher (e.g., conical), and one or more threads \n320\na \n(only one shown) extending proud of and helically running along the cylindrical first body portion \n310\na \nto the top of the cylindrical first body portion \n310\na\n.', 'A possible spiral thread \n323\n increasing in height from outside to inside is also shown in phantom.', 'Another example of a solidified plug that might be generated in the wellbore is seen in \nFIG.', '3\nb\n.', 'Plug \n300\nb \nis shown having a cylindrical first body portion \n310\nb\n, a cylindrical second body portion \n312\nb \nhaving a smaller diameter than the first cylindrical body portion, a first end \n315\nb \nshaped by the shape of the shot-catcher, a plurality of vertical ribs \n320\nbv \nextending proud of and helically running along the cylindrical first body portion to the top of the cylindrical first body portion as well as a plurality of horizontal ribs \n320\nbh \nconnecting the vertical ribs.', 'It will be appreciated that in some embodiments, instead of horizontal ribs, the plug might have angled (arced) ribs connecting the vertical ribs.', 'In fact, combinations of one or more of helical, vertical, horizontal, and arced ribs may get generated depending upon the etching of the impermeable formation layer provided that the etching generated one or more pathways for fluid to escape up and away from the formation wall as the bismuth alloy solidifies.', 'The ribs or the spiral grooves also provide hindrance to displacement of the plug.', 'Yet a third example of a solidified plug that might be generated in the wellbore is seen in \nFIG.', '3\nc\n.', 'Plug \n300\nc \nis shown having a first cylindrical body portion \n310\nc\n, a second cylindrical body portion \n312\nc \nof smaller diameter than the first cylindrical body portion, a tapered portion \n314\nc \nat the top of the first cylindrical body portion \n310\nc \nwhich tapers in diameter to the diameter of the second cylindrical body portion \n312\nc\n, a first end \n315\nc \nshaped by the shape of the shot-catcher (e.g., conical), and one or more threads \n320\nc \n(only one shown) extending proud of and helically running along the cylindrical first body portion \n310\nc \nto the top of the cylindrical first body portion \n310\nc. \n \nWhile \nFIGS.', '1\n, \n2\n, and \n3\na\n-\n3\nc \nare directed to plugging a wellbore at an impermeable layer of the formation, \nFIGS.', '4\n, \n5\n, \n6\na\n-\n6\nc \nand \n7\n are directed to plugging a wellbore at a permeable layer of the formation.', 'As seen in \nFIG.', '4\n, a wellbore \n400\n in a formation extends downward from a sea floor \n401\n and has a wall \n404\n, a casing \n406\n along a portion of the wall, and cement \n408\n between the casing and the wall.', 'The wellbore \n400\n extends through a formation \n410\n having multiple layers.', 'A permeable layer (e.g., sandstone) \n420\na \nwhich is capped by an impermeable layer \n420\nb \n(e.g., shale) is identified for receiving a plug.', 'The permeable layer \n420\na \nis shown prepared with the casing and cement removed adjacent to the interface of a permeable layer and the impermeable cap layer.', 'As a result, the diameter of the borehole at the impermeable layer \n420\nb \nwhere the casing \n406\n and cement \n408\n are located is shown as r\nc\n, while the diameter of the borehole at the permeable layer \n420\na \nand in the impermeable layer where the casing and cement have been removed is shown as r\nb\n.', 'Again, r\nb \nis the radius of the prepared area which may extend up to the borehole wall (i.e., the cement-formation interface) or beyond the borehole wall and into the formation.', 'The diameter to which the bismuth alloy penetrates the formation (as discussed hereinafter) is shown as r\np\n.', 'The height of the permeable layer from the shotcatcher \n429\n to the impermeable layer is shown as h, and the height of the area from which the casing and cement are removed in both the permeable layer and impermeable layer is shown as H\nc\n.', 'A method for plugging the wellbore \n400\n is shown in \nFIG.', '5\n.', 'At \n500\n, a porous portion of a formation (e.g., a sandstone layer) having an impermeable cap layer (e.g., a shale layer) is identified.', 'The porous portion of the formation having an impermeable cap layer may be identified by review of logs of the well and/or formation previously generated in order to explore and/or exploit the formation.', 'In one embodiment, the cap layer that is identified is a relatively thick shale layer (e.g., tens of meters thick) that is closest to the surface of the formation (i.e., the seabed).', 'At \n510\n, the formation—wellbore wall interface is prepared by removing the casing, cement, and possibly a part of the formation at the impermeable layer.', 'This section resembles a cavity within the wellbore.', 'Optionally, the impermeable cap layer wall (and shoulder) may also be etched with a laser or other device to form channels as previously described with reference to \nFIGS.', '1\n and \n2\n.', 'Also as previously described, optionally, the formation-wellbore interface may be prepared with a tapered shoulder.', 'At \n520\n, a barrier or shot-catcher may then be installed just at or below the prepared area of the formation.', 'At \n525\n, a determination is made as to the amount of bismuth alloy (e.g., bismuth-tin alloy) required to obtain a desired sealing of the wellbore (as discussed in more detail hereinafter).', 'At \n530\n, a tool containing at least the required amount of bismuth alloy and a thermite or other suitable reaction heater is situated in the borehole, e.g., using wireline, slickline or coiled tubing, and at \n540\n, the bismuth alloy and thermite is released to fill the borehole from the barrier upward.', 'The heater is then initiated (with electrical input) at \n550\n and is sufficient to raise the temperature above the melting point of the alloy, thereby melting the alloy and at \n555\n, pressure is applied as described hereinafter to the liquid alloy to force some of the alloy into the porous layer, thereby pushing borehole liquid (brine) into the formation.', 'Optionally, at \n560\n the height of the liquid alloy in the borehole and above the porous layer is monitored in order to prevent too much movement of the alloy into the porous layer with a concomitant decrease in plug height.', 'The height of the liquid alloy may be used as feedback to control the pressure application.', 'When the alloy cools at \n565\n, it expands upon solidification and a pressure difference is established along the desired seal height distance.', 'According to one aspect, in selecting the amount of alloy to utilize, the following points are considered.', 'After alloy pellets are delivered and melted, the height of the molten alloy should be more than the borehole height H\nm \n(the design specification for the minimum height requirement of the alloy over the shale interval) over which the alloy is intended to be set.', 'The pressure that is applied at \n555\n may be applied in different manners.', 'For example, the pressure may be applied through a water column above the molten alloy through the use of a surface pump so that the elevation in the bottom-hole pressure is nearly the same as the intended intrusion pressure.', 'Alternatively, and as described hereinafter with respect to \nFIGS.', '6\na\n-\n6\nc\n, a packer may be set above the interval with an internal pump within the tool that pumps fluids from above the packer into the packed-off region.', 'Turning to the second alternative first, the borehole may be only partially filled with brine.', 'This means that the formation pressure is less than the hydrostatic head in a filled borehole.', 'With a schematic representation of the plug region as shown in \nFIG.', '4\n, it should be understood that r\nb\n, H\nm\n, V\nC \nand h are fixed, where V\nC \nis the volume of the channels etched on the shale surface (if any), and r\np \nis assumed.', 'For this chosen geometry, the volume of alloy, V\nA\n, that penetrates into the permeable layer can be calculated by \n π(\nr\np\n2\n−r\nb\n2\n)φ\nh\n+π(\nr\np\n−r\nb\n)(\nr\np\n2\n−r\nc\n2\n)φ=\nV\nA\n\u2003\u2003(4) \n where, φ is the porosity, and as set forth above, h is the porous bed height (into which alloy is to be pushed), r\nc \nis the casing radius, r\nb \nis the borehole radius, and r\np \nis the penetration radius.', 'It is noted that the volume from the equation is slightly larger than the volume of alloy penetrating the formation because an assumption is made that the cement behind the casing has the same penetration volume as the formation.', 'This is usually an over-estimate.', 'It is also noted that the height across the impermeable layer does not contribute to the penetration volume of the alloy, except for what is present in the surface channels (if any).', 'At the bottom of the prepared portion of the formation, an umbrella may be set to prevent alloy from dropping below the prepared portion.', 'If the volume within the umbrella container is the total alloy volume V\nTA \nother than the cylindrical portion of the plug may be calculated according to \n \nV\nTA\n=V\nA\n+V\nC\n+V\nu\n.', '(5) \n \nThe minimum volume of the alloy in the rest of the borehole V\na \nmay be calculated by \n \nV\na\n=πr\nb\n2\n(\nH\nc\n−h\n)', '+π\nr\nb\n2\nh+πr\nc\n2\n(\nH−H\nc\n)+\nV\nR\n+V\nT\n\u2003\u2003(6) \n where H\nc \nis the height of the area from which the casing and cement are removed in both the permeable layer and impermeable layer (as previously described), V\nR \nis the casing volume removed above H\nc \n(if any), and V\nT \nis the volume of the tapered area (if any).', 'Thus, the minimum required total alloy volume where the plug is being set partially in a permeable portion of the formation (V\np\n) is calculated as V\np\n=V\nTA\n+V\na\n.', 'It will be appreciated that V\np \nmay be calculated manually or through the use of a processor.', 'According to one aspect, after setting the bottom umbrella, and before dropping the bismuth alloy pellets, a good contact of the brine with the formation is maintained.', 'A simple injection of water into the borehole may be used to increase the pressure in the borehole by ΔP\nw \nresulting in an influx of water q\nw\n(t) into the permeable layer.', 'For injection controlled from the surface, the volume added to the borehole in order to maintain the same pressure may be measured, and q\nw\n(t) may be inferred over a sufficiently long interval such that storage effects are not relevant.', 'For an interval set with a packer, the pumping rate into the interval can be monitored in order to maintain the pressure increase.', 'Alternatively, the pressure may be elevated by pumping liquid either at the surface or into the packed-off interval as the case may be.', 'Knowing the compressibility of the pumped brine, and the decay rate of pressure after pumping is stopped, the flow rate may also be estimated, after ignoring log(t) dependence on pressure-drop versus flow rate dependence, i.e., the average flow rate over a specified time interval is sufficient.', 'Now, in order to estimate the alloy flow rate, a zeroth-order approximation may be utilized\n \n \n \n \n \n \n \n \n \n \n \nq\n \nA\n \n \n\u2061\n \n \n(\n \nt\n \n)\n \n \n \n=\n \n \n \n \n \nµ\n \nw\n \n \n\u2062\n \nΔ\n \n\u2062\n \n \n \n \n\u2062\n \n \nP\n \nA\n \n \n \n \n \nµ\n \nA\n \n \n\u2062\n \nΔ\n \n\u2062\n \n \n \n \n\u2062\n \n \nP\n \nw\n \n \n \n \n\u2062\n \n \n \nq\n \nw\n \n \n\u2061\n \n \n(\n \nt\n \n)\n \n \n \n \n \n,\n \n \n \n \n \n(\n \n7\n \n)\n \n \n \n \n \n \n \n where P\nA \nis the pressure of the molten alloy during intrusion and q\nA \nis the alloy flow rate.', 'The time for alloy to penetrate a distance r\np \nis determined according to \n \n \n \n \n \n \n \n \n \nT\n \n=\n \n \n \nV\n \nA\n \n \n \n \nq\n \nA\n \n \n\u2061\n \n \n(\n \nt\n \n)\n \n \n \n \n \n,\n \n \n \n \n \n(\n \n8\n \n)\n \n \n \n \n \n \n \n which may be set to a desired value by adjusting the pressure P\nA\n.', 'It will be appreciated that there are complicating factors in attempting to control the bismuth alloy flow rate into the formation by adjusting pressure.', 'For example, while the temperature in the borehole is elevated through the igniting of a chemical source, the resulting thermal profile should stay above the melting point of the alloy to a distance r\np \nfor the time T.', 'But the alloy flow rate q\nA \ncannot be arbitrarily raised without limit simply by increasing ΔP\nA \nwithout limit.', 'Once the pressure limit is reached, T cannot be reduced any further and this defines T\nm\n, a minimum time.', 'From a design point, once T\nm \nbecomes the limit, r\np \nmust be computed based on q\nA\n(t) obtained with the maximum ΔP\nA\n.', 'If this r\np \nis insufficient to achieve the necessary plug strength, then the height h must be adjusted to be larger to meet the requirements necessary to prevent dislodging of the plug.', 'According to one aspect, it may be desirable to use a downhole system (as described hereinafter) to build pressure on the molten alloy since the necessary column height required to reach ΔP\nA \nmay exceed the time for temperature at r\np \nto stay above the melting point.', 'In the situation where the borehole is completely filled with brine, it will be appreciated that the formation pressure is greater than the borehole pressure.', 'A further elevation in alloy pressure is required in order to have it enter the porous rock.', 'Unlike the previous case where the borehole was assumed to be only partially filled with brine, and given the lack of an air column, the bottom-hole pressure may be rapidly increased by pumping brine into the wellbore at the surface.', 'Monitoring the pressure at the well-head for building up the requisite elevation in pressure in order to equal ΔP\nA \nmay be an acceptable solution, although a downhole wireline-conveyed pump could also be utilized and in one embodiment could be advantageous in being able to reduce the time required to achieve the necessary pressure elevation.', 'In some instances, a ΔP\nA \nlimit to prevent unlimited intrusion into the rock may not be known.', 'In reality, intrusion will not be unlimited since the upper limit for r\np \nis restricted by the temperature profile of the formation.', 'In particular, beyond a certain radius, the formation temperature will stay below the alloy melting point, and penetration of the molten alloy significantly beyond that radius is unlikely.', 'If this radial location becomes (unnecessarily) large, the cavity may not be completely filled with the bismuth alloy, and as a result, the plug height may become smaller (shorter) than the regulatory requirement or recommendation developed through historical practice of the art with cement plugs.', 'Therefore, it may be desirable to limit the volume of intruded alloy, by setting an upper value for the net pumped volume of brine into the isolated section of the well-bore interval or into the borehole at the surface.', 'For cases where a downhole pump with an isolated packed-off interval is deployed, this is easily implemented, and an upper limit on the pumped volume may be set.', 'The expansion volume of the alloy upon solidification does not need to be accounted for since the net volume limit for pumping is calculated based on V\nA\n, and is approximately equal to the pumped volume.', 'According to one aspect, the limit method described may have certain drawbacks due to volume expansion and contraction resulting from the heating and thermite reaction products.', 'For example, upon melting, there is a volume reduction in alloy, which in turn will reduce pressure, but this is likely to be more than offset by the volumetric expansion of borehole brine due to increase in temperature.', 'Therefore, pressure is likely to increase rather decrease.', 'With migration into the formation, and temperature reduction due to heat loss, the pressure may drop below the intrusion ΔP\nA \nand therefore continued pumping may be needed to maintain it.', 'However, pumping should stop once the alloy level drops to H\nm \n(with some tolerance) across the impermeable region since no further intrusion is desirable in the permeable region.', 'According to one embodiment, a simple level switch that monitors the liquid alloy position is sufficient to ensure a limit on intrusion volume.', 'The level switch may be implemented using two point or ring or bar electrodes mounted on a sonde, the resistance across which is monitored, with the electrodes set just above the desired plug height.', 'Upon a precipitous drop in conductance at this height (indicating that the alloy has dropped below that point), pumping may be stopped instantly.', 'Any continued intrusion of alloy into the porous layer will lead to a decrease in pressure.', 'But back-flow of alloy into well-bore is not possible since water sitting above the permeable layer cannot easily imbibe into the impermeable layer.', 'Therefore, the system remains stable without further intrusion until solidification.', 'The consequence is that the volume of the alloy being forced into the permeable layer is limited.', 'In other words, by measuring conductance at a particular height in the borehole and controlling pumping based on a change in the conductance at that particular height, alloy intrusion distance may be directly controlled.', 'FIG.', '6\na \nis a diagram of a tool assembly located in a wellbore \n600\n and adapted for plugging the wellbore.', 'The tool assembly \n670\na \nmay include a packer \n672\na\n.', 'The packer \n672\na \nis shown deployed and extending around a portion of the tool near the top of the tool and engaging the casing in the borehole.', 'Also shown is a fluid path including an inlet \n674\na \nlocated above the packer \n672\na\n, a pump \n676\na\n, and a fluid outlet \n678\na \nlocated below the packer, a bismuth alloy storage chamber \n680\na \nwhich stores the bismuth alloy and may also store thermite or another suitable reaction heater and which is adapted to release the bismuth alloy and thermite into the target area of the wellbore \n600\n, and an electrode assembly \n685\na \nwhich acts as a liquid alloy position monitor and is located at the bottom of the tool assembly.', 'The tool \n670\na \nmay also include a controller \n688\na \ncoupled to both the electrode assembly \n685\na \nand the pump \n676\na\n.', 'The controller \n688\na \nuses the output of the electrode assembly to control the pump \n676\na\n, i.e., to stop the pump when the electrode assembly indicates that the conductance being measured has dropped.', 'According to one aspect, since the alloy expands as it solidifies once pumping is stopped, there is a chance that the electrode assembly \n685\na\n, and hence the tool assembly \n670\na \nmay be “frozen in” by the alloy.', 'Thus, in one embodiment, the electrodes are mounted on a detachable mount that may be left behind.', 'Alternatively, the electrodes may be protruding pin electrodes (as suggested by \nFIG.', '6\na\n) with a sacrifical tension joint that may be broken off.', 'Replacement electrodes may be provided on the tool for later use in another borehole.', 'As another alternative, the electrode assembly \n685\na \nmay be provided with the necessary electronics to drive a finite current through the electrodes for measuring conductance.', 'If the electrodes are detected to be frozen in by friction, the alloy directly around the electrodes may be melted through additional circuitry by resistive heating thereby permitting the tool with its electrodes to be pulled out.', 'Another tool assembly adapted to plug a wellbore is seen in \nFIG.', '6\nb\n.', 'Tool assembly \n670\nb \nis similar to tool assembly \n670\na \nin that it may include a packer \n672\nb \n(shown deployed and extending around a portion of the tool near the top of the tool and engaging the casing in the borehole), a fluid path including an inlet \n674\nb \nlocated above the packer \n672\nb\n, a pump \n676\nb\n, and a fluid outlet \n678\nb \nlocated below the packer, a bismuth alloy storage chamber (not shown) which stores the bismuth alloy and may also store thermite or another suitable reaction heater and which is adapted to release the bismuth alloy and thermite into the target area of the wellbore \n600\n, and an electrode assembly \n685\nb \nwhich acts as a liquid alloy position monitor and is located at the bottom of the tool assembly.', 'The tool \n670\nb \nmay also include a controller \n688\nb \ncoupled to both the electrode assembly \n685\nb \nand the pump \n676\nb\n.', 'The controller \n688\nb \nuses the output of the electrode assembly to control the pump \n676\nb\n; i.e., to stop the pump when the electrode assembly indicates that the conductance being measured has dropped.', 'As seen in \nFIG. \n6\nb\n, the electrode assembly \n685\nb \nis provided with telescoping pistons \n690\nb \nso that the electrode assembly may be retracted via linear actuation; i.e., pulled back toward the body of the tool.', 'In order to avoid a resulting pressure variation, the tool assembly \n600\nb \nis shown to include a fluid reservoir cavity \n692\nb \nthat has holes for pressure and fluid communication and which dispenses a volume of fluid into the borehole equal to the volume displacement of the retracted electrode assembly.', 'Thus, no pressure change occurs within the isolated section of the borehole.', 'Another embodiment of a tool assembly for plugging a wellbore is seen in \nFIG.', '6\nc\n.', 'Tool assembly \n670\nc \nis similar to tool assemblies \n670\na \nand \n670\nb \nin that it may include a packer \n672\nc \n(shown deployed and extending around a portion of the tool near the top of the tool and engaging the casing in the borehole), a fluid path including an inlet \n674\nc \nlocated above the packer \n672\nc\n, a pump \n676\nc\n, and a fluid outlet \n678\nc \nlocated below the packer, a bismuth alloy storage chamber \n680\nc \nwhich stores the bismuth alloy and may also store thermite or another suitable reaction heater and which is adapted to release the bismuth alloy and thermite into the target area of the wellbore \n600\n, and an electrode assembly \n685\nc \nwhich acts as a liquid alloy position monitor and is located at the bottom of the tool assembly.', 'The tool \n670\nc \nmay also include a controller \n688\nc \ncoupled to both the electrode assembly \n685\nc \nand the pump \n676\nc\n.', 'The controller \n688\nc \nuses the output of the electrode assembly to control the pump \n676\nc\n; i.e., to stop the pump when the electrode assembly indicates that the conductance being measured has dropped.', 'As seen in \nFIG.', '6\nc\n, the electrode assembly \n685\nc \nincludes a plurality of electrode pairs \n695\n which are adapted to detect conductance transition along the depth of the well and accordingly permit the controller \n688\nc \nto ascertain the position of the alloy.', 'The intrusion rate of alloy into the permeable layer then may be inferred from the rate of change of position and temperature in order to account for alloy expansivity.', 'Based on this, an estimation may be made as to when the sonde bottom may be cleared of the alloy (including solidification), and the pump \n676\nc \nmay be stopped accordingly.', 'Using any of the tools of \nFIGS.', '6\na\n-\n6\nc\n, or any other tool permitting pressure to be applied to the bismuth alloy, and using the method of \nFIG.', '5\n, a bismuth alloy plug is generated in the wellbore.', 'FIG.', '7\n is a diagram of a solidified plug \n700\n generated in a wellbore located at the interface of a permeable layer and an impermeable layer.', 'Plug \n700\n is shown having a first cylindrical body portion \n710\n, a dendritic web \n711\n (almost like a fuzzy beard) taking the form of the pores of the formation extending around the outer surface of a lower portion of the first solid cylinder portion, a second cylindrical body portion \n712\n of smaller diameter than the first cylindrical body portion extending above the first solid cylinder portion, a first end \n715\n shaped by the shape of the shot-catcher (e.g., conical) extending below the first cylindrical body portion.', 'In some embodiments, where the impermeable layer is etched before plug formation, the plug \n700\n may include one or more threads \n720\n extending proud of and running upwards along the top portion of the cylindrical first body portion.', 'As with plugs \n300\na \nand \n300\nb\n, these threads may be helical, and/or may include a combination of (i) vertical and (ii) horizontal or arced ribs.', 'In addition, as previously described with respect to \nFIGS.', '3\na\n-\n3\nc\n, in some embodiments, the top portion of the first cylindrical body portion \n710\n may be tapered, and in some embodiments, a shoulder of the plug at the intersection of the first and second cylindrical body portions may have a spiral or concentric connected rings increasing in depth toward the middle of the plug.', 'Turning now to \nFIG.', '8\n, a schematic diagram is provided for a system for the rigless plugging an offshore wellbore \n800\n.', 'Wellbore \n800\n is seen traversing a formation \n810\n having a surface at seabed \n801\n.', 'A ship \n890\n is shown floating above the wellbore, and a cable or coil \n892\n (e.g., a wireline, slickline or coiled tube) is shown extending from the ship down into the wellbore \n800\n.', 'Extending from the cable or coil is a laser tool \n899\n as previously described which is used for preparing the wellbore—formation wall interface according to any of the previously described arrangements.', 'In one embodiment, a tool string is provided with the laser tool \n899\n and a bismuth alloy plug generation tool assembly \n870\n such as previously described with respect to any of tools \n670\na\n, \n670\nb \nand \n670\nc\n.', 'If desired, a separate barrier (umbrella) deployment tool (not shown) may be part of the string.', 'Where the tool string is provided, the laser tool is located above the bismuth alloy plug generation tool so that the laser tool can prepare a portion of the wellbore, and then the tool string may be pulled upward to locate the umbrella or barrier just below the prepared area of the wellbore and the bismuth alloy plug generation tool above the prepared area of the wellbore.', 'Alternatively, the laser tool \n899\n may be run separately from the bismuth alloy plug generation tool assembly \n870\n (and barrier deployment tool), so that the laser tool \n899\n is first deployed from the ship to prepare the wellbore—formation wall interface.', 'When the preparation is completed, the laser tool \n899\n is withdrawn, and the bismuth alloy plug generation tool assembly \n870\n is deployed.', 'Some of the methods and processes described above can be performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any particular device type or system.', 'The processor may include a computer system.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, or general purpose computer) for executing any of the methods and processes described above.', 'The computer system may further include a memory such as a semiconductor memory device (e.g., a RAM, ROM, PROM, EEPROM, or Flash-Programmable RAM), a magnetic memory device (e.g., a diskette or fixed disk), an optical memory device (e.g., a CD-ROM), a PC card (e.g., PCMCIA card), or other memory device.', 'Some of the methods and processes described above can be implemented as computer program logic for use with the computer processor.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Alternatively or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.', 'Although several example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from the scope of this disclosure.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure.']

['1.', 'A method for rigless plugging of an offshore wellbore having a casing and cement surrounding the casing and traversing a formation, comprising:\nlocating a relatively permeable layer of the formation adjacent a relatively impermeable cap rock layer of the formation;\npreparing an interface of said formation and said wellbore at said relatively permeable layer by extending a tool into the wellbore without a rig to remove the casing and cement along a selected portion of the wellbore along said relatively permeable layer to form a cavity with a shoulder;\nusing a wellbore bismuth alloy deployment tool, deploying bismuth alloy into the wellbore at said prepared interface and into the casing above said prepared interface;\ncausing the deployed bismuth alloy to become liquid;\napplying pressure to the liquid bismuth alloy to force some of the liquid bismuth alloy into the permeable layer;\npermitting said bismuth alloy to solidify to form a plug in said wellbore and in said permeable layer at said prepared interface and into the casing above said prepared interface with an excess pressure of the alloy as it solidifies along a desired seal height distance relative to the formation fluid pressure; and\ndetermining an amount of bismuth alloy to deploy, wherein said determining an amount of bismuth alloy comprises determining a minimum volume of bismuth alloy VTA+Va where VTA is a total bismuth alloy volume other than cylindrical portions of the plug and Va is a bismuth alloy volume of the cylindrical portions of the plug, and VTA=VA+VC+Vu where VA is a volume that penetrates into the relatively permeable layer, VC is a volume of the grooves, if any, etched into the relatively impermeable layer, and Vu is a volume in the barrier below the cavity.', '2.', 'The method of claim 1, further comprising, prior to deploying said amount of bismuth alloy into the wellbore, deploying a barrier in the wellbore just at or below a groove in the formation.', '3.', 'The method of claim 1, wherein said determining an amount of bismuth alloy comprises determining the bismuth alloy volume of the cylindrical portions of the plug substantially according to\nwhere n is a radius of the cavity, rc is a radius of the casing, Hc is a height of the cavity where the casing is removed, H is a melted alloy height required to obtain an excess pressure of the plug, VR is a casing volume removed above Hc, and VT is a volume of a tapered area, if any, of said shoulder.', '4.', 'A method for rigless plugging of an offshore wellbore having a casing and cement surrounding the casing and traversing a formation, comprising:\nlocating a relatively permeable layer of the formation adjacent to a relatively impermeable cap rock layer of the formation;\npreparing an interface of said formation and said wellbore at said relatively permeable layer by using a tool extended by wireline, slickline or coiled tubing into the wellbore to remove the casing and cement along a selected portion of the wellbore along said relatively permeable layer to form a cavity with a shoulder;\nusing a wellbore bismuth alloy deployment tool, deploying bismuth alloy into the wellbore at said prepared interface and into the casing above said prepared interface;\ncausing the deployed bismuth alloy to become liquid;\napplying pressure to the liquid bismuth alloy to force some of the liquid bismuth alloy into the permeable layer; and\npermitting said bismuth alloy to solidify to form a plug in said wellbore and in said permeable layer at said prepared interface and into the casing above said prepared interface with an excess pressure of the alloy as it solidifies along a desired seal height distance relative to the formation fluid pressure, and wherein said applying pressure comprises utilizing a wellbore tool assembly including a packer and said wellbore bismuth alloy deployment tool; deploying said packer at a relatively impermeable layer of the formation; locating a tool body of the wellbore bismuth alloy deployment tool so that it extends through the packer in the wellbore with said wellbore bismuth alloy deployment tool comprising a fluid passageway having a fluid inlet located above the packer, a fluid outlet located below the packer, and a pump between said fluid inlet and fluid outlet for pumping fluid from above the packer to below the packer in the wellbore, said tool body including a bismuth alloy storage chamber storing bismuth alloy and adapted to release the bismuth alloy into the wellbore.', '5.', 'The method of claim 4, wherein said preparing an interface further comprises preparing said interface both at the permeable layer of the formation and along a portion of the adjacent relatively impermeable cap rock layer in the formation.', '6.', 'The method of claim 5, wherein said preparing an interface comprises etching at least one continuous groove in the formation at the relatively impermeable cap rock layer of the formation.', '7.', 'The method of claim 6, wherein said etching at least one continuous groove comprises etching at least one helical groove.', '8.', 'The method of claim 6, wherein said etching at least one continuous groove comprises etching a plurality of vertical grooves and a plurality of grooves having a horizontal component connecting said vertical grooves.', '9.', 'The method of claim 6, wherein said preparing an interface comprises etching at least one second groove in fluid communication with said at least one continuous groove at the shoulder between the cement and casing and rock of the impermeable layer.', '10.', 'The method of claim 4, further comprising, prior to deploying said amount of bismuth alloy into the wellbore, deploying a barrier in the wellbore just at or below a continuous groove in the formation.', '11.', 'The method of claim 10, further comprising, determining an amount of bismuth alloy to deploy, wherein said determining an amount of bismuth alloy comprises determining a minimum volume of bismuth alloy VTA+Va where VTA is a total bismuth alloy volume other than cylindrical portions of the plug and Va is a bismuth alloy volume of the cylindrical portions of the plug, and VTA=VA+VC+Vu where VA is a volume that penetrates into the relatively permeable layer, VC is a volume of the grooves, if any, etched into the relatively impermeable layer, and Vu is a volume in the barrier below the cavity.', '12.', 'The method of claim 11, wherein said determining an amount of bismuth alloy comprises determining the bismuth alloy volume of the cylindrical portions of the plug substantially according to\nwhere n is a radius of the cavity, rc is a radius of the casing, Hc is a height of the cavity where the casing is removed, H is a melted alloy height required to obtain an excess pressure of the plug, VR is a casing volume removed above Hc, and VT is a volume of a tapered area, if any, of said shoulder.', '13.', 'The method of claim 4, wherein said preparing an interface of said formation and said wellbore further comprises preparing said interface by angling said shoulder to cause the cavity to taper.\n\n\n\n\n\n\n14.', 'The method of claim 4, wherein said plug comprises a solid bismuth alloy material having a solid first cylindrical body portion, a dendritic web extending outwardly from and around at least a portion of said solid first cylindrical body portion, a solid second cylindrical body portion of smaller diameter than the first cylindrical body portion, and a shoulder being defined at a transition from said first cylindrical body portion to said second cylindrical body portion.', '15.', 'The method of claim 4, wherein said plug comprises a solid bismuth alloy material having a solid first cylindrical body portion, a dendritic web extending outwardly from and around at least a portion of said solid first cylindrical body portion, a solid second cylindrical body portion of smaller diameter than the first cylindrical body portion, and a shoulder being defined at a transition from said first cylindrical body portion to said second cylindrical body portion.']

['FIG.', '1 is a diagram of a wellbore in a formation prepared for plugging at an impermeable layer.; FIG.', '2 is a flow chart of a method for plugging an abandoned wellbore at an impermeable layer.; FIG.', '3a is a diagram of a first solidified plug generated in a wellbore.; FIG.', '3b is a diagram of a second solidified plug generated in a wellbore.; FIG.', '3c is a diagram of a third solidified plug generated in a wellbore.; FIG.', '4 is a diagram of a wellbore in a formation prepared for plugging at the interface of a permeable layer and an impermeable layer.; FIG.', '5 is a flow chart of another method for plugging an abandoned wellbore at a permeable layer.; FIG.', '6a is a diagram of a first tool assembly located in a wellbore and adapted for plugging the wellbore.; FIG.', '6b is a diagram of a second tool assembly located in a wellbore and adapted for plugging the wellbore.; FIG.', '6c is a diagram of a third tool assembly located in a wellbore and adapted for plugging the wellbore.; FIG.', '7 is a diagram of a solidified plug generated in a wellbore located at the interface of a permeable layer and an impermeable layer.; FIG. 8 is a schematic of a system for plugging an offshore well.; FIG.', '6a is a diagram of a tool assembly located in a wellbore 600 and adapted for plugging the wellbore.', 'The tool assembly 670a may include a packer 672a.', 'The packer 672a is shown deployed and extending around a portion of the tool near the top of the tool and engaging the casing in the borehole.', 'Also shown is a fluid path including an inlet 674a located above the packer 672a, a pump 676a, and a fluid outlet 678a located below the packer, a bismuth alloy storage chamber 680a which stores the bismuth alloy and may also store thermite or another suitable reaction heater and which is adapted to release the bismuth alloy and thermite into the target area of the wellbore 600, and an electrode assembly 685a which acts as a liquid alloy position monitor and is located at the bottom of the tool assembly.', 'The tool 670a may also include a controller 688a coupled to both the electrode assembly 685a and the pump 676a.', 'The controller 688a uses the output of the electrode assembly to control the pump 676a, i.e., to stop the pump when the electrode assembly indicates that the conductance being measured has dropped.']

US11762825

Automated system and method for processing oilfield information

May 19, 2020

Tracy Dorrington, Chiao-Fang Hsu

Schlumberger Technology Corporation

International Search Report and Written Opinion for the equivalent PCT/US2020/033568 dated Aug. 28, 2020.; Extended European Search Report issued in European Patent Application No. 20808795.7 dated May 12, 2023; 12 pages.

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2019023982; February 2019; WO

['Systems, methods, and computer-readable media of which the method includes obtaining a knowledge graph comprising elements and relationships that connect together the elements, receiving a raw oilfield data, generating structured oilfield data based on the raw oilfield data, wherein the structured oilfield data represents information about the raw oilfield data, and generating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph.', 'The unstructured data includes data about the raw oilfield data, and one or more of the elements, one or more of the relationships, or both.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority to U.S. Provisional Patent Application having Ser.', 'No. 62/850,017, which was filed on May 20, 2019 and is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nIn the oil and gas exploration and production (E&P) field, there are many types and sources of data that can form the basis for different types of analyses, including geological, rock formation types, drilling logs/events, political news, industry/technological development, journal articles, etc.', 'Domain experts constantly evolve their knowledge during their careers via news, journal articles, reports and working with their network of peers.', 'As such, the accuracy and completeness of the analysis currently relies heavily on the expertise and insights of the particular experts involved.', 'Moreover, finding the relevant information takes time for an individual as data and information is widely-disseminated and cumbersome to discover.', 'For example, fragments of the overall available data for a particular field, entity, etc. may be contained in several different sources, and the full picture may materialize by combining these fragments together.', 'Thus, insight generation and knowledge creation is largely dependent on, and greatly slowed by information gathering.', 'During the life of an E&P organization, knowledge from experts is neither completely captured nor easily transferred to others.', 'This becomes especially difficult at large scales.', 'Further, over time, the information and knowledge often gets lost and rediscovered several times, yielding inefficiency that may be inherent to such subjective, individualized data collection and organization processes.', 'SUMMARY\n \nEmbodiments of the disclosure provide a method including obtaining a knowledge graph comprising entities and relationships that connect together the entities, receiving a raw oilfield data, and generating structured oilfield data based on the raw oilfield data.', 'The structured oilfield data represents information about the raw oilfield data.', 'The method also includes generating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph.', 'The unstructured data includes data about the raw oilfield data, and one or more of the entities, one or more of the relationships, or both.\n \nEmbodiments of the disclosure further provide a computing system including one or more processors, and a memory system including one or more non-transitory, computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations.', 'The operations include obtaining a knowledge graph comprising entities and/or events and relationships that connect together the entities and/or events, receiving a raw oilfield data, and generating structured oilfield data based on the raw oilfield data.', 'The structured oilfield data represents information about the raw oilfield data.', 'The operations also include generating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph.', 'The unstructured data includes data about the raw oilfield data, and one or more of the entities and/or events, one or more of the relationships, or both.\n \nEmbodiments of the disclosure also provide a non-transitory, computer-readable medium storing instructions that, when executed by at least one processor of a computing system, cause the computing system to perform operations.', 'The operations include obtaining a knowledge graph comprising entities and/or events and relationships that connect together the entities and/or events, receiving a raw oilfield data, and generating structured oilfield data based on the raw oilfield data.', 'The structured oilfield data represents information about the raw oilfield data.', 'The operations also include generating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph.', 'The unstructured data includes data about the raw oilfield data, and one or more of the entities and/or events, one or more of the relationships, or both.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings.', 'In the figures:\n \nFIG.', '1\n illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.\n \nFIG.', '2\n illustrates a flowchart of a method for collecting oilfield data and determining insights therefrom for use in determining search results in response to a user query, according to an embodiment.\n \nFIG.', '3\n illustrates a knowledge graph, according to an embodiment.\n \nFIG.', '4\n illustrates an example of raw data, structured data, and unstructured data, according to an embodiment.\n \nFIG.', '5\n illustrates a view of a dashboard showing data associated with an entity (e.g., a basin or geographic region), which may be linked together using the knowledge graph of \nFIG.', '3\n and using the method of \nFIG.', '2\n, according to an embodiment.', 'FIG.', '6\n illustrates a schematic view of a computing system, according to an embodiment.', 'DETAILED DESCRIPTION\n \nReference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures.', 'In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention.', 'However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details.', 'In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms are only used to distinguish one element from another.', 'For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the present disclosure.', 'The first object or step, and the second object or step, are both, objects or steps, respectively, but they are not to be considered the same object or step.', 'The terminology used in the description herein is for the purpose of describing particular embodiments and is not intended to be limiting.', 'As used in this description and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will also be understood that the term “and/or” as used herein refers to and encompasses any possible combinations of one or more of the associated listed items.', 'It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.', 'Attention is now directed to processing procedures, methods, techniques, and workflows that are in accordance with some embodiments.', 'Some operations in the processing procedures, methods, techniques, and workflows disclosed herein may be combined and/or the order of some operations may be changed.\n \nFIG.', '1\n illustrates an example of a system \n100\n that includes various management components \n110\n to manage various aspects of a geologic environment \n150\n (e.g., an environment that includes a sedimentary basin, a reservoir \n151\n, one or more faults \n153\n-\n1\n, one or more geobodies \n153\n-\n2\n, etc.).', 'For example, the management components \n110\n may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment \n150\n.', 'In turn, further information about the geologic environment \n150\n may become available as feedback \n160\n (e.g., optionally as input to one or more of the management components \n110\n).', 'In the example of \nFIG.', '1\n, the management components \n110\n include a seismic data component \n112\n, an additional information component \n114\n (e.g., well/logging data), a processing component \n116\n, a simulation component \n120\n, an attribute component \n130\n, an analysis/visualization component \n142\n and a workflow component \n144\n.', 'In operation, seismic data and other information provided per the components \n112\n and \n114\n may be input to the simulation component \n120\n.', 'In an example embodiment, the simulation component \n120\n may rely on entities and/or events \n122\n.', 'Entities/events \n122\n may include earth entities or geological objects such as wells, surfaces, bodies, reservoirs, etc.', 'In the system \n100\n, the entities/events \n122\n can include virtual representations of actual physical entities that are reconstructed for purposes of simulation.', 'The entities \n122\n may include entities based on data acquired via sensing, observation, etc. (e.g., the seismic data \n112\n and other information \n114\n).', 'An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property).', 'Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.', 'Relatedly, an event of the entities/events block \n122\n may include any event directly or indirectly related to an oilfield, well production, economics of wells, etc.', 'Such events are described in greater detail below and may be modeled and/or otherwise taken into consideration via the management components \n110\n.', 'In an example embodiment, the simulation component \n120\n may operate in conjunction with a software framework such as an object-based framework.', 'In such a framework, entities may include entities based on pre-defined classes to facilitate modeling and simulation.', 'A commercially available example of an object-based framework is the MICROSOFT® .NET® framework (Redmond, Wash.), which provides a set of extensible object classes.', 'In the .NET® framework, an object class encapsulates a module of reusable code and associated data structures.', 'Object classes can be used to instantiate object instances for use in by a program, script, etc.', 'For example, borehole classes may define objects for representing boreholes based on well data.', 'In the example of \nFIG.', '1\n, the simulation component \n120\n may process information to conform to one or more attributes specified by the attribute component \n130\n, which may include a library of attributes.', 'Such processing may occur prior to input to the simulation component \n120\n (e.g., consider the processing component \n116\n).', 'As an example, the simulation component \n120\n may perform operations on input information based on one or more attributes specified by the attribute component \n130\n.', 'In an example embodiment, the simulation component \n120\n may construct one or more models of the geologic environment \n150\n, which may be relied on to simulate behavior of the geologic environment \n150\n (e.g., responsive to one or more acts, whether natural or artificial).', 'In the example of \nFIG. \n1\n, the analysis/visualization component \n142\n may allow for interaction with a model or model-based results (e.g., simulation results, etc.).', 'As an example, output from the simulation component \n120\n may be input to one or more other workflows, as indicated by a workflow component \n144\n.', 'As an example, the simulation component \n120\n may include one or more features of a simulator such as the ECLIPSE™ reservoir simulator (Schlumberger Limited, Houston Tex.), the INTERSECT™ reservoir simulator (Schlumberger Limited, Houston Tex.), etc.', 'As an example, a simulation component, a simulator, etc. may include features to implement one or more meshless techniques (e.g., to solve one or more equations, etc.).', 'As an example, a reservoir or reservoirs may be simulated with respect to one or more enhanced recovery techniques (e.g., consider a thermal process such as SAGD, etc.).', 'In an example embodiment, the management components \n110\n may include features of a commercially available framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Tex.).', 'The PETREL® framework provides components that allow for optimization of exploration and development operations.', 'The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).', 'In an example embodiment, various aspects of the management components \n110\n may include add-ons or plug-ins that operate according to specifications of a framework environment.', 'For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Tex.) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow.', 'The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Wash.) and offers stable, user-friendly interfaces for efficient development.', 'In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'FIG.', '1\n also shows an example of a framework \n170\n that includes a model simulation layer \n180\n along with a framework services layer \n190\n, a framework core layer \n195\n and a modules layer \n175\n.', 'The framework \n170\n may include the commercially available OCEAN® framework where the model simulation layer \n180\n is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.', 'As an example, a framework may include features for implementing one or more mesh generation techniques.', 'For example, a framework may include an input component for receipt of information from interpretation of seismic data, one or more attributes based at least in part on seismic data, log data, image data, etc.', 'Such a framework may include a mesh generation component that processes input information, optionally in conjunction with other information, to generate a mesh.', 'In the example of \nFIG.', '1\n, the model simulation layer \n180\n may provide domain objects \n182\n, act as a data source \n184\n, provide for rendering \n186\n and provide for various user interfaces \n188\n.', 'Rendering \n186\n may provide a graphical environment in which applications can display their data while the user interfaces \n188\n may provide a common look and feel for application user interface components.', 'As an example, the domain objects \n182\n can include entity objects, property objects and optionally other objects.', 'Entity objects may be used to geometrically represent wells, surfaces, bodies, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters.', 'For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).', 'In the example of \nFIG.', '1\n, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks.', 'The model simulation layer \n180\n may be configured to model projects.', 'As such, a particular project may be stored where stored project information may include inputs, models, results and cases.', 'Thus, upon completion of a modeling session, a user may store a project.', 'At a later time, the project can be accessed and restored using the model simulation layer \n180\n, which can recreate instances of the relevant domain objects.', 'In the example of \nFIG.', '1\n, the geologic environment \n150\n may include layers (e.g., stratification) that include a reservoir \n151\n and one or more other features such as the fault \n153\n-\n1\n, the geobody \n153\n-\n2\n, etc.', 'As an example, the geologic environment \n150\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n152\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n155\n.', 'Such information may include information associated with downhole equipment \n154\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n156\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n155\n that may be configured for communications, noting that the satellite may additionally or instead include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n150\n as optionally including equipment \n157\n and \n158\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n159\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n157\n and/or \n158\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As mentioned, the system \n100\n may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable in the PETREL® software, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, a workflow may be a process implementable in the OCEAN® framework.', 'As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).', 'Machines have proven abilities in searching, filtering, finding, and retaining information without being encumbered by large data volumes, the scalability of combining and integrating information nor the human limitation of memory endurance.', "Embodiments of the disclosure may thus provide an Exploration and Production (E&P) “Evergreen Knowledge Mind” that responds to natural language queries by making use of knowledge graphs that connect relevant information from a variety of raw data sources (e.g., news, journal articles and reports), and structures data sources (e.g., E&P companies' databases).", 'Over time, the collective intelligence of an organization may be grown through KGs where the Mind can find, connect, and store information, facilitating human users rapidly gaining insights and building knowledge about a particular area, event, entity, etc.', 'Turning to the illustrated embodiments, \nFIG.', '2\n illustrates a flowchart of a method \n200\n for collecting and organizing data, generating insights therefrom, and providing results to a user, according to an embodiment.', 'The method \n200\n may begin by building a knowledge graph connecting events and/or entities, as at \n202\n.', 'The knowledge graph may be built using any available data and/or expertise from domain experts, e.g., known facts coming from entities mentioned in different data sources about different data types, such as seismic, well, pipeline, platform, field, prospect, leasing block, basin, play, protraction, gravity, magnetic, bathymetry, and others.', 'The metadata within these sources may provide initial information about how each is related to another.', 'Entities may include various industry participants (well owners, service providers, operators, etc.) and/or government/regulatory entities, or other entities that may impact one or more aspects of the oilfield industry that may be relevant to making determinations about wells.', 'Events may include events directly related to oilfields, such as successful or unsuccessful wells, drilling events, production quotas, etc.', 'Events may also include events that indirectly impact oilfields such as political events (e.g., elections or change of leadership), geopolitical events, events indicating popular sentiment and/or the stability in a region (e.g., protests, riots, etc.), and/or the like.', 'Thus, the knowledge graph may include various entities and/or events (collectively, “elements” or “nodes”), which are linked together by connections.', 'The connections represent relationships between the various elements. \nFIG.', '3\n illustrates an example of such a knowledge graph, according to an embodiment.', 'As shown, the elements are in blocks, and the relationships are indicated by the connections therebetween.', 'The connections may be directional or not (they are directional as shown).', 'Accordingly, for example, in the graph, it is indicated that data about a company (element) may be relevant to a particular well (another element), but not all data about the well may be related to the company operating the well (i.e., as indicated by the directionality of the connection).', 'Further, the well is within a particular field, within a basin, in a field, within a continent, and the graph thus links together these elements are relevant to one another, in at least one direction, based on these relationships.', 'This is but one example among many that the knowledge graph can be used to plot relationships.', 'Thus, the relationships may represent real relationships between elements (e.g., events or entities), e.g., describing how data about one element impacts data about another element.', 'As noted above, at least some of the elements of the knowledge graph may include or be events, rather than entities, as well.', 'Thus, events may be connected using the knowledge graph, e.g., by reference to what type of entity is directly impacted or otherwise related to the event.', 'For example, an election might impact a country; successful intervention might impact a well; a geopolitical conflict might impact a continent, a basin, or a particular type of hydrocarbon; public sentiment might impact a company or a hydrocarbon, etc.', 'The knowledge graph may provide links between events, e.g., via their associations with the entities, thus indicating how an election might be linked to popular sentiment about an oilfield or a company, thereby providing insights into the impact of different events on one another and/or on the different entities.', 'Moreover, events may, in some embodiments, be a higher-level element in the graph, potentially being associated directly with two or more events, e.g., a country and a basin may be affected directly by an event.', 'Returning to \nFIG.', '2\n, the method \n200\n may include receiving new raw data, as at \n204\n.', 'For example, various industrial organizations may maintain curated (e.g., manually) databases of oilfield information.', 'Lists of oilfields and information related thereto is an example of such structured oilfield data.', 'The raw data may be new articles, journal papers, symposium presentations, logs, etc.', 'The raw data may generally be text-heavy, and thus the method \n200\n may include determining structured data (e.g., metadata) using natural language processing of the raw data, as at \n206\n.', 'Natural language processing may use keyword searching/recognition, part-of-speech tagging, etc. to recognize various characteristics of the raw data.', 'The characteristics from the raw data may be loaded into static fields or variables stored in a database, as will be described in greater detail below.', 'Once the structured data is recognized, the method \n200\n may proceed to determining unstructured data using connections and prior data in the knowledge graph, as at \n208\n.', 'Unstructured data may be data that does not have a pre-defined data model (e.g., no static fields with a predetermined set of options).', 'As mentioned above, the knowledge graph may have entities (nodes) that are connected together by relationships (connections).', 'The knowledge graph may thus aggregate or link different pieces of information gleaned from the raw data to the pertinent entity or entities and/or to a particular event.', 'Thus, various small amounts of information may be aggregated and employed to form the basis for larger-scale insights about the various entities and/or events.', 'Accordingly, the method \n200\n may include adding the unstructured data to the knowledge graph, as at \n210\n.', 'In some embodiments, the knowledge graph may use the unstructured data to add new entities (nodes) and/or relationships (connections) to the knowledge graph and thereby extend the graph, as at \n212\n, e.g., when new features, companies, etc. become apparent.', 'Similarly, the data collected and generated may be employed to reinforce connections, which may be used to affect rankings in search results, as described below.', 'The knowledge-graph building process may be iterative.', 'Thus, upon adding structure or unstructured data, the method \n200\n may loop back to determining more structured data based on additional oilfield data.', 'The knowledge graph may thus be employed to efficiently store the data and to generate insights from the aggregation of the data, rather than merely gleaning data from a single source of raw data.', 'To further illustrate the structure, unstructured, and raw data, \nFIG.', '4\n illustrates an example thereof.', 'As shown, a news article is provided, which represents the raw data.', 'By processing the raw data itself, metadata (structured data) is gleaned, and predetermined fields for the structured data (in this example, sentiment, geolocation, company mentioned, and/or event type) may be populated.', 'However, the structured data/metadata may generally relate solely to the raw data, and thus may not place the raw data in its proper context in the world of information available.', 'Thus, the knowledge graph may be employed to generate contextual understanding, i.e., unstructured data.', 'The unstructured data may not rely on static fields like the structured data but may provide additional insight to users based on the impact of the raw data.', 'Returning to \nFIG.', '2\n, with the knowledge graph built (or at least a stage of iteration thereof complete), the method \n200\n may receive a search query from a user, as at \n214\n.', 'The search query may be a request related to a location, well, basin, field, company, event, etc., e.g., one of the entities on the knowledge graph and/or an event associated therewith, and thus the query may be matched thereto, as at \n216\n.', 'This may be used to generate search results, as at \n218\n.', 'Each entity and/or event may be linked to a tremendous amount of information, much of it potentially uninteresting to the user.', 'Thus, the search results may be curated based on a variety of factors before being provided to the user.', 'For example, the search results may be ranked, as at \n220\n.', 'In some embodiments, the search results may be ranked based on historical trends.', 'For example, a particular basin may have a certain frequency of raw data collected that is related thereto; however, when a certain event occurs, the frequency of raw data collected thereto may increase rapidly.', 'The method \n200\n may recognize the anomalous activity, and determine that it is likely relevant to any searches related to that well, or its basin, the company operating the well, etc.', "Further, a user's search history and historical search result utilization may be employed to adjust rankings such that those similar to prior interactions (e.g., the present search may be for a different basin than in the past, but the user may often search for a particular type of well, and thus search results in the different basin that are related to the same type of well may be prioritized).", 'The ranking/prioritization of the search results may employ predictive and prescriptive analytics.', 'Classification, regression, or convolution neural network modeling (or other machine learning) may allow quick prediction on a few key problem domains.', 'Recommendation engine technique can be used to incorporate the user historical data and then suggest areas to focus on in the future.', 'Various ranking algorithms can sort the importance of each piece of relevant information per query and surface the most relevant results.', 'Once the search results are prioritized, the method may provide the search results to the user, as at \n222\n.', 'Accordingly, the present knowledge tree implementation may allow for an efficient search through a vast amount of data, not only by ranking the data by trends and historical importance (generally or to an individual user), but also be developing relationships between entities and/or events.', 'Thus, the data returned from a query may be curated to collect and summarize data from a wide variety of raw data sources about a particular entity and/or event, and its impact on other entities/events, even when the raw data sources do not directly mention the entity that the user initially searched for.', 'Moreover, the knowledge graph may aggregate raw data, where each bit of raw data provides a piece of the overall picture, and thus provide the overall picture, e.g., in summary or insights, to the user, without necessitating the user reviewing all the raw data.\n \nFIG.', '5\n illustrates a dashboard \n500\n of an output of the method \n200\n, e.g., using the knowledge tree of \nFIG.', '3\n, according to an embodiment.', 'For example, a user may provide an input, which may include selecting a geographical area, entering a name or otherwise selecting a particular basin, or the like.', 'A geographical depiction (e.g., map) of the region may be shown in a first window \n502\n.', 'In another window \n504\n of the dashboard \n500\n, a simplified view of the map may be shown, e.g., indicating cities, political boundaries, etc.', 'In another window \n506\n, basic basin information may be provided, e.g., an identification (e.g., assigned number, name, etc.) of the basin, a geographic location/area thereof, a geographic perimeter, subregime, and source, may also be provided.', 'Yet another window \n508\n may indicate unstructured data related to the basin and/or one or more other elements (entities or events) linked to the basin.', 'Such unstructured data may include news stories, as well as an analysis of the news stories (e.g., giving a numerical value to the sentiment toward oil extraction operations in the area, and a magnitude of those sentiments).', 'A window \n510\n may specify more detailed geological and oil E&P activities in the basin.', 'As indicated, this window \n510\n may indicate a number of surveys (3D or otherwise) that are available, a number of fields in the basin, field geological data, hydrocarbon discovery breakdown (e.g., depth, layers where hydrocarbon reservoirs were found, etc.), reservoir information, total number of wells, information that is missing for the basin, and historical and current activities by industry participants (e.g., companies) in the area.', 'This visualization of the curated data, provided by the dashboard \n500\n, generated using knowledge tree of \nFIG.', '3\n, according to the method \n200\n of \nFIG.', '2\n, may facilitate a user making a determination about the merits of oilfield activities in a particular area.', 'This data may be reliably and repeatable recovered using the method \n200\n, such that company-wide, or even industry-wide, data about a basin, or another entity, may be obtained and efficiently employed.', 'In some embodiments, the methods of the present disclosure may be executed by a computing system.', 'FIG.', '6\n illustrates an example of such a computing system \n600\n, in accordance with some embodiments.', 'The computing system \n600\n may include a computer or computer system \n601\nA, which may be an individual computer system \n601\nA or an arrangement of distributed computer systems.', 'The computer system \n601\nA includes one or more analysis modules \n602\n that are configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein.', 'To perform these various tasks, the analysis module \n602\n executes independently, or in coordination with, one or more processors \n604\n, which is (or are) connected to one or more storage media \n606\n.', 'The processor(s) \n604\n is (or are) also connected to a network interface \n607\n to allow the computer system \n601\nA to communicate over a data network \n609\n with one or more additional computer systems and/or computing systems, such as \n601\nB, \n601\nC, and/or \n601\nD (note that computer systems \n601\nB, \n601\nC and/or \n601\nD may or may not share the same architecture as computer system \n601\nA, and may be located in different physical locations, e.g., computer systems \n601\nA and \n601\nB may be located in a processing facility, while in communication with one or more computer systems such as \n601\nC and/or \n601\nD that are located in one or more data centers, and/or located in varying countries on different continents).', 'A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'The storage media \n606\n may be implemented as one or more computer-readable or machine-readable storage media.', 'Note that while in the example embodiment of \nFIG.', '6\n storage media \n606\n is depicted as within computer system \n601\nA, in some embodiments, storage media \n606\n may be distributed within and/or across multiple internal and/or external enclosures of computing system \n601\nA and/or additional computing systems.', 'Storage media \n606\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY® disks, or other types of optical storage, or other types of storage devices.', 'Note that the instructions discussed above may be provided on one computer-readable or machine-readable storage medium, or may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture).', 'An article or article of manufacture may refer to any manufactured single component or multiple components.', 'The storage medium or media may be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In some embodiments, computing system \n600\n contains one or more knowledge graph module(s) \n608\n.', 'In the example of computing system \n600\n, computer system \n601\nA includes the knowledge graph module \n608\n.', 'In some embodiments, a single knowledge graph module may be used to perform some aspects of one or more embodiments of the methods disclosed herein.', 'In other embodiments, a plurality of knowledge graph modules may be used to perform some aspects of methods herein.', 'It should be appreciated that computing system \n600\n is merely one example of a computing system, and that computing system \n600\n may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of \nFIG.', '6\n, and/or computing system \n600\n may have a different configuration or arrangement of the components depicted in \nFIG. \n6\n.', 'The various components shown in \nFIG.', '6\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices.', 'These modules, combinations of these modules, and/or their combination with general hardware are included within the scope of the present disclosure.', 'Computational interpretations, models, and/or other interpretation aids may be refined in an iterative fashion; this concept is applicable to the methods discussed herein.', 'This may include use of feedback loops executed on an algorithmic basis, such as at a computing device (e.g., computing system \n600\n, \nFIG. \n6\n), and/or through manual control by a user who may make determinations regarding whether a given step, action, template, model, or set of curves has become sufficiently accurate for the evaluation of the subsurface three-dimensional geologic formation under consideration.', 'The foregoing description, for purpose of explanation, has been described with reference to specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or limiting to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'Moreover, the order in which the elements of the methods described herein are illustrate and described may be re-arranged, and/or two or more elements may occur simultaneously.', 'The embodiments were chosen and described in order to best explain the principals of the disclosure and its practical applications, to thereby enable others skilled in the art to best utilize the disclosed embodiments and various embodiments with various modifications as are suited to the particular use contemplated.']

['1.', 'A method, comprising:\nobtaining, via one or more processors, a knowledge graph comprising elements and relationships that connect together the elements;\nreceiving, via the one or more processors, a raw oilfield data;\ngenerating, via the one or more processors, structured oilfield data based on the raw oilfield data, wherein the structured oilfield data represents information about the raw oilfield data;\ngenerating, via the one or more processors, unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph, wherein the unstructured oilfield data comprises data about the raw oilfield data, and one or more of the elements, one or more of the relationships, or both;\nadding, via the one or more processors, the unstructured oilfield data to the knowledge graph;\nreceiving, via the one or more processors, a search query; and\nproviding, via the one or more processors, search results based on the search query and the knowledge graph comprising the unstructured oilfield data.', '2.', 'The method of claim 1, wherein the elements comprise entities and events that are associated with the entities, wherein the knowledge graph provides a link between at least two of the entities and at least two of the events.', '3.', 'The method of claim 1, wherein generating, via the one or more processors, the structured oilfield data comprises natural language processing the raw oilfield data using the one or more processors.', '4.', 'The method of claim 1, wherein the structured oilfield data comprises only data about the raw oilfield data, and no data that is external to the raw oilfield data.', '5.', 'The method of claim 1, further comprising:\nmatching, via the one or more processors, the search query to one or more of the elements; and\ndetermining, via the one or more processors, the search results for the search query including unstructured oilfield data related to the one or more of the elements.', '6.', 'The method of claim 5, further comprising ranking, via the one or more processors, the search results based on historical relevance of the one or more elements or historical user data.', '7.', 'The method of claim 1, further comprising extending, via the one or more processors, the knowledge graph based on new raw oilfield data.', '8.', 'The method of claim 1, further comprising reinforcing, via the one or more processors, relationships or generating new relationships in the knowledge graph based on new raw oilfield data.', '9.', 'A computing system, comprising:\none or more processors; and\na memory system including one or more non-transitory, computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations, the operations comprising: obtaining a knowledge graph comprising entities and/or events and relationships that connect together the entities and/or the events; receiving a raw oilfield data; generating structured oilfield data based on the raw oilfield data, wherein the structured oilfield data represents information about the raw oilfield data; generating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph, wherein the unstructured oilfield data comprises data about the raw oilfield data, and one or more of the entities and/or the events, one or more of the relationships, or both; adding the unstructured oilfield data to the knowledge graph; receiving a search query; and providing search results based on the search query and the knowledge graph comprising the unstructured oilfield data.\n\n\n\n\n\n\n10.', 'The system of claim 9, wherein generating the structured oilfield data comprises natural language processing the raw oilfield data.', '11.', 'The system of claim 9, wherein the structured oilfield data comprises only data about the raw oilfield data, and no data that is external to the raw oilfield data.', '12.', 'The system of claim 9, wherein the operations further comprise:\nmatching the search query to one or more of the entities; and\ndetermining the search results for the search query including unstructured oilfield data related to the one or more of the entities.', '13.', 'The system of claim 12, wherein the operations further comprise ranking the search results based on historical relevance of the one or more entities or historical user data.', '14.', 'The system of claim 9, wherein the operations further comprise extending the knowledge graph based on new raw oilfield data.', '15.', 'The system of claim 9, wherein the operations further comprise reinforcing relationships or generating new relationships in the knowledge graph based on new raw oilfield data.', '16.', 'A non-transitory, computer-readable medium storing instructions that, when executed by at least one processor of a computing system, cause the computing system to perform operations, the operations comprising:\nobtaining a knowledge graph comprising entities and/or events and relationships that connect together the entities and/or the events;\nreceiving a raw oilfield data;\ngenerating structured oilfield data based on the raw oilfield data, wherein the structured oilfield data represents information about the raw oilfield data;\ngenerating unstructured oilfield data based on the raw oilfield data, the structured oilfield data, and the knowledge graph, wherein the unstructured oilfield data comprises data about the raw oilfield data, and one or more of the entities and/or the events, one or more of the relationships, or both;\nadding the unstructured oilfield data to the knowledge graph;\nreceiving a search query; and\nproviding search results based on the search query and the knowledge graph with comprising the unstructured oilfield data.\n\n\n\n\n\n\n17.', 'The non-transitory, computer-readable medium of claim 16, wherein generating the structured oilfield data comprises natural language processing the raw oilfield data.', '18.', 'The non-transitory, computer-readable medium of claim 16, wherein the structured oilfield data comprises only data about the raw oilfield data, and no data that is external to the raw oilfield data.', '19.', 'The non-transitory, computer-readable medium of claim 15, wherein the operations further comprise:\nmatching the search query to one or more of the entities; and\ndetermining the search results for the search query including unstructured oilfield data related to the one or more of the entities.', '20.', 'The non-transitory, computer-readable medium of claim 18, wherein the operations further comprise ranking the search results based on historical relevance of the one or more entities or historical user data.']

['FIG. 1 illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.; FIG.', '2 illustrates a flowchart of a method for collecting oilfield data and determining insights therefrom for use in determining search results in response to a user query, according to an embodiment.; FIG.', '3 illustrates a knowledge graph, according to an embodiment.; FIG.', '4 illustrates an example of raw data, structured data, and unstructured data, according to an embodiment.; FIG.', '5 illustrates a view of a dashboard showing data associated with an entity (e.g., a basin or geographic region), which may be linked together using the knowledge graph of FIG.', '3', 'and using the method of FIG.', '2, according to an embodiment.', '; FIG.', '6 illustrates a schematic view of a computing system, according to an embodiment.; FIG.', '1 illustrates an example of a system 100 that includes various management components 110 to manage various aspects of a geologic environment 150 (e.g., an environment that includes a sedimentary basin, a reservoir 151, one or more faults 153-1, one or more geobodies 153-2, etc.).', 'For example, the management components 110 may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 150.', 'In turn, further information about the geologic environment 150 may become available as feedback 160 (e.g., optionally as input to one or more of the management components 110).; FIG.', '1 also shows an example of a framework 170 that includes a model simulation layer 180 along with a framework services layer 190, a framework core layer 195 and a modules layer 175.', 'The framework 170 may include the commercially available OCEAN® framework where the model simulation layer 180 is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.; FIG. 1 also shows the geologic environment 150 as optionally including equipment 157 and 158 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 159.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 157 and/or 158 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG.', '5 illustrates a dashboard 500 of an output of the method 200, e.g., using the knowledge tree of FIG.', '3, according to an embodiment.', 'For example, a user may provide an input, which may include selecting a geographical area, entering a name or otherwise selecting a particular basin, or the like.', 'A geographical depiction (e.g., map) of the region may be shown in a first window 502.', 'In another window 504 of the dashboard 500, a simplified view of the map may be shown, e.g., indicating cities, political boundaries, etc.', 'In another window 506, basic basin information may be provided, e.g., an identification (e.g., assigned number, name, etc.) of the basin, a geographic location/area thereof, a geographic perimeter, subregime, and source, may also be provided.', 'Yet another window 508 may indicate unstructured data related to the basin and/or one or more other elements (entities or events) linked to the basin.', 'Such unstructured data may include news stories, as well as an analysis of the news stories (e.g., giving a numerical value to the sentiment toward oil extraction operations in the area, and a magnitude of those sentiments).', 'A window 510 may specify more detailed geological and oil E&P activities in the basin.', 'As indicated, this window 510 may indicate a number of surveys (3D or otherwise) that are available, a number of fields in the basin, field geological data, hydrocarbon discovery breakdown (e.g., depth, layers where hydrocarbon reservoirs were found, etc.), reservoir information, total number of wells, information that is missing for the basin, and historical and current activities by industry participants (e.g., companies) in the area.']

US11899153

Guided mode beamforming for probing open-hole and cased-hole well environments

Dec 14, 2022

Yang Liu, Ralph D'Angelo, Smaine Zeroug, Sandip Bose

SCHLUMBERGER TECHNOLOGY CORPORATION

Zeroug, S. et al., “Sonic and ultrasonic measurement applications fort cased oil wells”, Insight, 2016, 58(8), pp. 423-430.; Zeroug, S. et al., “Ultrasonic leaky-lamb wave imaging through a highly contrasting layer,” 2003 IEEE Symposium on Ultrasonics, 2003, 1, pp. 794-798.; Van Kuijk, R. et al., “A Novel Ultrasonic Cased-Hole Imager for Enhanced Cement Evaluation”, IPTC 10546, presented at the International Petroleum Technolgy Conference, Doha, Qatar, 2005, 14 pages.; Arroyo France, J. L. et al., “Sonic Investigations In and Around the Borehole,” Schlumberger Oilfield Review, Spring 2006, pp. 14-33.; Haldorsen, J. B. U. et al., “Borehole Acoustic Waves,” Haldorsen et al.; Schlumberger Oilfield Review, pp. 34-43, (Spring 2006).; Sinha, B. K. et al., “Dispersion and radial depth of investigation of borehole modes”, Geophysical Prospecting, 2004, 52(4), pp. 271-286.; Pistre, V. et al., “A Modular Wireline Sonic Tool for Measurements of 3D (Azimuthal, Radial, and Axial) Formation Acoustic Properties”, presented at the SPWLA 46th Annual Logging Symposium, New Orleans, Louisiana, U.S.A., 2005, pp. 13 pages.; Liu, Y. et al., “Theoretical and experimental investigations of acoustic waves in embedded fluid-solid multi-string structures”, Applied Physics Letters, 2017, 110, 101906, 5 pages.; Lu, C.-C. et al., “A three-dimensional dyadic Greens function for elastic waves in multilayer cylindrical structures”, Journal of Acoustical Society of America, 1995, 98(5), pp. 2825-2835.; International Search Report and Written Opinion of International Patent Application No. PCT/US2018/024247 dated Jul. 4, 2018, 15 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2018/024247 dated Oct. 3, 2019, 12 pages.; Examination Report issued in GB Application 1915446.7, dated Sep. 16, 2021 (3 pages).

3860759; January 1975; Miller; 4592031; May 27, 1986; Bradshaw; 5383114; January 17, 1995; Chambers; 7771356; August 10, 2010; Voie; 10191173; January 29, 2019; Thierry; 20060175057; August 10, 2006; Mandal; 20120120767; May 17, 2012; Vu; 20130258809; October 3, 2013; Cotton; 20150198732; July 16, 2015; Zeroug; 20150268367; September 24, 2015; Khajeh; 20150377016; December 31, 2015; Ahmad; 20160216393; July 28, 2016; Zhou; 20200049850; February 13, 2020; Liu

2015200457; December 2015; WO; 2016187239; November 2016; WO; 2017123150; July 2017; WO

['A downhole tool including at least one transmitter, a receiver array, and a controller.', 'Each receiver element of the receiver array is configured to apply variable amplification and a variable time delay to detected acoustic waveforms, wherein the variable amplification is controlled by an amplification factor assigned to the given receiver element, and wherein the variable time delay is controlled by a time delay assigned to the given receiver element.', 'The controller assigns a set of amplification factors and time delays to the receiver elements of the receiver array and combines signals resulting from the application of the variable amplification and the variable time delay to the detected acoustic waveforms such that sensitivity of the receiver elements of the receiver array is focused at a desired zone-of-interest in a wellbore corresponding to the set of amplification factors and time delays assigned to the receiver elements of the receiver array.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThe present document is a Divisional of U.S. patent application Ser.', 'No. 16/495,408, filed Sep. 19, 2019, which is the National Stage Entry of PCT/US2018/024247, filed Mar. 26, 2018, which is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/476,696, filed Mar. 24, 2017, all of which are incorporated herein by reference in their entirety.', 'BACKGROUND\n \n1.', 'Technical Field\n \nThe subject disclosure relates to acoustic apparatus, methods and systems for characterizing rock formations and completions in wellbores.', '2.', 'Related Art\n \nInterrogating rock formations in open or cased oil and gas wells with acoustics is routinely conducted with a variety of downhole measurement tools.', 'The data acquired with these measurements provide the means to estimate formation mechanical, geophysical and petrophysical properties in open-holes and cased-holes.', 'In cased-holes, the measurement data also allow for characterization of the cement sheath behind a casing string.', 'See, e.g., S. Zeroug, et al., “Sonic and ultrasonic measurement applications fort cased oil wells,” Insight, vol.', '58(8), August, 2016, pp. 423-430; S. Zeroug and B. Froelich, “Ultrasonic leaky-lamb wave imaging through a highly contrasting layer,” 2003 IEEE Symposium on Ultrasonics, Vol. 1. (2003), pp.', '794-798; and R. van Kuijk, et al., “A Novel Ultrasonic Cased-Hole Imager for Enhanced Cement Evaluation,” International Petroleum Technology Conference (IPTC), 21-23 Sep. 2005, Doha, Qatar.', '(2005).', 'Two types of measurement embodiments can be distinguished: (i) the sonic type where signals of frequencies ranging from a few hundreds of Hertz to 25 kHz are employed to excite wellbore cylindrical modes either in open or cased-hole configurations (see, e.g., Arroye, France et al., “Sonic Investigations In and Around the Borehole”, Schlumberger Oilfield Review, Spring 2006 pp.', '14-33; and Haldorsen et al., “Borehole Acoustic Waves”, Schlumberger Oilfield Review, Spring 2006, pp.', '34-43; and (ii) the ultrasonic type where signals of frequencies ranging from 50 kHz to several hundreds of kHz are used to localize acoustic energy and image specific spatial regions mostly in cased-hole configurations for cement sheath evaluation, but also for wellbore wall imaging (see, e.g., the previously cited publications to S. Zeroug, et al., and S. Zeroug and B. Froelich).', 'An advantage of the low-frequency sonic measurement is the ability to probe radially deep into the formation (e.g., about three to five wellbore diameters in an open-hole configuration) or through multiple casing strings.', 'See, Sinha, B. K. and Asvadurov, S., “Dispersion and radial depth of investigation of borehole modes”, Geophysical Prospecting, vol.', '52, 2004, pp.', '271-286, and US Patent Publ.', 'No. 2015/0198732 to Sinha, B. K. et al., entitled “Sonic logging for well integrity.”', 'However, this is achieved at the expense of poor azimuthal resolution as the acoustic energy tends to fill in the space at all azimuths.', 'The reverse is true for the high-frequency ultrasonic measurement where high azimuthal resolution is achieved but with limited radial probing—a few inches into the rock in an open-hole and not beyond the rock face in a cased-hole.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure is directed to an acoustic logging tool apparatus, and related methods and systems that provide for relatively deep radial probing with relatively high azimuthal resolution.', 'In embodiments, the acoustic logging tool includes an array of transmitter elements (transmitter array) which are spaced around the outer circumference of the tool at different azimuthal angles at a common axial location along the central tool axis.', 'Each transmitter element (which is also referred to herein as a “transducer” or a “source channel” or “channel”) is individually controllable in terms of the amplitude of a borehole guided mode acoustic signal that is emitted by the transmitter element as well as its excitation initiation time, which allows for control of variable time delay between the excitation initiation times of the transmitter elements and thus the phase of the borehole guided mode acoustic signals that are emitted by the transmitter elements.', 'Specific amplitude controls (or factors or weights) and time delays can be dynamically applied to the transmitter elements.', 'By properly adjusting the amplitude controls and time delays for the transmitter elements of the transmitter array, a composite borehole guided mode (which is referred to as a focused acoustic beam) that results from the combination of the borehole guided mode acoustic signals emitted by the array of transmitter elements can be steered and focused to probe a desired zone in the borehole environment.', 'Such control can be configured for deep probing with high azimuthal resolution by the steering and focusing of the wellbore acoustic energy azimuthally, axially, and radially.', 'In one embodiment, azimuthal localization of the focused acoustic beam can be achieved without sacrificing deep probing by configuring the transmitter elements of the transmitter array to emit borehole guided mode acoustic signals with a narrow-bandwidth in the ultrasonic frequency range.', 'The acoustic logging tool can also include an array of receiver elements (receiver array) which are spaced around the outer circumference of the tool at different azimuthal angles at a common axial location along the central tool axis.', 'The common axial location of the array of receiver elements is spaced apart from (preferably up or above) the common axial location of the array of transmitter elements along the central tool axis.', 'The array of receiver elements can be configured to detect acoustic waveforms (signals) resulting from the interaction of the focused acoustic beam generated by array of transmitter elements with the borehole environment.', 'In embodiments, the transmitter elements of the transmitter array generate a steered and focused acoustic beam through control of the excitation initiation time and amplitude of borehole guided mode acoustic signals emitted by the transmitter elements.', 'The experiment can be repeated with different excitation initiation time controls (time delays) and amplitude controls applied to the transmitter elements of the transmitter array to scan the acoustic energy through an area of interest in the borehole environment.', 'By properly adjusting the time delays and amplitude control among the transmitter elements of the transmitter array, the focused acoustic beam can be steered and focused dynamically without requiring mechanical scanning (rotation) of the acoustic logging tool.', 'In embodiments, each receiver element of the receiver array can be individually controllable in terms of an amplification factor and a time delay that are applied to acoustic waveforms that are detected by the receiver element.', 'The acoustic waveforms are electrical signals representing acoustic energy received by the receiver element.', 'The application of the time delay allows for control of variable time delay between the acoustic waveforms that are detected by the receiver elements and thus the phase of the acoustic waveforms that are detected by the receiver elements.', 'Specific amplification factors (or weights) and time delays can be dynamically applied to the receiver elements of the receiver array.', 'By properly adjusting the amplification factors and time delays for the receiver elements of the receiver array and combining the resulting signals for all of the receiver elements of the receiver array, the sensitivity of the receiver elements of the receiver array can be steered and focused to probe a desired zone in the borehole environment.', 'Such control can be configured for deep probing with high azimuthal resolution by steering and focusing the sensitivity of the receiver elements of the receiver array azimuthally, axially, and radially.', 'In such embodiments, the transmitter elements of the transmitter array can be configured to emit a focused acoustic beam in the same (or overlapping) zone in the borehole environment that is probed by the steered and focused sensitivity of the receiver elements of the receiver array.', 'However, such beam focusing operations by the transmitter elements of the transmitter array is not required and one or more other transmitter configurations (such as a monopole source, dipole source or quadropole source) can be incorporated and used by the acoustic logging tool provided that such transmitter configuration(s) produce the desired borehole guided acoustic mode signal that reaches and interacts with the desired zone in the borehole environment that is probed by the steered and focused senstivity of the receiver elements of the receiver array.', 'In embodiments, the experiment employing the steered and focused sensitivity of the receiver elements of the receiver array can be repeated with different time delays and amplification factors applied to the receiver elements of the receiver array to scan the sensitivity of the receiver elements of the receiver array through an area of interest in the borehole environment.', 'By properly adjusting the time delays and amplification factors among the receiver elements of the receiver array and combining the resulting signals for all of the receiver elements of the receiver array, the sensitivity of the receiver elements of the receiver array can be steered and focused dynamically without requiring mechanical scanning (rotation) of the acoustic logging tool.', 'The acoustic waveforms that are received by the receiver elements(s) of the receiver array from any or all experiments may be processed in order to obtain information regarding the borehole environment.', 'For example, in open-hole environments, the acoustic waveforms may be processed to provide imaging of varying velocity distributions around the borehole at high azimthual resolution.', 'Such images can be useful to detect non-uniform stress concentration around the borehole.', 'Likewise, the acoustic waveforms may be processed to provide images of a network of preferentially aligned fractures.', 'In cased-hole environments, the acoustic waveforms may be processed to determine characteristics of cement in the borehole environment and evaluate the integrity of such cement.', 'More specifically, accurate evaluation of the cement can require azimuthal resolution to detect azimuthally-localized flaws that may arise from the azimuthally non-symmetric process of cement placement and cement distribution that takes place between a rock formation and a casing (that is typically centered within the hole).', 'The same is also true for a well cased with multiple casing strings where the interest may be in interrogating with acoustics the multiple annuli for complete cement fill or placement.', 'Other applications that may utilize azimuthal localization of the acoustic energy include (i) acoustic imaging of bed boundaries situated away from the well trajectory and (ii) the use of the focused energy beam for inducing non-linear interaction in the rock formation.', 'Such nonlinear characterization requires high amplitude ultrasonic excitation, which can be achieved through the acoustic phased array focusing as described herein.', 'Additional aspects, embodiments, objects and advantages of the disclosed methods may be understood with reference to the following detailed description taken in conjunction with the provided drawings.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\nA\n is a schematic illustration of an acoustic logging tool and system in accordance with embodiments of the present disclosure.\n \nFIG.', '1\nB\n is schematic illustration of a cylindrical coordinate system which can be used to describe the three-dimensional configuration of the acoustic logging tool and the three-dimensional space of the borehole environment.\n \nFIG.', '2\nA\n is a schematic illustration of different types of borehole guided mode acoustic signals that can be emitted by the transmitter elements of the transmitter array \n120\n (or emitted by some other transmitter configuration) for guided wave propagation by the cylindrical structures (e.g., casing) of the intended borehole environment and received by the receiver elements of the receiver array \n130\n for processing.\n \nFIG.', '2\nB\n shows phase velocity dispersion curves of families of longitudinal waves (L-modes) and torsional waves (T-modes) with higher order azimuthal symmetries in a steel pipe with 4.23 inch ID and 4.75 inch OD.\n \nFIGS.', '3\nA-\n3\nF\n show modal displacement plots for a radial energy distribution study of various borehole guided modes at 115 kHz.\n \nFIGS.', '4\nA and \n4\nB\n show an acoustic logging tool having a 16-channel wellbore acoustical array in accordance with one embodiment of the present disclosure.\n \nFIG.', '5\n is a flowchart illustrating a method for angular profile calculation that results from a single transduction channel loading, in accordance with one embodiment of the present disclosure.', 'FIGS.', '6\nA and \n6\nB\n show an angular profile due to a single channel loading at different propagation distances.\n \nFIG.', '7\n is a flow chart illustrating a method for controlling the transmitter array to produce a focused acoustic beam at a desired zone in the borehole environment in accordance with one embodiment of the present disclosure.', 'FIGS.', '8\nA and \n8\nB\n show an angular profile of the focused acoustic energy of multiple channels at different propagation differences utilizing steering of the focused acoustic beam by electronic control of the transmitter array of the acoustic logging tool.\n \nFIG.', '9\n is a flowchart illustrating operations that acquire and process data representing the acoustic waveforms detected by the receiver elements of the receiver array of the acoustic logging tool to a generate a log of properties of the borehole environment in a zone of interest interrogated by a focused acoustic beam emitted by the transmitter elements of the transmitter array of the acoustic logging tool.\n \nFIG.', '10\n is a flowchart of an exemplary inversion that can be used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.\n \nFIG.', '11\n is a schematic illustration of an exemplary machine-learning algorithm that can used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.', 'FIGS.', '12\nA and \n12\nB\n show interrogation by a focused acoustic beam emitted from an acoustic logging tool as described herein for 3D scanning of formation properties in an open hole environment.\n \nFIGS.', '13\nA and \n13\nB\n show interrogation by a focused acoustic beam emitted from an acoustic logging tool as described herein for 3D scanning of azimuthal cement damage in a cased-hole environment.', 'DETAILED DESCRIPTION', 'The present disclosure is directed to an apparatus, method and system that utilizes beamforming of acoustic energy radiated within a wellbore at prescribed confined regions of the surrounding borehole environment (which is also referred to as a “wellbore” herein).', 'As will be described in more detail hereinafter, according to one embodiment, an acoustic logging tool includes a tool body that supports an array of transmitter elements (transmitter array) and an array of receiver elements (receiver array).', 'The transmitter elements of the transmitter array are spaced around the outer circumference of the tool body at different azimuthal angles at a common axial location along the central tool axis.', 'The receiver elements of the receiver array are spaced around the outer circumference of the tool body at different azimuthal angles at a common axial location along the central tool axis.', 'The axial location of the receiver array is spaced apart from (preferably up or above) the axial location of the transmitter array along the central tool axis.', 'The tool body can also house a controller for causing controlled excitation of the transmitters elements.', 'Alternatively, the controller can be external the tool body at the surface.', 'The controller provides for individual control of each transmitter element of the array in terms of the amplitude of a borehole guided mode acoustic signal that is emitted by the transmitter element as well as its excitation initiation time, which allows for control of variable time delay between the excitation initiation times of the transmitter elements and thus the phase of the borehole guided mode acoustic signals that are emitted by the transmitter elements.', 'By properly adjusting the amplitude controls (e.g., factors or weights) and the excitation initiation time (or time delays) for the transmitter elements of the array, a composite guided mode (which can be referred to as a focused acoustic beam) is formed by combination of the borehole guided mode signals emitted by the array of transmitter elements through constructive interference and steered to probe a desired zone in the borehole environment.', 'In embodiments, the desired zone in the borehole environment can be located within the full 360 degree azimthual range around the tool body and within a range of axial positions along the length of the tool body.', 'The location of the desired zone within such azimthual range and such axial range is dictated by the amplitude controls (e.g., factors or weights) and the excitation initiation time (or time delays) dynamically assigned to the transmitter elements of the array.', 'Such control can be configured for deep probing with high azimuthal resolution by the focusing of the wellbore acoustic energy azimuthally, axially, and radially.', 'In embodiments, the focused acoustic beam combines (through constructive interference) and localizes the acoustic energy of the borehole guided mode signals emitted by the array of transmitter elements such that maximal (or peak) acoustic energy occurs in the desired zone in the borehole environment.', 'For example, the focused acoustic beam can have a primary lobe with a peak acoustic energy that occurs at or near the desired zone, where such peak acoustic energy is greater than the maximum energy of secondary lobes of the acoustic beam that occur outside the desired zone.', 'The array of receiver elements of the acoustic logging tool can be configured to detect acoustic waveforms resulting from the interaction of the focused acoustic beam with the borehole environment.', 'The detected waveforms that are received by the receiver elements of the array may be processed in order to obtain information regarding the borehole environment.', 'The experiment can be repeated by dynamically assigning different excitation initiation time controls (time delays) and amplitude controls (factors or weights) to the transmitter elements of the array such that the focused acoustic beam scans through a desired area of interest in the borehole environment.', 'By properly adjusting the excitation initiation time controls (time delays) and amplitude controls (factors or weights) for the transmitter elements of the array, the focused acoustic beam can be steered and focused dynamically over an area of interest in the borehole environment without requiring mechanical scanning (rotation) of the acoustic logging tool.', 'In embodiments, each receiver element can be individually controllable in terms of an amplification factor and time delay applied to acoustic waveforms that are detected by the receiver element.', 'The control of time delay allows for control of variable time delay between the acoustic waveforms that are detected by the receiver elements and thus the phase of the acoustic waveforms that are received by the receiver elements.', 'Specific amplification controls (or factors or weights) and time delays can be dynamically applied to the receiver elements of the receiver array.', 'By properly adjusting the amplification controls and time delays for the receiver elements of the receiver array and combining the resulting signals for all of the receiver elements of the receiver array, the sensitivity of the receiver elements can be steered and focused to probe a desired zone in the borehole environment.', 'Such control can be configured for deep probing with high azimuthal resolution by the steering and focusing of the sensitivity of the receiver elements azimuthally and axially.', 'In such embodiments, the transmitter elements can be configured to emit a focused acoustic beam in the same (or overlapping) zone in the borehole environment that is probed by the steered and focused sensitivity of the receiver elements.', 'However, such beam focusing operations by the transmitter elements is not required and another transmitter configuration (such as a monopole source, dipole source or quadropole source) can be incorporated and used by the acoustic logging tool provided that such transmitter configuration produces the desired borehole guided acoustic mode signal that reaches and interacts with the desired zone in the borehole environment that is probed by the steered and focused sensitivity of the receiver elements of the receiver array.', 'In embodiments, the experiment employing the steered and focused sensitivity of the receiver elements can be repeated with different time delays and amplification controls applied to the receiver elements of the receiver array to scan the sensitivity of the receiver elements through an area of interest in the borehole environment.', 'By properly adjusting the time delays and amplification controls among the receiver elements of the receiver array, the sensitivity of the receiver elements can be steered and focused dynamically without requiring mechanical scanning (rotation) of the acoustic logging tool.', 'The borehole environment can include an open-hole geometry, in which case, the apparatus, method and system can be used to (i) localize the focused acoustic beam and/or focus the sensitivity of the receiver elements at a specific axial, azimuthal and radial zone within the rock formation for imaging purposes, or (ii) apply the focused acoustic beam/or focus the sensitivity of the receiver elements at a specific axial, azimuthal and radial zone within the rock formation to generate and measure non-linear interaction with the rock.', 'Alternatively, the borehole environment can include a cased-hole geometry (e.g. a wellbore with a completion), in which case, the acoustic energy interacts with a more complex cylindrically-layered fluid-elastic structure made of one or more (i) concentric steel casings, (ii) one or more corresponding annuli containing cement sheath or fluid, and (iii) a rock formation.', 'The cased-hole may include potential defects in the cemented annular region.', 'The apparatus, method and system can accordingly be used in the cased-hole geometry to localize the focused acoustic beam and/or focus the sensitivity of the receiver elements of the receiver array to interrogate specific regions of the structure for structural specifics such as (i) interfacial debonding between cement and casing or cement and formation or (ii) bulk defects within the cement sheath (e.g., cracking or voids).', 'Note that when an acoustic wave propagates along an open/cased wellbore geometry, complex constructive and destructive interferences occur that lead to the generation of numerous borehole guided mode signals in the cylindrically-layered fluid-elastic structures.', 'These borehole guided mode signals are dispersive in nature and their acoustic energy distribute uniquely along the radial and azimuthal directions of the borehole environment.', 'Analytical and numerical methods can be employed to understand the modal dispersive properties and energy spatial distributions.', 'Such an understanding can be leveraged for selective mode excitation and detection to address the objective of localizing the modal energy/or focus the sensitivity of the receiver elements at particular azimuthal range, axial position, and radial layer.', 'According to one aspect, generating the focused acoustic beam and/or focusing the sensitivity of the receiver elements of the receiver array in a wellbore for the purpose of investigating a desired zone of the borehole environment may use an analysis of wave propagation in the borehole environment being considered.', 'Such analysis can employ modal dispersion signatures and modal energy distributions in the form of particle displacement plots across the radial and azimuthal directions of the three components (radial, azimuthal, and axial) of wave particle displacement within the borehole environment.', 'Given a particular configuration and particular purpose, modal sensitivity and excitability studies may then be conducted to identify and select one or more borehole guided modes that can be used to interrogate the borehole environment and have the most bearing on the objective pursued.', 'In some embodiments, such analysis can be used to identify and select one or more borehole guided modes that are most sensitive to changes in the material properties of the region of interest in the borehole environment.', 'For example, probing cement imperfections at a particular annulus requires consideration of modal dispersions and energy distributions that are most affected by the presence of such imperfections.', 'As another example, amplifying acoustic energy within the rock formation at a particular distance away from a cased-hole wellbore requires consideration of modal dispersions and energy distributions that yield the largest modal amplitude at the specific region and that, additionally, are not impeded by imperfections of the cement sheath (e.g., whether within the bulk of the cement sheath or at the interfacial bonds with casing and formation).', 'In embodiments, the selection of one or more borehole guided modes can be implemented with an acoustic logging tool designed and fabricated with multi-element phased array transmitters, multi-element phased array receiver elements, and a processor.', 'In one embodiment, the array of transmitters and the array of receivers can be configured in a pitch-catch mode, where energy of the focused acoustic beam generated by the array of transmitters occurs at or near the desired zone in the borehole environment and then propagates through the borehole environment where it is sensed by the array of receivers.', 'The energy of the focused acoustic beam interacts with the borehole environment as it propagates through the borehole environment.', 'Such interaction can induce reflection, attenuation, and dispersion of the energy of the focused acoustic beam as it propagates through the borehole environment.', 'In one embodiment, the receivers may be identical in characteristics to the transmitters.', 'Regardless, features of the received signals such as estimated reflection coefficients, attenuation, and spectral content can be used to provide quantitative answers with regard to the borehole environment as discussed in more detail below.', 'Turning to \nFIG.', '1\nA\n, an acoustic logging tool is shown located in a plugged-in cased well \n50\n traversing a formation \n60\n.', 'The acoustic logging tool includes a cylindrical tool body \n105\n suspended on a wireline cable \n100\n and in communication with a processor \n110\n.', 'The well \n50\n is shown to be cased with a casing \n70\n surrounded by an annulus of cement \n80\n between the casing \n70\n and the formation \n60\n along a length of the cased well \n50\n.', 'A winch or other deployment device (not shown) can be controlled to lower or raise the wireline cable \n100\n from a rig, platform or other surface structure (not shown).', 'A liquid fluid, such as drilling mud or other borehole fluid, can fill the well \n50\n such that it occupies the space between the acoustic logging tool and the local borehole environment adjacent the tool (i.e., the casing \n70\n, the annulus of cement \n80\n, and the formation \n60\n in the cased-hole geometry shown or the formation in an open-hole geometry).', 'The acoustic logging tool may be configured for data acquisition where the tool is advanced to a desired depth in the well \n50\n and operated to emit acoustic signals that interact with the local borehole environment adjacent the tool (such as the casing \n70\n, the annulus of cement \n80\n, and the formation \n60\n) to estimate characteristics of the local borehole environment.', 'The well \n50\n may be a vertical well as shown, but is not limited thereto.', 'For example, the well or portions thereof can be vertical, deviated, horizontal and can have any selected path that traverses through the formation \n60\n.', 'The three-dimensional configuration of the acoustic logging tool and the three-dimensional space of the borehole environment can be described by a cylindrical coordinate system as shown in \nFIG.', '1\nB\n.', 'The cylindrical tool body \n105\n defines a central tool axis that extends along the length of the tool body \n105\n.', 'A reference plane is perpendicular to the central tool axis with a polar axis that defines a ray lying in the reference plane at a predefined 0° azimuthal angle.', 'Position in the cylindrical coordinate system is specified by a radial distance p from the central tool axis, an azimthual direction or angle θ in the reference plane relative to the polar axis, and a distance z from the reference plane (which is shown as a direction parallel to the central tool axis).', 'Referring back to \nFIG.', '1\nA\n, the tool body \n105\n supports an array of transmitter elements \n120\n that are spaced around the outer circumference of tool body \n105\n at different azimuthal angles θ (in a ring configuration) at a common axial location (e.g., z\nt\n) along the tool axis as shown.', 'For example, the array of transmitter elements \n120\n can include a ring of eight transmitter elements spaced at forty-five degree intervals of azimuth, or a ring of sixteen transmitter elements spaced at twenty-two and a half degree intervals of azimuth, or possibly a ring of a different number of transmitters spaced at different azimuthal intervals.', 'The tool body \n105\n may also support a number of transmitter ring configurations that are spaced axially relative to one another along the central tool axis.', 'The tool body \n105\n also supports an array of receiver elements \n130\n that are spaced around the outer circumference of tool body \n105\n at different azimuthal angles θ (in a ring configuration) at a common axial location (e.g., z\nr\n) along the tool axis as shown.', 'The common axial location (e.g., z\nr\n) of the array of receiver elements \n130\n is spaced apart from and up or above the common axial location (e.g., z\nt\n) of the array of transmitter elements \n120\n along the central tool axis as shown.', 'For example, the array of receiver elements \n130\n can include a ring of eight receiver elements spaced at forty-five degree intervals of azimuth, or a ring of sixteen receiver elements spaced at twenty-two and a half degree intervals of azimuth, or possibly a ring of a different number of receivers spaced at different azimuthal intervals.', 'The tool body \n105\n may also support a number of receiver ring configurations that are spaced axially relative to one another along the central tool axis and spaced above the transmitter ring configuration(s).', 'The tool body \n105\n can also house a controller (not shown) for controlling the transmitter elements of the transmitter array(s) and the receiver elements of the receiver array as described herein.', 'Alternatively, the controller can be external to the tool body \n105\n, such as embodied by the processor \n110\n at the surface.', 'In embodiments, the controller can provide for individual control of each transmitter element of the transmitter array(s) \n120\n in terms of the amplitude (e.g., an amplitude factor or weight) of a guided mode acoustic signal that is emitted by the transmitter element as well as its excitation initiation time.', 'The control of the excitation initiation times of the respective transmitter elements of the array(s) allows for control of variable time delay between the excitation initiation times of the transmitter elements and thus the relative phases of the guided mode acoustic signals that are emitted by the transmitter elements as described hereinafter.', 'In embodiments, each given transmitter element can be assigned a weight value in the range from a weight value W\noff \n(or 0% of maximum amplitude) where the given transmitter element is turned off and thus does not contribute to focused acoustic beam and a weight value W\nmax \n(or 100% of maximum amplitude) where the given transmitter element is operated at maximum amplitude.', 'The weight values between W\noff \nand W\nmax \ncan correspond to varying percentage of the maximum amplitude of the given transmitter element.', 'Furthermore, the given transmitter element can be assigned a time delay in a range from null or zero time delay to some predefined maximum time delay.', 'Note that each transmitter element of the array \n120\n can be configured as an electronically-controlled acoustic transducer that emits a particular borehole guided mode acoustic signal (or a particular family of borehole guided mode acoustic signals) for transmission and wave guided propagation in the borehole environment of the well \n50\n where the amplitude and excitation timing of the emitted borehole guided mode acoustic signal (or family) is electronically-controlled by the controller according to a corresponding amplification factor or weight and time delay assigned dynamically to the transmitter element.', 'In embodiments, the acoustic energy of the particular borehole guided mode acoustic signal (or a particular family of borehole guide mode acoustic signals) that is emitted by the electronically-controlled acoustic transducer is within a narrowband in the ultrasonic frequency range that extends from 1 kHz up to 2 MHZ and possibly beyond to several gigahertz.', 'The narrowband can extend over 50 kHz (and more preferably over 25 kHz or less) in this ultrasonic frequency range.', 'The electronically-controlled acoustic transducer can be an electromagnetic acoustic transducer (EMAT), piezoelectric transducer or magneto strictive transducer, provided that such transducer is configured to emit the particular guided model signal or family (e.g., L-mode or T-mode acoustic signal) for guided wave propagation by the cylindrical structure(s) of the intended borehole environment.', 'In one embodiment, the particular guided mode acoustic signal (or the particular family of guide mode acoustic signals) that is emitted by the electronically-controlled acoustic transducer is a narrowband L(m,2) guided mode family in the ultrasonic frequency range that extends from 100 kHz up to 150 kHz (\nFIG.', '2\nB\n).', 'In embodiments, the controller can controllably vary the amplitude of the emitted borehole guided mode acoustic signal (or family) emitted by the acoustic transducer by electronic control of a variable-gain amplifier that drives the acoustic transducer.', 'Furthermore, the controller can controllably vary the time delay of the emitted borehole guided mode acoustic signal (or family) emitted by the acoustic transducer by controlling the timing of the excitation signal supplied to the variable-gain amplifier that drives the acoustic transducer.', 'Other suitable schemes that control the amplitude and time delay of the acoustic transducer can also be used.', 'Although the transmitter array \n120\n is described as having a plurality of individual elements, it is not so limited.', 'For example, a single element can be segmented to create individual actuating elements.', 'For example, a cylinder or disk of piezoelectric material can be cut, grooved, diced or otherwise segmented and individually actuated to create the array of transmitters from one or more chosen shapes.', 'Also note that the transducers are not limited to the specific configurations described herein, as the transducers can be shaped and configured in any manner to allow for transmission of the guided mode acoustic signals (or family) in the intended borehole environment.', 'In embodiments, the controller can provide for individual control of each receiver element of the receiver array(s) \n130\n in terms of an amplification factor and time delay that are applied to acoustic waveforms that are detected by the receiver element.', 'The control of time delay allows for control of variable time delay between the acoustic waveforms that are detected by the receiver elements of the array(s) \n130\n and thus the phase of the acoustic waveforms that are detected by the receiver elements of the array(s) \n130\n as described hereinafter.', 'In embodiments, each given receiver element can be assigned a weight value in the range from a weight value W\noff \n(or 0% of maximum amplification) where the acoustic waveforms that are detected by the receiver element are not amplified and thus suppressed or otherwise minimized, and a weight value W\nmax \n(or 100% of maximum amplification) where the acoustic waveforms that are detected by the receiver element are amplified at a maximum amplification factor.', 'The weight values between W\noff \nand W\nmax \ncan correspond to varying percentage of the maximum amplification of the acoustic waveforms that are detected by the receiver element.', 'Furthermore, the given receiver element can be assigned a time delay in a range from null or zero time delay to some predefined maximum time delay.', 'Note that each receiver element of the array \n130\n can be configured as an acoustic transducer that receives the particular borehole guided mode acoustic signal (or a particular family of borehole guided mode acoustic signals) that travels by wave guided propagation in the borehole environment of the well \n50\n with signal processing circuitry electronically-controlled by the controller that amplifies and applies a time delay to the acoustic waveforms received by the receiver element according to a corresponding amplification factor (or weight) and time delay assigned dynamically to the receiver element.', 'In embodiments, the particular borehole guided mode acoustic signal (or a particular family of borehole guide mode acoustic signals) that is received by the acoustic transducer is within a narrowband in the ultrasonic frequency range that extends from 1 kHz up to 2 MHz and possible higher to several gigahertz.', 'The narrowband can extend over 50 kHz (and more preferably over 25 kHz or less) in this ultrasonic frequency range.', 'The acoustic transducer can be an electromagnetic acoustic transducer (EMAT), piezoelectric transducer or magneto strictive transducer, provided that such transducer is configured to received the particular guided model signal or family (e.g., L-mode or T-mode acoustic signal) that travels by wave propagation guided by the cylindrical structures of the intended borehole environment.', 'In one particular embodiment, the particular guided mode acoustic signal (or the particular family of guide mode acoustic signals) is a narrowband L(m,2) guided mode family in the ultrasonic frequency range that extends from 100 kHz up to 150 kHz (\nFIG.', '2\nB\n).', 'In embodiments, the controller can controllably vary the amplification of the acoustic waveforms detected by the acoustic transducer by electronic control of a variable-gain amplifier that processes the detected acoustic waveforms.', 'Furthermore, the controller can controllably vary the time delay of the acoustic waveforms detected by the acoustic transducer by controlling a variable delay line that processes the detected acoustic waveforms.', 'Note that the signal processing functions of the variable gain amplifier and variable delay line can be carried out in the analog domain (before analog-to-digital conversion of the detected acoustic waveforms) or in the digital domain (after analog-to-digital conversion of the detected acoustic waveforms).', 'Other suitable schemes that control the amplitude and time delay of the detected acoustic waveforms can also be used.', 'Furthermore, although the receiver array \n130\n is described as having a plurality of individual elements, it is not so limited.', 'For example, a single element can be segmented to create individual receiver elements.', 'For example, a cylinder or disk of piezoelectric material can be cut, grooved, diced or otherwise segmented and individually actuated to create the array of receivers from one or more chosen shapes.', 'Also note that the transducers are not limited to the specific configurations described herein, as the transducers can be shaped and configured in any manner to allow for reception of the guided mode acoustic signals (or family) in the intended borehole environment.', 'The processor \n110\n located on the surface (and/or alternatively located downhole and housed within the tool body \n105\n or some other tool body) may be configured to perform various functions including receiving, storing, transmitting and/or processing data from the acoustic logging tool.', 'The processor \n110\n can include a number of suitable components, such as a processors, memory, communication devices and power sources.', 'Communication can be achieved by any suitable configuration, such as electrical, optical, wireless or acoustic (e.g., mud-pulse telemetry) communication.', 'The processor \n110\n can be configured to collect and process data that represents the acoustic signals received by the receiver elements of the receiver arrays(s) \n130\n to provide desired answer products related to the borehole environment in the vicinity of the tool body \n105\n.', 'For purposes of example only, \nFIG.', '1\nA\n shows the borehole environment containing a single pipe (casing) and the disclosure describes how localization of the focused acoustic beam at a particular desired zone in this borehole environment is achieved.', 'In alternate embodiments, the wireline acoustic logging tool can be positioned in the well by other conveyance means, such as drill pipe, coiled tubing or a tractor.', 'And in other embodiments, the wireline acoustic logging tool can be operated in a open (uncased) borehole (or open-hole geometry).', 'In yet other embodiments, the acoustic logging tool can be part of a drill string that terminates at a drill bit for logging-while drilling (LWD) applications.\n \nFIG.', '2\nA\n illustrates different types of borehole guided mode acoustic signals that can be emitted by the transmitter elements of the transmitter array \n120\n (or emitted by some other transmitter configuration) for guided wave propagation by the cylindrical structures (e.g., casing) of the intended borehole environment and received by the receiver elements of the receiver array \n130\n for processing.', 'Such borehole guided mode acoustic signals include torsional waves (T-mode acoustic signals) and longitudinal waves (L-mode acoustic signals).', 'The torsional waves (T-mode acoustic signals) have shearing particle motion parallel to the circumferential direction (θ).', 'The longitudinal waves (L-mode acoustic signals) have flexural/compressional particle motion in the radial direction (ρ) and the axial direction (z) as show.\n \nFIG.', '2\nB\n shows phase velocity dispersion curves in a single steel pipe (such as pipe \n32\n) with inner and outer diameters of 4.23 and 4.75 inches, respectively.', 'Each dispersion curve line in \nFIG.', '2\nB\n represents a guided mode that exists in the pipe.', 'The pipe is a cylindrical waveguide that is analogous to the casing \n70\n of the well \n50\n shown in \nFIG.', '1\nA\n.', 'These guided modes propagate along a length of the pipe and are usually dispersive with respective to frequency.', 'On the other hand, the cased-borehole geometries are fluid-solid composite waveguides embedded in infinite formation media.', 'The borehole guided modes propagate along the length of the wellbore while leaking energy in the surrounding formation.', 'The guided modes in the cylindrical waveguide can be represented by two indices, for example L(m,N) and T(m,N), where m is the order of guided mode azimuthal symmetry, and N is the n\nth \nroot of the characteristic equation.', 'L and T represent the longitudinal and torsional nature of the waves respectively.', 'Conventionally, guided modes with the same N and various circumferential order M are often called a “mode family”.', 'When m=0, the guided modes have uniformly distributed azimuthal energy which is referred as axisymmetric waves (monopole).', 'The waves with nonzero circumferential orders are referred as higher order multi-pole waves.', 'As an example, the mode family L(m,2) seen in \nFIG.', '2\nB\n is a longitudinal mode family with mode number 2.', 'Hereinafter, for purposes of illustration only, a narrowband L(m,2) mode family centered around 115 kHz is used to demonstrate how localization of a focused acoustic beam as emitted by an array of transmitter elements is achieved.', 'While according to one aspect, the L(m,2) mode family is found to be useful in finding cement defects, it will be appreciated that other individual guided modes and mode families can be utilized if desired.', 'In order to understand the behavior of the borehole guided modes (which are guided by the cylindrical waveguide(s) of the intended borehole environment), the wave displacement and stress and energy distribution in the radial direction of a cylinder, which is referred to as mode shapes, is studied.', 'FIGS.', '3\nA-\n3\nF\n show sample mode shapes in a steel pipe within the sample modal family L(m,2).', 'The monopole mode shapes of L(0,2) as well as the higher order multi-pole waves with circumferential order up to order L(5,2) are shown.', 'As will be described hereinafter, an intelligent selection of the borehole guided mode based on a mode shape analysis can be used to localize transmitted acoustic energy to a certain radial depth in the borehole environment.', 'FIGS.', '4\nA and \n4\nB\n illustrate an example acoustic logging tool that employs an array of sixteen transmitters, an array of receivers and a controller (not shown) which controls the amplitude factors and time delays (phase) of the borehole guided mode signals emitted by the individual sixteen transmitters of the array.', 'When the sixteen transmitters (channels) are excited simultaneously, axisymmetric waves (monopole) are generated with a modal preference that determines the beam launching angle.', 'However, as explained in detail hereinafter, acoustic energy localization can be achieved by applying a proper amplitude factor and excitation time delay to each transmitter (i.e., array channel).', 'The amplitude factors and time delays that produce a focused acoustic beam at a desired zone in the borehole environment can be calculated based on the dispersive and acoustic wave fields in the borehole environment (e.g., an open or cased wellbore).', 'In case of exciting (or firing) only one of the sixteen transmitters, a partial loading condition is encountered.', 'The source influence acoustic fields are determined by the loading function, transducer size, launching angle, etc.', 'The resulting wave fields in an open or cased wellbore (e.g., a pipe) can be derived from:\n \n \n \n \n \n \n \n \n \n \n \nP\n \n \nn\n \n\u2062\n \nm\n \n \nMN\n \n \n=\n \n0\n \n \n,\n \n \n \nunless\n \n\u2062\n \n \n \nm\n \n \n=\n \n \n \nn\n \n\u2062\n \n \n \nand\n \n\u2062\n \n \n \n \nk\n \nn\n \nM\n \n \n \n=\n \n \nk\n \nm\n \nN\n \n \n \n \n \n\u2062\n \n \n \n \n \n \nP\n \n \nn\n \n\u2062\n \nm\n \n \nMN\n \n \n=\n \n \n \n-\n \n \n1\n \n4\n \n \n \n\u2062\n \n \n \n∫\n \n∫\n \n \nD\n \n \n\u2062\n \n \n(\n \n \n \n \nv\n \nn\n \n \nM\n \n*\n \n \n \n·\n \n \nT\n \nm\n \nN\n \n \n \n+\n \n \n \nv\n \nm\n \nN\n \n \n·\n \n \nT\n \nn\n \n \nM\n \n*\n \n \n \n \n \n)\n \n \n \n \n,\n \n \n \n \n \n \n(\n \n1\n \n)\n \n \n \n \n \n \n \n where P\nnm\nMN \n≠ 0 is the complex power flux in the wave propagation direction, k\nn\nM \nis the wavenumber of the unique mode such that P\nnm\nMN \n≠ 0, and v and T are the particle velocity vector and stress tensor of the n\nth \nor m\nth \ncircumferential order, i.e. the order of the Bessel functions, and M\nth \nor N\nth \nroot of the corresponding Bessel functions, i.e. the M\nth \nor N\nth \nmode group.', 'The orthogonality relation and completeness of the wave field provide basis for a Normal Mode Expansion (NME) analysis, based on which, the resulting amplitude of each normal mode generated by a specific partial loading can be evaluated.', 'For a source loading by a single transduction channel, the loading function is given by: \n \n \n \n \n \n \n \n \n \n \nT\n \np\n \n \n·\n \nn\n \n \n=\n \n \n{\n \n \n \n \n \n \n \n \n-\n \n \n \np\n \n1\n \n \n(\n \nθ\n \n)', '\u2062\n \n \n \np\n \n2\n \n \n(\n \n𝓏\n \n)\n \n \n\u2062\n \n \ne\n \nr\n \n \n \n,\n \n \n \n \n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n𝓏\n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n≤\n \nL\n \n \n,\n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \nθ\n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n≤\n \nα\n \n \n,\n \n \nr\n \n≠\n \nb\n \n \n \n \n \n \n \n \n0\n \n,\n \n \n \n \n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n𝓏\n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n>\n \nL\n \n \n,\n \n \n \nor\n \n\u2062\n \n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \nθ\n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n>\n \n \nα\n \n\u2062\n \n \n \nor\n \n\u2062\n \n \n \nr\n \n \n≠\n \nb\n \n \n \n \n \n \n,\n \n \n \n \n \n \n \n(\n \n2\n \n)\n \n \n \n \n \n \n \n where T\np \nand n are the external loading stress and the surface normal, respectively.', 'The amplitude of the L(n,M) mode (e.g., the L(m,2) mode) generated by the loading function (Equation (2)) is given by \n \n \n \n \n \n \n \n \n \n \n \nA\n \n \n+\n \nn\n \n \nM\n \n \n(\n \n𝓏\n \n)\n \n \n=\n \n \n \n-\n \n \n \n \nR\n \nnr\n \n \nM\n \n*\n \n \n \n\u2062\n \n \ne\n \n \n \n-\n \n \nik\n \nn\n \nM\n \n \n \n\u2062\n \n𝓏\n \n \n \n \n \n4\n \n\u2062\n \n \nP\n \nnn\n \nMM\n \n \n \n \n \n\u2062\n \n \n \n∫\n \n \n-\n \nα\n \n \n \n \n-\n \nα\n \n \n+\n \n \n2\n \n\u2062\n \nπ\n \n \n \n \n \n \n \nΘ\n \nr\n \nn\n \n \n(\n \n \nn\n \n\u2062\n \nθ\n \n \n)\n \n \n\u2062\n \n \n \np\n \n1\n \n \n(\n \nθ\n \n)\n \n \n\u2062\n \nd\n \n\u2062\n \nθ\n \n\u2062\n \n \n \n∫\n \n \n-\n \n∞\n \n \n \n+\n \n∞\n \n \n \n \n \n \np\n \n2\n \n \n(\n \n𝓏\n \n)\n \n \n\u2062\n \n \ne\n \n \n \nik\n \nn\n \nM\n \n \n\u2062\n \n𝓏\n \n \n \n\u2062\n \nd\n \n\u2062\n \n𝓏\n \n \n \n \n \n \n \n,\n \n \n \n \n \n(\n \n3\n \n)\n \n \n \n \n \n \n \n where R\nnr\nM* \nis the wave structure in the radial direction for mode L(n,M), and θ\nr\nn\n(nθ) is the azimuthal displacement distribution, which is basically a sinusoidal function.', 'Equation (3) indicates that for an axisymmetric loading function, for which p\n1\n(θ)=1 within 0≤θ≤2π, the first integral in Eq.', '(3) vanishes except for n=0.', 'This explains quite well the fact that only monopole modes will be generated in the case of axisymmetric loading.', 'A summation of the generated modes weighted by their corresponding amplitude factors and time delays (phases) yields the guided wave displacement/energy distribution due to a specific partial loading function.', 'An angular profile is defined as the energy displacement/energy distribution around the pipe circumference at a certain axial distance from the partial loading source.', 'According to one aspect, a method for calculating angular profile resulting from single transduction channel loading in open or cased wellbore geometries is seen in \nFIG.', '5\n.', "At \n505\n, the boundary value problem for an idealized model open or cased borehole may be solved by computational analysis with one or more processors, such as with an analytical method as described in in “A three-dimensional dyadic Green's function for elastic waves in multiplayer cylindrical structures”, Lu et al., J. Acoust.", 'Soc.', 'Am., 98(5), 1995, pp. 2825-2835, and/or with a semi-analytical finite element method as described in “Theoretical and experimental investigations of acoustic waves in embedded fluid-solid multi-string structures, Liu et al, Appl.', 'Phys.', 'Lett., 110, 2017, pg. 101906.', 'At \n510\n, dispersion curves are calculated and mode shapes are generated (as in \nFIG.', '2\nB\n).', 'A thorough analysis of the dispersion curves can lead to an intelligent selection of a specific borehole guided modal family that is advantageous in acoustic beam focusing.', 'More importantly, the analysis of mode shapes will lead to acoustic energy control in the radial direction of the wellbore.', 'Optionally, and as shown at \n512\n, \n514\n, and \n516\n, the dispersion curves and mode shapes generated at \n510\n can be calibrated with initial data acquisition to account for differences from the idealized model.', 'For example, using a standard Sonic Scanner type tool, acoustic logging waveforms may be recorded using an axial and azimuthal array of receivers at \n512\n.', 'The received waveforms may then be processed to extract the dispersion curves and mode shapes for various guided modes at \n514\n, and a modal calibration may be generated at \n516\n to calibrate the model with field measurement data.', 'The modal calibration may then be used to ensure the model is accurate.', 'At \n520\n, a modal power density (power flux) is calculated.', 'The modal power density is a physical quantity that represents the energy of the guided waves.', 'At \n530\n, one or more single transduction channel loading parameters are provided.', 'In embodiments, the single transduction loading parameters can include one or more of the following: an axial length (L) along the z direction, an azimuthal coverage (α), and loading pressures p\n1\n(θ) and p\n2\n(z).', 'Pressures p\n1\n(θ) and p\n2\n(z) represent the azimuthal and axial distribution functions of the pressures, respectively.', 'The distributions are dependent on the transduction methods, assuming a constant loading for p\n1\n(θ) and p\n2\n(z).', 'In these theoretical calculations, it can be assumed the borehole geometry are perfectly round and there is no breakout or other geometric irregularities.', 'At \n540\n, the modal power density of \n520\n and the single transduction channel loading parameter(s) of \n530\n can be used in conjunction with normal mode expansion to calculate the normal mode expansion (NME) modal amplitude ratios according to equations (2) and (3).', 'The normal mode expansion is a mathematical tool to analyze the acoustic wave field of guided modes.', 'The calculated NME modal amplitude ratios represent the normalized amplitude of guided modes that result from the loading specified by the single transduction channel loading parameter(s) provided in \n530\n.', 'Then, at \n550\n, the angular profiles at certain axial propagation distances may be generated.', 'Such angular profiles are calculated by summation of all the resulted guided modes due to the specified loading at certain propagation distances.', 'FIGS.', '6\nA and \n6\nB\n show sample angular profiles calculated at \n550\n and measured for the L(m,2) mode group at two different axial propagation distances (displaced along borehole axis z) of one meter (\nFIG.', '6\na\n) and two meters (\nFIG.', '6\nb\n) for a 22.5 degree loading (i.e., sixteen transmitters spaced equally circumferentially) at \n115\n kHz.', 'It is seen in \nFIGS.', '6\na \nand \n6\nb \nthat the azimuthal acoustic energy distribution changes and exhibits unique patterns along the propagation distance.', 'The experimental (measured) results are seen to agree well with theoretical predictions determined by the method of \nFIG.', '5\n.', 'While \nFIGS.', '5\n, \n6\nA, and \n6\nB\n are related to a single transduction channel, \nFIG.', '7\n displays a workflow utilized to localize acoustic energy in three dimensions (radially, axially and azimuthally) through multiple transduction channels.', 'The procedure can be performed by the controller of the acoustic logging tool (possibly in conjunction with control signals from another downhole tool or surface-located processor) to acquire the focusing parameters and results therefrom as described below.', 'In this embodiment, operations \n705\n, \n710\n, \n712\n, \n714\n and \n716\n are similar to steps \n505\n, \n510\n, \n512\n, \n514\n, and \n516\n of \nFIG.', '5\n and the results are used at \n718\n to study possible shapes of the borehole guided mode emitted by the transmitters of the array and select or design the transmitters of the array to emit a particular borehole guided mode or family of guided modes (such as the L(m,2) mode family).', 'Such borehole guided mode(s) propagate into the borehole environment (e.g., formation in an open borehole or a casing or surrounding cement in a cased borehole) at a characteristic radial offset (e.g., fixed radial component) from the transmitters of the array as determined and recorded at \n719\n.', 'For tuning the angular profile of the particular borehole guided mode or mode family at an axial propagation distance z from the transmitter array, the angular profile for “element 0”, i.e., the transmitter placed on the “azimuthal top” (angle=0) of a pipe, is a periodic function H(θ) with a period of 2π and θ representing the varying azimuthal direction.', 'It is also assumed that the performances of all of the transmitter elements spaced around the circumference of the borehole are identical.', 'Therefore, the angular profile of element i will be H(θ−θ\nd i \n), where θ\ni \nis the azimuthal position of the element i. Functions H(θ−θ\ni\n) come directly from the results of the angular profiles \n550\n.', 'The total angular profile G(θ) at the axial propagation distance z will be a superposition of the angular profiles of all of the elements according to:\n \n \n \n \n \n \n \n \n \n \nG\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n=\n \n \n \n \n∑\n \n \ni\n \n=\n \n0\n \n \n \nN\n \n-\n \n1\n \n \n \n \n \nA\n \n\u2061\n \n(\n \n \nθ\n \ni\n \n \n)\n \n \n\u2062\n \n \nH\n \n\u2061\n \n(\n \n \nθ\n \n-\n \n \nθ\n \ni\n \n \n \n)\n \n \n \n \n=\n \n \nA\n \n⊗\n \nH\n \n \n \n \n,\n \n \n \n \n \n(\n \n4\n \n)\n \n \n \n \n \n \n \n where A(θ\ni\n) is the weight for summed angular profiles, and ⊗ represents a convolution.', 'It will be appreciated that A(θ\ni\n) is a complex function, whose norm and phase are respectively represented by the excitation amplitude factor and time delay applied on each element.', 'Equation (4) also shows that the total angular profile is the circular convolution between the weight function, A(θ\ni\n), and the single element angular profile function, H(θ).', 'Therefore, given the excitation amplitude factors and time delays applied on the elements and the angular profile function, the total angular profile G(θ) at the axial propagation distance z can be calculated.', 'For an inverse problem (e.g., the focused angular profile tuning), an azimuthal direction θ and axial propagation distance z is input to solve for a desired total angular profile G(θ).', 'The distribution function A(θ\ni\n) that generates the desired total angular profile G(θ) can be calculated based on a deconvolution algorithm derived from Eqn.', '(4), which is: \n \nA\n(θ\ni\n)=\nG ⊗\n−1 \nH \n \n \nA\n(θ\ni\n)=FFT\n−1\n(\nG\n(ω)/\nH\n(ω))\u2003\u2003(5) \n where ⊗\n−1 \nrepresents a deconvolution.', 'Equation (5) shows that deconvolution can be fulfilled by direct and inverse (fast)', 'Fourier transforms.', 'It can be used for calculating the amplitude factors and time delays needed for angular profile tuning to achieve guided wave beam steering in the borehole environment.', 'Note that A(θ) is a complex function, therefore the amplitude factor and the time delays can be deduced from the amplitude and phase of A(θ).', 'In this manner, Eqn. (5) and the related calculations can be used to derive a model (e.g., system of equations) that relates azimuthal direction θ and axial propagation distance z specified as inputs to amplitude factors and time delays for the transmitter elements of the transmitter array that will produce a focused acoustic beam at a zone in the borehole environment that corresponds to the azimuthal direction θ and axial propagation distance z.', 'Thus, an azimuthal direction θ and axial propagation distance z can be specified as inputs to this model, and the model can be solved to determine amplitude factors and time delays for the transmitter elements of the transmitter array that will produce a focused acoustic beam at a zone in the borehole environment that corresponds to the azimuthal direction θ and axial propagation distance z.', 'In other embodiments, the model can be embodied by another representation (such as a table, array or list) that relates azimuthal direction θ and axial propagation distance z specified as inputs to amplitude factors and time delays for the transmitter elements of the transmitter array that will produce a focused acoustic beam at a zone in the borehole environment that corresponds to the azimuthal direction θ and axial propagation distance z.', 'Given the above, the operations \n730\n, \n740\n and \n750\n are similar steps to the operations of \n520\n, \n530\n, \n540\n and \n550\n of \nFIG.', '5\n to generate an angular profile at certain axial propagation distances for a single input transduction channel.', 'These results are used in the operations of \n760\n and \n770\n to derive the model that relates azimuthal direction and axial propagation distance specified as inputs to amplitude factors and time delays for the transmitter elements of the transmitter array so that the summed borehole guided mode signals generated by the transmitters of the array form a focused acoustic beam at a zone in the borehole environment that corresponds to the azimuthal direction and axial propagation distance specified by the input.', 'In embodiments, the model can be configured such that the range of azimuthal direction and axial propagation distance specified as inputs to the model cover different zones in the borehole environment.', 'For example, such zones can possibly cover zones located within the full 360 degree azimuthal range around the tool body and a range of axial positions along the length of the tool body.', 'In block \n780\n, a particular azimuthal direction and axial propagation distance that corresponds to a desired zone of interest can be specified as inputs to this model, and the model used to determine amplitude factors and time delays for the transmitter elements of the transmitter array that will produce a focused acoustic beam at the desired zone of interest.', 'Note that the radial component of the desired zone of interest, which corresponds to offset relative to the transmitter array in the radial dimension ρ in the borehole (\nFIG.', '1\nB\n), is determined by the borehole guided mode(s) emitted by the array of transmitters as described above.', 'In block \n790\n, the amplitude factors and time delays for the transmitter elements of the transmitter array as output by the model in \n770\n are applied dynamically to the transmitter elements of the transmitter array such that the transmitter elements of the transmitter array produce a focused acoustic beam at or near the desired zone of interest.', 'Note that the radial component of the resulting focused acoustic beam is determined by the borehole guided mode(s) emitted by the array of transmitters as described above.', 'Such control can be configured for deep probing with high azimuthal resolution by the focusing of the wellbore acoustic energy azimuthally, axially, and radially.', 'In order to derive the model of \n760\n, channel array parameters and borehole parameters can be provided.', 'The channel array parameters can include the number of transmitter channels and loading function parameters.', 'The borehole parameters can include borehole geometries (such as borehole radius) and material properties of the borehole.', 'These parameters are used for theoretical calculation of focal parameters.', 'At \n770\n, a deconvolution as described above with respect to equation (5) is conducted in order to find the amplitude factor and time delay for each transmitter element of the transmitter array, i.e., A(θ\ni\n).', 'In this step, the frequency domain values of the desired focused beam profile, G(ω), and the periodic function H(ω) is known or assumed.', 'The amplitude factors and time delays for each transmitter element of the transmitter array provide for superpositioning the transmitter signal waves in a manner that produces a focused acoustic beam in a desired axial and azimuthal direction as indicated at \n780\n.', 'With the radial component (e.g. radial offset) of the selected guided mode recorded in \n719\n, the amplitude factors and time delays determined at \n770\n can be used to control the emission of the selected borehole guide mode (or mode-family) by the transmitter elements of the array to produce the focused acoustic beam as indicated at \n790\n.', 'The focused acoustic beam localizes acoustic energy at a desired zone in the borehole environment.', 'This desired zone in the borehole environment lies along axial and azimuthal directions which correspond to the amplitude factors and time delays for the transmitter elements of the transmitter array as determined \n770\n at the radial component of the selected guided mode recorded in \n719\n.', 'According to one aspect, and as discussed hereinafter, such a focused acoustic beam permits measurements and determinations with respect to the surroundings of the borehole, not previously obtainable.', 'According to another aspect, by changing the selection of the first transmitter element (channel) and/or providing different amplitude factors and time delays for the transmitter elements (channels) of the transmitter array, a series of experiments may be conducted to provide a plurality of instances of the focused acoustic beam in different azimuthal directions and/or different axial directions.', 'Thus, information specific to different azimuthal directions and/or axial directions about the borehole may be obtained.', 'Using the workflow of \nFIG.', '7\n, theoretical analysis and actual experiments were conducted with an 8-channel phased transducer array placed in a steel pipe.', 'The transducers were selected for generating the L(m,2) mode group centered at 115 kHz.', 'The eight transmitters of the array were spaced circumferentially at 22.5 degrees intervals of azimuth.', 'Equation (5) was utilized to calculate the time delay and amplitude controls for a predetermined beam steering axial and azimuthal position.', 'For focusing at one meter from the source transmitters, the following amplitude factors and time delays were calculated for the transmitters as seen in Table 1.\n \n \n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \nCHANNEL NO.', 'AMPLITUDE FACTOR\n \nPHASE DELAY (μs)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1\n \n0.515\n \n2.561\n \n \n \n2\n \n0.486\n \n1.284\n \n \n \n3\n \n0.165\n \n3.009\n \n \n \n4\n \n0.628\n \n3.090\n \n \n \n5\n \n1.000\n \n0.604\n \n \n \n6\n \n0.628\n \n3.090\n \n \n \n7\n \n0.165\n \n3.009\n \n \n \n8\n \n0.486\n \n1.284', 'The theoretical results from NME calculations and the numerical results from finite-element simulation of the detection of the resulting beam at a distance of one meter are plotted n \nFIG.', '8\nA\n.', 'These results show a focused acoustic beam with a primary lobe of acoustic energy having peak acoustic energy focused at 0° azimuthal direction.', 'Note the primary lobe carries most (e.g., 80%) of the acoustic energy in a sixty degree azimuthal segment centered about the 0° azimuthal direction of its peak.', 'Also note that there are secondary lobes with maximal acoustic energy in other azimuthal directions, but the peak energy of the primary lobe is approximately twice the maximal energies of the secondary lobes.', 'This shows that the transmitter elements can be successfully arranged to generate a focused acoustic beam.', 'The same 8-channel arrangement was also analyzed for providing a focused profile at two meters, and equation (5) was utilized to calculate the time delay and amplitude factors for the transmitters which are set forth in Table 2.\n \n \n \n \n \n \n \n \n \n \nTABLE 2\n \n \n \n \n \n \nCHANNEL NO.', 'AMPLITUDE FACTOR\n \nPHASE DELAY (μs)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1\n \n0.466\n \n2.625\n \n \n \n2\n \n0.867\n \n0.710\n \n \n \n3\n \n0.654\n \n1.004\n \n \n \n4\n \n0.633\n \n3.159\n \n \n \n5\n \n1.000\n \n2.239\n \n \n \n6\n \n0.633\n \n3.159\n \n \n \n7\n \n0.654\n \n1.004\n \n \n \n8\n \n0.867\n \n0.710', 'In addition to theoretical results, thirty-six acoustic detectors were azimuthally spaced at ten degree intervals two meters from the transmitters and two sets of measurements were made.', 'The results are plotted in \nFIG.', '8\nB\n, where the measured results correspond well to the theoretical results.', 'Again, the particular 8-channel arrangement produced a focused acoustic beam with a primary lobe of acoustic energy having peak acoustic energy focused at 0° azimuthal direction.', 'Note the primary lobe carries most (e.g., 75%) of the acoustic energy in a sixty degree azimuthal segment centered about the 0° azimuthal direction of its peak.', 'Also note that there are secondary lobes with maximal acoustic energy in other azimuthal directions, but the peak energy of the primary lobe is approximately twice the maximal energies of the secondary lobes.', 'This shows that the borehole guided mode signals can be successfully combined (through constructive interference) and focused at an expected azimuthal direction and axial propagation distance.', 'Moreover, the mode selection can be used to localize the acoustic wave energy at certain radial depths.', 'Furthermore, such control can be used to steer and focus the combined borehole guided mode signals at varying azimuthal direction and axial propagation distances.', 'Therefore, the method and associated system described herein can be used for localizing wellbore acoustic energy axially, azimuthally and radially.', 'As previously suggested, it will be appreciated that the focused acoustic beam generated from the plurality of circumferentially spaced transmitters can be directed in azimuthal direction that covers the full 360 degrees around the tool.', 'This can be accomplished by changing which transmitter is considered as channel 1 and adjusting the amplitudes and phase changes of the other transmitters accordingly.', 'For example, if it is desired to change the azimuthal direction of an eight-transmitter array by ninety degrees, the transmitter previously assigned to be channel #3 may be selected as channel #1 with an amplitude factor of 0.466 and a phase delay of 2.625 μs, the transmitter previously assigned to be channel #4 may be assigned the amplitude factor of 0.867 and a phase delay of 0.710 μs, the transmitter previously assigned to be channel #5 may be assigned the amplitude factor of 0.654 and a phase delay of 1.004 μs, etc.\n \nFIG.', '9\n illustrates operations that acquire and process data representing the acoustic waveforms sensed by the receiver elements of the receiver array \n130\n of the acoustic logging tool to generate a log of properties of the borehole environment in a zone of interest interrogated by a focused acoustic beam emitted by the transmitter array \n120\n of the acoustic logging tool.', 'The operations can be carried out by the processor \n110\n that is located at the surface or housed as part of the downhole tool or other tool.', 'In block \n901\n, ultrasonic data is acquired that represents the waveforms sensed by the receiver elements of the receiver array which result from interaction of the focused acoustic beam with the borehole environment during wave guided propagation of the focused acoustic beam in the borehole environment.', 'Note that the focused acoustic beam is focused at a desired zone of interest in the borehole environment by the electronic control of the transmitter array as described herein.', 'Such data acquisition can involve analog-to-digital conversion, amplification (in the analog domain or digital domain) and spectral filtering (in the analog domain or digital domain) of waveforms detected by the receiver elements of the receiver array.', 'In block \n903\n, the acquired ultrasonic data can be processed to extract the borehole guided mode components from the acquired ultrasonic data.', 'The operations can involve narrow-band spectral filtering to extract the frequency range of the borehole guided mode components of interest.', 'For example, in the case that the focused acoustic beam is produced from constructive interference of L(m,2) guided mode signals centered around 115 KHz, narrow-band spectral filtering with a passband around 115 KHz can be used to extract the frequency range of the borehole guided mode components of such L(m,2) guided mode signals.', 'In block \n905\n, properties of the borehole environment in the zone of interest can be determined on the basis of inversion and/or machine learning of the extracted guided mode components.', 'An example of such inversion is described below with respect to \nFIG.', '10\n, and an example of such machine learning is described below with respect to \nFIG.', '11\n.', 'In block \n907\n, store and report (output) the properties of the borehole environment in the zone of interest as determined in block \n905\n can be stored and/or reported (output), for example by storing and outputting the properties of the borehole environment in the zone of interest as part of a log that is displayed on a graphical user interface.', 'In block \n909\n, the operations of \n901\n to \n907\n can be repeated for additional iterations where the focused acoustic beam is focused at different zones of interest in the borehole environment by electronic control of the operation of the transmitter array.', 'The different zones of interest can follow a circumferential path (at a fixed axial position) around the tool body to study azimuthal variations in the properties of the borehole environment.', 'The different zones of interest can follow a helical path (at varying azimuthal and axial positions) or other desired complex paths with varying azimuthal and axial positions to study azimuthal and axial variations in the properties of the borehole environment.', 'Furthermore, the tool can be moved to another depth and the operations of \n901\n to \n909\n can be repeated in order to investigate another segment of the borehole environment.\n \nFIG.', '10\n is a flowchart of exemplary inversion operations that can used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.', 'In block \n1001\n, parameters for a forward model are input.', 'In block \n1003\n, an initial guess is made for one or more properties of the borehole environment in the zone of interest.', 'In block \n1005\n, the forward model (e.g., a system of mathematical equations) is used to produce synthetic acoustic data (such as a reference dispersion curve) on the basis of the properties of the borehole environment in the zone of interest.', 'In block \n1007\n, the extracted guided mode components (block \n903\n) can be processed to produce measured acoustic data (such as measured dispersion curve).', 'In block \n1009\n, a cost function is computed based on the differences between the synthetic acoustic data of block \n1005\n and the measured acoustic data of block \n1007\n.', 'In block \n1011\n, the cost function is evaluated to determine if it satisfies one or more criteria for convergence.', 'In block \n1013\n, the operations determine if the cost function satisfies the one or more criteria for convergence.', 'If not, the operations continue to block \n1015\n.', 'If so, the operations, continue to block \n1017\n.', 'In block \n1015\n, one or more properties of the borehole environment in the zone of interest can be updated and the operations return to block \n1005\n for another iteration of the inversion processing.', 'In block \n1017\n, the properties of the borehole environment in the zone of interest that are solved by the inversion processing can be stored and/or reported, for example, by storing and outputting the properties of the borehole environment in the zone of interest as part of a log that is displayed on a graphical user interface.', 'Such inversion processing can be useful for characterizing properties of the rock formation (such as characteristics of near-wellbore stresses) at different zones of interest (at varying azimuthal and axial positions) in an open-hole environment or cement properties (such as fast and shear velocities) in different zones of interest (at varying azimuthal and axial positions) in a cased-hole environment.\n \nFIG.', '11\n is a schematic illustration of an exemplary machine-learning algorithm that can used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.', 'The machine-learning algorithm can be carried out by the processor \n110\n that is located at the surface or housed as part of the downhole tool or other tool.', 'For example, the machine learning algorithm can be used to interpret properties (such as the fill state and bond state) of cement that surrounds the casing over the range of azimuth directions θ and axial depths z of the cased well.', 'For this purpose, the acoustic waveforms sensed by the receiver array(s) of the acoustic logging tool can be acquired and processed to extract the guided mode signal components that result from the focused acoustic beam at a given zone of interest (which is referenced by a particular azimuth direction θ, radial depth ρ, and axial depth z).', 'Such guided mode signal components can be processed to obtain modal phase slowness and attenuation dispersion curves for the given zone of interest.', 'Features sensitive to the cement properties (such as the fill state and bond state) in the given zone of interest can be constructed from the modal phase slowness and attenuation dispersion curves for the given zone of interest.', 'Such features can be derived from synthetic acoustic data and can be used to train the machine learning classifier in a supervised fashion such that the trained machine learning classifier outputs classes that correspond to such features, where the classes pertain to cement properties (such as the fill state and bond state) for a variety of formations.', 'These classes can be used to characterize and diagnosis the condition of the placed cement in a cased well.', 'The trained machine learning classifier can also be used in an unsupervised fashion with features derived from the focused acoustic beam measurements of the acoustic logging tool.', 'The trained machine learning processing can be applied over different zones of interest (with varying azimuth directions θ and axial positions z) investigated by the acoustic logging tool where the classes output by the trained machine learning classifier can be used to characterize and diagnosis the condition of the placed cement in the cased well.', 'In embodiments, the receiver elements of the receiver array \n130\n can be individually controllable in terms of an amplification factor and time delay applied to acoustic waveforms that are detected by the receiver element.', 'The control of time delay allows for control of variable time delay between the acoustic waveforms that are detected by the receiver elements of the receiver array and thus the phase of the acoustic waveforms that are detected by the receiver elements of the receiver array.', 'Specific amplification controls (or factors or weights) and time delays can be dynamically applied to the receiver elements of the receiver array.', 'By properly adjusting the amplification controls and time delays for the receiver elements of the receiver array and combining the resulting signals, the sensitivity of the receiver elements can be steered and focused to probe a desired zone in the borehole environment.', 'Such control can be configured for deep probing with high azimuthal resolution by the steering and focusing of the sensitivity of the receiver elements of the receiver array azimuthally, axially, and radially.', 'In such embodiments, the transmitter elements of the transmitter array \n120\n of the tool can be configured to emit a focused acoustic beam in the same (or overlapping) zone in the borehole environment that is probed by the steered and focused sensitivity of the receiver elements of the receiver array.', 'However, such beam focusing operations by the transmitter elements are not required and another transmitter configuration (such as a monopole source, dipole source or quadropole source) can be incorporated and used by the acoustic logging tool provided that such transmitter configuration produces the desired borehole guided acoustic mode signal that reaches and interacts with the desired zone in the borehole environment that is probed by the steered and focused sensitivity of the receiver elements of the receiver array.', 'In embodiments, the experiment employing the steered and focused sensitivity of the receiver elements of the receiver array \n130\n can be repeated with different time delays and amplification controls applied to the receiver elements of the receiver array \n130\n to scan the sensitivity of the receiver elements through an area of interest in the borehole environment.', 'By properly adjusting the time delays and amplification controls among the receiver elements of the receiver array and combining the resulting signals, the sensitivity of the receiver elements of the receiver array can be steered and focused dynamically without requiring mechanical scanning (rotation) of the acoustic logging tool.', 'In order to steer and focus the sensitivity of the receiver elements of the receiver array, Eqn. (5) and the related calculations as described above can be used to derive a model (e.g., system of equations) that relates azimuthal direction θ and axial propagation distance z specified as inputs to amplification factors and time delays for the receiver elements of the receiving array \n130\n that will focus the sensitivity of the receiving array \n130\n to a zone in the borehole environment that corresponds to the azimuthal direction θ and axial propagation distance z.', 'Thus, an azimuthal direction θ and axial propagation distance z can be specified as inputs to this model, and the model can be solved to determine amplification factors and time delays for the receiver elements of the receiving array \n130\n that will focus the sensitivity of the receiving array \n130\n at the zone in the borehole environment that corresponds to the azimuthal direction θ and axial propagation distance z.', 'In other embodiments, this model can be embodied by other representations (such as a table, array or list) that relates azimuthal direction θ and axial propagation distance z specified as inputs to amplification factors and time delays for the receiver elements of the receiving array \n130\n that will focus the sensitivity of the receiving array \n130\n at the zone in the borehole environment that corresponds to the azimuthal direction θ and axial propagation distance z.\n \nFIGS.', '12\nA and \n12\nB\n show applications of the systems and method described herein that employ transmitter array beam steering and focusing and/or receiver array steering and focusing to probe a rock formation adjacent the tool in an open wellbore geometry for open-hole evaluation.', 'The radial modal energy distribution is dependent on the modal shape of the borehole guided mode waves.', 'Note that the borehole guided mode waves transmitted by the transmitter array (or other transmitter configuration of the tool) can be selected to have large energy concentration at particular radial depth range such that the measurements of the tool are sensitive to formation properties at this particular radial depth.', 'The systems and method described herein can also been used for dipole and quadrupole azimuthal steering for open-hole evaluation.', 'FIGS.', '13\nA and \n13\nB\n show applications of the systems and method described herein that employ transmitter array beam steering and focusing and/or receiver array steering and focusing to probe cement adjacent the tool in a cased wellbore geometry for cased-hole evaluation.', 'The radial modal energy distribution is dependent on the modal shape of the borehole guided mode waves.', 'Note that the borehole guided mode waves transmitted by the transmitter array (or other transmitter configuration of the tool) can be selected to have large energy concentration at particular radial depth range (for example, at annulus B in the figure) such that the measurements of the tool are sensitive to the casing/cement properties at this particular radial depth.', 'These measurements can be used for the following: \n \n \n \nLocalized azimuthal probing within the cement sheath for fluid channel, cracking, and damage imaging in a cased-hole with a single casing string.', 'Localized azimuthal probing of the cement-casing bond characterization in a cased-hole with a single casing string.', 'Localized azimuthal probing of the cement-formation bond characterization in a cased-hole with a single casing string.', 'Localized azimuthal probing within the cement sheath of the inner annulus A or the outer annulus B for fluid channel, cracking, and damage imaging in a cased-hole with a double casing string.', 'Localized azimuthal probing of the cement-casing bond characterization of the inner annulus A or the outer annulus B in a cased hole with a double casing string.', 'Localized azimuthal probing of the cement-formation bond characterization in outer annulus B in a cased-hole with a double casing string.', 'The methods described herein for transmitter array beam steering and focusing and/or receiver array steering and focusing can be performed at least partially by a processing system.', 'For example, processes, such as (i) determining a plurality of modes using acoustic data, (ii) identifying a mode-of-interest from a plurality of modes, (ii) determining a set of parameters that can be used to optimize a measurement of the well zone using a mode-of-interest, (iv) determining a plurality of modes using modeling of the wellzone; (v) processing data derived from detected acoustic waveforms, and vi) determining at least one property of a zone-of-interest using such data, can be performed using a processing system.', 'Some of the methods and processes described above can be performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any particular device type or system.', 'The processor may include a computer system.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, or general purpose computer) for executing any of the methods and processes described above.', 'The computer system may further include a memory such as a semiconductor memory device (e.g., a RAM, ROM, PROM, EEPROM, or Flash-Programmable RAM), a magnetic memory device (e.g., a diskette or fixed disk), an optical memory device (e.g., a CD-ROM), a PC card (e.g., PCMCIA card), or other memory device.', 'Some of the methods and processes described above, as listed above, can be implemented as computer program logic for use with the computer processor.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Alternatively or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.', 'Although several example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from the scope of this disclosure.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure.', "REFERENCES\n \n \n \n1. S. Zeroug, S. Bose, B. Sinha, M. Skataric, Y. Liu, and R. D'Angelo, “Sonic and ultrasonic measurement applications fort cased oil wells”, Insight, vol.", '58(8), pp. 423-430, August 2016 and in 19th World Conference on Non-Destructive Testing, June, 2016 in Munich, Germany\n \n2.', '“Ultrasonic leaky-lamb wave imaging through a highly contrasting layer,” S. Zeroug and B. Froelich, in 2003 IEEE Symposium on Ultrasonics, pages 794-798, Vol. 1.', '(2003)\n \n3.', '“A Novel Ultrasonic Cased-Hole Imager for Enhanced Cement Evaluation,” R. van Kuijk, SPE, S. Zeroug, B. Froelich, M. Allouche, S. Bose, D. Miller, J.-L. le Calvez, V. Schoepf, and A. Pagnin; International Petroleum Technology Conference (IPTC), 21-23 Sep. 2005, Doha, Qatar.', '(2005)', '4.', '“Sonic Investigations In and Around the Borehole,” Arroye, France et al.; Schlumberger Oilfield Review, pp.', '14-33, (Spring 2006)', '5.', '“Borehole Acoustic Waves,” Haldorsen et al.; Schlumberger Oilfield Review, pp.', '34-43, (Spring 2006)', '6. B. K. Sinha and S. Asvadurov, “Dispersion and radial depth of investigation of borehole modes”, Geophysical Prospecting, vol.', '52, pp.', '271-286, 2004.', '7.', 'Sinha, B. K., Lei, T. and Zeroug, S., “Sonic logging for well integrity,” US patent application Publication No 2015/0198732.', '8. Pistre, V., Kinoshita, T., Endo, T., Schilling, K., Pabon, J., Sinha, B., Plona, T., Ikegami, T., and Johnson, D., A modular wireline sonic tool for measurements of 3D formation acoustic properties, SPWLA 46\nth \nAnnual Logging Symposium, New Orleans, June 2005.', '9.', "“Theoretical and experimental investigations of acoustic waves in embedded fluid-solid multi-string structures”, Y. Liu, R. M. D'Angelo, B. K. Sinha, and S. Zeroug, Appl.", 'Phys.', 'Lett., 110, 101906, (2017)']

['1.', 'A downhole tool that uses acoustic energy to probe a wellbore traversing a subterranean formation, the downhole tool comprising:\nat least one transmitter configured to emit borehole guided mode acoustic signals that propagate in the wellbore;\na receiver array comprising a plurality of receiver elements, wherein each receiver element of the receiver array is configured to detect acoustic waveforms that result from propagation of the acoustic borehole guided mode signals in the wellbore and apply variable amplification and a variable time delay to the detected acoustic waveforms, wherein the variable amplification is controlled by an amplification factor assigned to the given receiver element, and wherein the variable time delay is controlled by a time delay assigned to the given receiver element; and\na controller that configures the at least one transmitter to emit the borehole guided mode acoustic signals that propagate in the wellbore and assigns a set of amplification factors and time delays to the receiver elements of the receiver array and combines signals resulting from the application of the variable amplification and the variable time delay to the detected acoustic waveforms such that sensitivity of the receiver elements of the receiver array is focused at a desired zone-of-interest in the wellbore corresponding to the set of amplification factors and time delays assigned to the receiver elements of the receiver array.', '2.', 'The downhole tool according to claim 1, wherein:\nthe set of amplification factors and time delays for the receiver elements of the receiver array are determined based upon a model that relates wellbore coordinates to amplification factors and time delays for the receiver elements of the receiver array that will focus the sensitivity of the receiver elements at different zones in the wellbore.', '3.', 'The downhole tool according to claim 2, wherein:\nthe model accounts for at least one borehole effect that influences propagation of the borehole guided mode acoustic signals in the wellbore.', '4.', 'The downhole tool according to claim 2, wherein:\nthe receiver elements of the receiver array are azimthully spaced about an outer circumference of the downhole tool in a ring-configuration.', '5.', 'The downhole tool according to claim 2, which is configured as a wireline tool.', '6.', 'A downhole acoustic logging system comprising:\nthe downhole tool of claim 2; and\nthe controller of the downhole tool or another processor which is configured to determine at least one property of the zone-of-interest using the combined signals output from the receiver array.']

['FIG.', '1A is a schematic illustration of an acoustic logging tool and system in accordance with embodiments of the present disclosure.', ';', 'FIG.', '1B is schematic illustration of a cylindrical coordinate system which can be used to describe the three-dimensional configuration of the acoustic logging tool and the three-dimensional space of the borehole environment.; FIG.', '2A is a schematic illustration of different types of borehole guided mode acoustic signals that can be emitted by the transmitter elements of the transmitter array 120 (or emitted by some other transmitter configuration) for guided wave propagation by the cylindrical structures (e.g., casing) of the intended borehole environment and received by the receiver elements of the receiver array 130 for processing.;', 'FIG.', '2B shows phase velocity dispersion curves of families of longitudinal waves (L-modes) and torsional waves (T-modes) with higher order azimuthal symmetries in a steel pipe with 4.23 inch ID and 4.75 inch OD.; FIGS.', '3A-3F show modal displacement plots for a radial energy distribution study of various borehole guided modes at 115 kHz.; FIGS.', '4A and 4B show an acoustic logging tool having a 16-channel wellbore acoustical array in accordance with one embodiment of the present disclosure.', '; FIG.', '5 is a flowchart illustrating a method for angular profile calculation that results from a single transduction channel loading, in accordance with one embodiment of the present disclosure.;', 'FIGS.', '6A and 6B show an angular profile due to a single channel loading at different propagation distances.; FIG.', '7 is a flow chart illustrating a method for controlling the transmitter array to produce a focused acoustic beam at a desired zone in the borehole environment in accordance with one embodiment of the present disclosure.;', 'FIGS.', '8A and 8B show an angular profile of the focused acoustic energy of multiple channels at different propagation differences utilizing steering of the focused acoustic beam by electronic control of the transmitter array of the acoustic logging tool.;', 'FIG. 9 is a flowchart illustrating operations that acquire and process data representing the acoustic waveforms detected by the receiver elements of the receiver array of the acoustic logging tool to a generate a log of properties of the borehole environment in a zone of interest interrogated by a focused acoustic beam emitted by the transmitter elements of the transmitter array of the acoustic logging tool.; FIG.', '10 is a flowchart of an exemplary inversion that can be used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.; FIG.', '11 is a schematic illustration of an exemplary machine-learning algorithm that can used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.; FIGS.', '12A and 12B show interrogation by a focused acoustic beam emitted from an acoustic logging tool as described herein for 3D scanning of formation properties in an open hole environment.;', 'FIGS.', '13A and 13B show interrogation by a focused acoustic beam emitted from an acoustic logging tool as described herein for 3D scanning of azimuthal cement damage in a cased-hole environment.;', 'FIG.', '2A illustrates different types of borehole guided mode acoustic signals that can be emitted by the transmitter elements of the transmitter array 120 (or emitted by some other transmitter configuration) for guided wave propagation by the cylindrical structures (e.g., casing) of the intended borehole environment and received by the receiver elements of the receiver array 130 for processing.', 'Such borehole guided mode acoustic signals include torsional waves (T-mode acoustic signals) and longitudinal waves (L-mode acoustic signals).', 'The torsional waves (T-mode acoustic signals) have shearing particle motion parallel to the circumferential direction (θ).', 'The longitudinal waves (L-mode acoustic signals) have flexural/compressional particle motion in the radial direction (ρ) and the axial direction (z) as show.', '; FIG.', '2B shows phase velocity dispersion curves in a single steel pipe (such as pipe 32) with inner and outer diameters of 4.23 and 4.75 inches, respectively.', 'Each dispersion curve line in FIG.', '2B represents a guided mode that exists in the pipe.', 'The pipe is a cylindrical waveguide that is analogous to the casing 70 of the well 50 shown in FIG.', '1A. These guided modes propagate along a length of the pipe and are usually dispersive with respective to frequency.', 'On the other hand, the cased-borehole geometries are fluid-solid composite waveguides embedded in infinite formation media.', 'The borehole guided modes propagate along the length of the wellbore while leaking energy in the surrounding formation.', 'The guided modes in the cylindrical waveguide can be represented by two indices, for example L(m,N) and T(m,N), where m is the order of guided mode azimuthal symmetry, and N is the nth root of the characteristic equation.', 'L and T represent the longitudinal and torsional nature of the waves respectively.', 'Conventionally, guided modes with the same N and various circumferential order M are often called a “mode family”.', 'When m=0, the guided modes have uniformly distributed azimuthal energy which is referred as axisymmetric waves (monopole).', 'The waves with nonzero circumferential orders are referred as higher order multi-pole waves.', 'As an example, the mode family L(m,2) seen in FIG.', '2B is a longitudinal mode family with mode number 2.', 'Hereinafter, for purposes of illustration only, a narrowband L(m,2) mode family centered around 115 kHz is used to demonstrate how localization of a focused acoustic beam as emitted by an array of transmitter elements is achieved.', 'While according to one aspect, the L(m,2) mode family is found to be useful in finding cement defects, it will be appreciated that other individual guided modes and mode families can be utilized if desired.; FIGS.', '4A and 4B illustrate an example acoustic logging tool that employs an array of sixteen transmitters, an array of receivers and a controller (not shown) which controls the amplitude factors and time delays (phase) of the borehole guided mode signals emitted by the individual sixteen transmitters of the array.', 'When the sixteen transmitters (channels) are excited simultaneously, axisymmetric waves (monopole) are generated with a modal preference that determines the beam launching angle.', 'However, as explained in detail hereinafter, acoustic energy localization can be achieved by applying a proper amplitude factor and excitation time delay to each transmitter (i.e., array channel).', 'The amplitude factors and time delays that produce a focused acoustic beam at a desired zone in the borehole environment can be calculated based on the dispersive and acoustic wave fields in the borehole environment (e.g., an open or cased wellbore).;', 'FIGS.', '6A and 6B show sample angular profiles calculated at 550 and measured for the L(m,2) mode group at two different axial propagation distances (displaced along borehole axis z) of one meter (FIG. 6a) and two meters (FIG.', '6b) for a 22.5 degree loading (i.e., sixteen transmitters spaced equally circumferentially) at 115 kHz.', 'It is seen in FIGS.', '6a and 6b that the azimuthal acoustic energy distribution changes and exhibits unique patterns along the propagation distance.', 'The experimental (measured) results are seen to agree well with theoretical predictions determined by the method of FIG.', '5.; FIG. 9 illustrates operations that acquire and process data representing the acoustic waveforms sensed by the receiver elements of the receiver array 130 of the acoustic logging tool to generate a log of properties of the borehole environment in a zone of interest interrogated by a focused acoustic beam emitted by the transmitter array 120 of the acoustic logging tool.', 'The operations can be carried out by the processor 110 that is located at the surface or housed as part of the downhole tool or other tool.; FIG.', '10 is a flowchart of exemplary inversion operations that can used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.; FIG.', '11 is a schematic illustration of an exemplary machine-learning algorithm that can used to infer properties of a zone of interest in the borehole environment of a well that is interrogated by a focused acoustic beam emitted from an acoustic logging tool as described herein.', 'The machine-learning algorithm can be carried out by the processor 110 that is located at the surface or housed as part of the downhole tool or other tool.', 'For example, the machine learning algorithm can be used to interpret properties (such as the fill state and bond state) of cement that surrounds the casing over the range of azimuth directions θ and axial depths z of the cased well.', 'For this purpose, the acoustic waveforms sensed by the receiver array(s) of the acoustic logging tool can be acquired and processed to extract the guided mode signal components that result from the focused acoustic beam at a given zone of interest (which is referenced by a particular azimuth direction θ, radial depth ρ, and axial depth z).', 'Such guided mode signal components can be processed to obtain modal phase slowness and attenuation dispersion curves for the given zone of interest.', 'Features sensitive to the cement properties (such as the fill state and bond state) in the given zone of interest can be constructed from the modal phase slowness and attenuation dispersion curves for the given zone of interest.', 'Such features can be derived from synthetic acoustic data and can be used to train the machine learning classifier in a supervised fashion such that the trained machine learning classifier outputs classes that correspond to such features, where the classes pertain to cement properties (such as the fill state and bond state) for a variety of formations.', 'These classes can be used to characterize and diagnosis the condition of the placed cement in a cased well.', 'The trained machine learning classifier can also be used in an unsupervised fashion with features derived from the focused acoustic beam measurements of the acoustic logging tool.', 'The trained machine learning processing can be applied over different zones of interest (with varying azimuth directions θ and axial positions z) investigated by the acoustic logging tool where the classes output by the trained machine learning classifier can be used to characterize and diagnosis the condition of the placed cement in the cased well.; FIGS.', '12A and 12B show applications of the systems and method described herein that employ transmitter array beam steering and focusing and/or receiver array steering and focusing to probe a rock formation adjacent the tool in an open wellbore geometry for open-hole evaluation.', 'The radial modal energy distribution is dependent on the modal shape of the borehole guided mode waves.', 'Note that the borehole guided mode waves transmitted by the transmitter array (or other transmitter configuration of the tool) can be selected to have large energy concentration at particular radial depth range such that the measurements of the tool are sensitive to formation properties at this particular radial depth.', 'The systems and method described herein can also been used for dipole and quadrupole azimuthal steering for open-hole evaluation.; FIGS.', '13A and 13B show applications of the systems and method described herein that employ transmitter array beam steering and focusing and/or receiver array steering and focusing to probe cement adjacent the tool in a cased wellbore geometry for cased-hole evaluation.', 'The radial modal energy distribution is dependent on the modal shape of the borehole guided mode waves.', 'Note that the borehole guided mode waves transmitted by the transmitter array (or other transmitter configuration of the tool) can be selected to have large energy concentration at particular radial depth range (for example, at annulus B in the figure) such that the measurements of the tool are sensitive to the casing/cement properties at this particular radial depth.', 'These measurements can be used for the following: Localized azimuthal probing within the cement sheath for fluid channel, cracking, and damage imaging in a cased-hole with a single casing string.', 'Localized azimuthal probing of the cement-casing bond characterization in a cased-hole with a single casing string.', 'Localized azimuthal probing of the cement-formation bond characterization in a cased-hole with a single casing string.', 'Localized azimuthal probing within the cement sheath of the inner annulus A or the outer annulus B for fluid channel, cracking, and damage imaging in a cased-hole with a double casing string.', 'Localized azimuthal probing of the cement-casing bond characterization of the inner annulus A or the outer annulus B in a cased hole with a double casing string.', 'Localized azimuthal probing of the cement-formation bond characterization in outer annulus B in a cased-hole with a double casing string.']

US11822038

Systems and methods for determining properties of porous, fluid-filled geological formations based on multi-frequency measurements

Feb 15, 2021

Siddharth Misra, Dean Homan, Yuteng Jin, John Rasmus

SCHLUMBERGER TECHNOLOGY CORPORATION

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3643738; February 1972; Dreher; 10697910; June 30, 2020; Mitchell; 20180113088; April 26, 2018; Misra; 20190233713; August 1, 2019; Chawathe; 20210033746; February 4, 2021; Misra et al.

2787301; July 2011; CA; 114235641; March 2022; CN; WO-2016176541; November 2016; WO; WO-2021076529; April 2021; WO

['Aspects of the present disclosure relate to a method for determining a contact angle, a wettability, or both, of one or more types of solid particles within a geological formation.', 'The method may include identifying a relative conductive of the type of solid particles and identifying a frequency range for one or more EM measurements.', 'The method may also include determining a contact angle associated with at least one type of solid particles within the geological formation using the electromagnetic measurements corresponding to the frequency range.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This is a continuation in part of U.S. patent application Ser.', 'No. 16/940,492, which is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/879,882, filed Jul. 29, 2019, which is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nThis disclosure relates to determining properties of porous, fluid-fluid geological formations based on multi-frequency electromagnetic measurements.', 'This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present techniques, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'Producing hydrocarbons from a wellbore drilled into a geological formation is a remarkably complex endeavor.', 'In many cases, decisions involved in hydrocarbon exploration and production may be informed by measurements from downhole well-logging tools that are conveyed deep into the wellbore.', 'The measurements may be used to infer properties and characteristics of the geological formation surrounding the wellbore.', 'The discovery and observation of resources using downhole techniques generally takes place down in the wellbore with certain sensors.', 'Electromagnetic well-logging sensors or induction well-logging sensors use electromagnetic waves to acquire measurements, which may inform the decisions involved in hydrocarbon exploration and production.', 'The composition of the geological formation may increase the complexity of the measurements by adding artifacts.', 'SUMMARY\n \nA summary of certain embodiments disclosed herein is set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.', 'One embodiment of the present disclosure relates to a method for determining a wettability of one or more types of solid particles within a geological formation.', 'The method includes identifying at least one type of solid particle within the geological formation.', 'The method also includes identifying a frequency range for an electromagnetic measurement based on the identified at least one type of solid particle within the geological formation.', 'Further, the method includes receiving a plurality of electromagnetic (EM) measurements associated with the geological formation, wherein the plurality of EM measurements are within the identified frequency range.', 'Further still, the method includes determining a contact angle associated with solid particles within the geological formation based on the received plurality of EM measurements.', 'Another embodiment of the present disclosure relates to a non-transitory, computer-readable medium comprising instructions that, when executed by at least one processor, cause the at least one processor to receive an input indicative of a conductivity of at least one solid particle present within a geological formation.', 'The instructions may also cause the processor to retrieve a mechanistic model based on a relative conductivity of the at least one solid particle.', 'Further, the instructions may cause the processor to identify a frequency range for an electromagnetic measurement based on the mechanistic model.', 'Even further, the instructions may cause the processor to receive a plurality of electromagnetic (EM) measurements associated with the geological formation, wherein the plurality of EM measurements are within the identified frequency range.', 'Further still, the instructions may cause the processor to determine a contact angle associated with solid particles within the geological formation based on the received plurality of EM measurements.', 'Another embodiment of the present disclosure relates to a system.', 'The system includes a non-transitory machine-readable medium storing a first mechanistic model and a second mechanistic model.', 'The system also includes a processor configured to execute instructions stored in the non-transitory, machine readable medium to perform operations.', 'The operations include identifying a type of solid particle present within a geological formation.', 'The operations also include identifying at least one model to use based on a relative conductivity of the type of the solid particle, wherein the model comprises the first mechanistic model, the second mechanistic model, or both.', 'Further, the operations include receiving, as an input to the identified at least one model, one or more inputs indicative of estimated properties of the porous, fluid-filled geological formation, wherein the mechanistic model correlates one or more fluid phases, compositions, or both, to a contact angle of at least one type of solid particle and correlates an interfacial polarization of the at least one type of solid particle to the contact angle of the at least one type of solid particle.', 'Further still, the operations include generating, as an output by the identified at least one model, a set of frequencies to measure by a downhole tool, wherein the set of frequencies corresponds to where frequency dispersions in conductivity, permittivity, or both are measureable.', 'Various refinements of the features noted above may be undertaken in relation to various aspects of the present disclosure.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'The brief summary presented above is intended to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings in which:\n \nFIG.', '1\n is an example of a neutron-induced gamma-ray spectroscopy system, in accordance with an embodiment;\n \nFIG.', '2\n is an example of a neutron-induced gamma-ray spectroscopy downhole tool, in accordance with an embodiment;\n \nFIG.', '3\n is an example of a process for determining properties of a fluid-filled formation, in accordance with an embodiment;\n \nFIG.', '4\n is an example illustration of a cross section of a volume that includes a solid suspended in an oil-water media, in accordance with an embodiment;\n \nFIG.', '5\nA\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;\n \nFIG.', '5\nB\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;\n \nFIG.', '5\nC\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;\n \nFIG.', '5\nD\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;\n \nFIG.', '6\nA\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different oil saturations with a contact angle of 30°, in accordance with an embodiment;\n \nFIG.', '6\nB\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different oil saturations with a contact angle of 90°, in accordance with an embodiment;\n \nFIG.', '6\nC\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different oil saturations with a contact angle of 150°, in accordance with an embodiment;\n \nFIG.', '6\nD\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different oil saturations with a contact angle of 30°, in accordance with an embodiment;\n \nFIG.', '6\nE\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different oil saturations with a contact angle of 90°, in accordance with an embodiment;\n \nFIG.', '6\nF\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different oil saturations with a contact angle of 150°, in accordance with an embodiment;\n \nFIG.', '7\nA\n shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates of clay surface conductance for oil-water-filled porous material containing water-wet sands, clays, and graphite, in accordance with an embodiment;\n \nFIG.', '7\nB\n shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates of graphite contact angle for oil-water-filled porous material containing water-wet sands, clays, and graphite, in accordance with an embodiment;\n \nFIG.', '7\nC\n shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates of water conductivity for oil-water-filled porous material containing water-wet sands, clays, and graphite, in accordance with an embodiment;\n \nFIG.', '8\nA\n shows graphs depicting a histogram of MCMC inversion-derived estimates of clay surface conductance of \nFIG.', '7\nA\n, in accordance with an embodiment;\n \nFIG.', '8\nB\n shows graphs depicting a histogram of MCMC inversion-derived estimates of graphite contact angle of \nFIG.', '7\nB\n, in accordance with an embodiment;\n \nFIG.', '8\nC\n shows graphs depicting a histogram of MCMC inversion-derived estimates of water conductivity of \nFIG.', '7\nC\n, in accordance with an embodiment;\n \nFIG.', '9\nA\n shows multi-frequency electromagnetic (EM) measurements and model predictions based on inversion-derived estimates of effective conductivity associated with \nFIGS.', '7\nA, \n7\nB, and \n7\nC\n and \nFIGS.', '8\nA, \n8\nB, and \n8\nC\n, in accordance with an embodiment;\n \nFIG.', '9\nB\n shows multi-frequency electromagnetic (EM) measurements and model predictions based on inversion-derived estimates of effective permittivity associated with \nFIGS.', '7\nA, \n7\nB, and \n7\nC\n and \nFIGS.', '8\nA, \n8\nB, and \n8\nC\n, in accordance with an embodiment;\n \nFIG.', '10\nA\n shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for clay surface conductance for oil-water-filled porous material containing water-wet sands, clays, and slightly oil-wet graphite, in accordance with an embodiment;\n \nFIG.', '10\nB\n shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for graphite contact angle for oil-water-filled porous material containing water-wet sands, clays, and slightly oil-wet graphite, in accordance with an embodiment;\n \nFIG.', '10\nC\n shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for water conductivity for oil-water-filled porous material containing water-wet sands, clays, and slightly oil-wet graphite, in accordance with an embodiment;\n \nFIG.', '11\nA\n shows graphs depicting a histogram of MCMC inversion-derived estimates of clay surface conductance of \nFIG.', '10\nA\n, in accordance with an embodiment;\n \nFIG.', '11\nB\n shows graphs depicting a histogram of MCMC inversion-derived estimates of graphite contact angle of \nFIG.', '10\nB\n, in accordance with an embodiment;\n \nFIG.', '11\nC\n shows graphs depicting a histogram of MCMC inversion-derived estimates of water conductivity of \nFIG.', '10\nC\n, in accordance with an embodiment;\n \nFIG.', '12\nA\n shows multi-frequency EM measurements and model predictions for effective conductivity based on inversion-derived estimates associated with \nFIGS.', '10\nA, \n10\nB, and \n10\nC\n and \nFIGS.', '11\nA, \n11\nB, and \n11\nC\n, in accordance with an embodiment;\n \nFIG.', '12\nB\n shows multi-frequency EM measurements and model predictions for effective permittivity based on inversion-derived estimates associated with \nFIGS.', '10\nA, \n10\n, and IOC and \nFIGS.', '11\nA, \n11\nB, and \n11\nC\n, in accordance with an embodiment;\n \nFIG.', '13\nA\n shows a graph depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for contact angle for oil/water-filled porous material containing water-wet sand and clays and oil-wet graphite, in accordance with an embodiment;\n \nFIG.', '13\nB\n shows a graph depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for contact angle for oil saturation oil/water-filled porous material containing water-wet sand and clays and oil-wet graphite, in accordance with an embodiment;\n \nFIG.', '14\nA\n shows a graph depicting a histogram of MCMC inversion-derived estimates of clay surface conductance of \nFIG.', '13\nA\n, in accordance with an embodiment;\n \nFIG.', '14\nB\n shows a graph depicting a histogram of MCMC inversion-derived estimates of oil saturation of \nFIG.', '13\nB\n, in accordance with an embodiment;\n \nFIG.', '15\nA\n shows multi-frequency EM measurements and model predictions for effective conductance based on inversion-derived estimates associated with \nFIGS.', '13\nA and \n13\nB\n, and \nFIGS.', '14\nA and \n14\nB\n, in accordance with an embodiment;\n \nFIG.', '15\nB\n shows multi-frequency EM measurements and model predictions for effective permittivity based on inversion-derived estimates associated with \nFIGS.', '13\nA and \n13\nB\n, and \nFIGS.', '14\nA and \n14\nB\n, in accordance with an embodiment;\n \nFIG.', '16\n is an example illustration of a cross section of a volume that includes a solid suspended in an oil-water media, in accordance with an embodiment;\n \nFIG.', '17\nA\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;\n \nFIG.', '17\nB\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;\n \nFIG.', '17\nC\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;\n \nFIG.', '17\nD\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;\n \nFIG.', '18\nA\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 30 degrees, in accordance with an embodiment;\n \nFIG.', '18\nB\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 150 degrees, in accordance with an embodiment;\n \nFIG.', '18\nC\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 30 degrees, in accordance with an embodiment;\n \nFIG.', '18\nD\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 150 degrees, in accordance with an embodiment;\n \nFIG.', '19\nA\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different surface conductance with a contact angle of 30 degrees, in accordance with an embodiment;\n \nFIG.', '19\nB\n shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different surface conductance with a contact angle of 150 degrees, in accordance with an embodiment;\n \nFIG.', '19\nC\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different surface conductance with a contact angle of 30 degrees, in accordance with an embodiment;\n \nFIG.', '19\nD\n shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different surface conductance with a contact angle of 150 degrees, in accordance with an embodiment; and\n \nFIG.', '20\n is a second example of a process for determining properties of a fluid-filled formation, in accordance with an embodiment.', 'DETAILED DESCRIPTION', 'One or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'As used herein, “wettability” refers to a tendency of one fluid to spread on and/or adhere to a solid surface in the presence of other immiscible fluids.', '“Wettability” may be quantified by a contact angle where a liquid interface meets a solid surface.', 'As discussed above, electromagnetic well-logging or induction well-logging may inform certain decisions related to hydrocarbon exploration and production.', 'Certain existing techniques in electromagnetic well logging may use models that assume that conductive particles, like graphite and pyrite, and surface-charge-bearing nonconductive particles, like quartz, calcite and clays, are completely water wet (e.g., the contact angle between a liquid and a solid surface is zero).', 'It is presently noted that wettability of conductive particles and surface-charge-bearing nonconductive particles governs the preferential spreading of fluids on the surface of the particles that influences the interfacial polarization phenomena and charge transport/accumulation around the particles.', 'Consequently, wettability of conductive particles influences the electromagnetic properties of fluid-filled porous materials.', 'Further, the wettability and the electrical properties are closely related such that wettability can be estimated using the electromagnetic properties.', 'For example, the dielectric permittivity of oil-wet sand is smaller than that of the water-wet sand at low water saturation, while the dielectric permittivity of oil-wet sand becomes much larger than that of the water-wet sand at higher water saturation.', 'Additionally, it is noted that both resistivity and magnitude of the phase increase with the increase of oil saturation for sand saturated with non-wetting oil, while they both decrease with the increase of oil saturation for sand partially saturated with wetting oil.', 'Accordingly, one aspect of the present disclosure relates to systems and methods for using a material and subsurface characterization model to quantify the effects of wettability of conductive particles.', 'Moreover, the model may be implemented to determine the wettability effects of solid particles that produce interfacial polarization phenomena on multi-frequency electromagnetic measurements.', 'Further, the material and subsurface characterization model, in accordance with the present disclosure, provides a novel technique for identifying a range of operating frequencies for electromagnetic measurements to characterize the contact angle of solid particles that are present within a subsurface formation.', 'With this in mind, \nFIG.', '1\n illustrates an electromagnetic well-logging system \n10\n that may employ the systems and methods of this disclosure.', 'The electromagnetic well-logging system \n10\n may be used to convey an electromagnetic well-logging tool \n12\n through a geological formation \n14\n via a wellbore \n16\n.', 'The electromagnetic well-logging tool \n12\n may be conveyed on a cable \n18\n via a logging winch system \n20\n.', 'Although the logging winch system \n20\n is schematically shown in \nFIG.', '1\n as a mobile logging winch system carried by a truck, the logging winch system \n20\n may be substantially fixed (e.g., a long-term installation that is substantially permanent or modular).', 'Any suitable cable \n18\n for well logging may be used.', 'The cable \n18\n may be spooled and unspooled on a drum \n22\n and an auxiliary power source \n24\n may provide energy to the logging winch system \n20\n and/or the electromagnetic well-logging tool \n12\n.', 'Moreover, although the electromagnetic well-logging tool \n12\n is described as a wireline downhole tool, it should be appreciated that any suitable conveyance may be used.', 'For example, the electromagnetic well-logging tool \n12\n may instead be conveyed as a logging-while-drilling (LWD) tool as part of a bottom hole assembly (BHA) of a drill string, conveyed on a slickline or via coiled tubing, and so forth.', 'For the purposes of this disclosure, the electromagnetic well-logging tool \n12\n may be any suitable measurement tool that obtains electromagnetic logging measurements through depths of the wellbore \n16\n.', 'Many types of electromagnetic well-logging tools \n12\n may obtain electromagnetic logging measurements in the wellbore \n16\n.', 'These include, for example, the Rt Scanner, AIT, and Thrubit Electromagnetic tools by Schlumberger Technology Corporation, but electromagnetic logging measurements from other downhole tools by other manufacturers may also be used.', 'The electromagnetic well-logging tool \n12\n may provide electromagnetic logging measurements \n26\n to a data processing system \n28\n via any suitable telemetry (e.g., via electrical signals pulsed through the geological formation \n14\n or via mud pulse telemetry).', 'The data processing system \n28\n may process the electromagnetic logging measurements \n26\n to identify a contact angel and/or wettability at various depths of the geological formation \n14\n in the wellbore \n16\n.', 'To this end, the data processing system \n28\n thus may be any electronic data processing system that can be used to carry out the systems and methods of this disclosure.', 'For example, the data processing system \n28\n may include a processor \n30\n, which may execute instructions stored in memory \n32\n and/or storage \n34\n.', 'As such, the memory \n32\n and/or the storage \n34\n of the data processing system \n28\n may be any suitable article of manufacture that can store the instructions.', 'The memory \n32\n and/or the storage \n34\n may be ROM memory, random-access memory (RAM), flash memory, an optical storage medium, or a hard disk drive, to name a few examples.', 'A display \n36\n, which may be any suitable electronic display, may provide a visualization, a well log, or other indication of properties in the geological formation \n14\n or the wellbore \n16\n using the electromagnetic logging measurements \n26\n.\n \nFIG.', '2\n shows an example of an electromagnetic well-logging tool \n12\n that may acquire electromagnetic measurements.', 'The illustrated embodiment of the electromagnetic well-logging tool \n12\n includes a transmitter \n40\n and a receiver \n42\n.', 'While only one transmitter \n40\n and one receiver \n42\n are shown, it should be noted that the number of transmitters and receivers is not a limit on the scope of the present disclosure.', 'Generally speaking, the transmitter \n40\n induces electric eddy currents to produce electromagnetic waves \n44\n having a set of frequencies in a direction of the magnetic dipole moment of the transmitter \n40\n.', 'The electromagnetic waves \n44\n that interact with the geological formation \n14\n are subsequently received by the receiver \n42\n to generate electromagnetic measurements.', 'As shown in \nFIG.', '2\n, the illustrated embodiment of the electromagnetic well-logging tool \n12\n is communicatively coupled to the data processing system \n28\n, which includes a material and subsurface characterization model \n46\n stored in the memory \n32\n.', 'As discussed in further detail below, the material and subsurface characterization model \n46\n may be utilized by the processor \n30\n of the data processing system \n28\n to determine a set of frequencies that the electromagnetic well-logging tool \n12\n may operate to acquire electromagnetic measurements.', 'Further, the electromagnetic measurements may be processed according to the present disclosure to quantify the wettability effects of graphite, clays and other conductive or surface-charge-bearing nonconductive particles for improving subsurface electromagnetic log measurement interpretation in various subsurface geological formations to better quantify the water content/saturation in the subsurface.\n \nFIG.', '3\n illustrates a process \n50\n for determining one or more physical properties of a fluid-filled geological formation.', 'Although described in a particular order, which represents a particular embodiment, it should be noted that the process \n50\n may be performed in any suitable order.', 'Additionally, embodiments of the process \n50\n may omit process blocks and/or include additional process blocks.', 'Moreover, in some embodiments, the process \n50\n may be implemented at least in part by executing instructions stored in a tangible, non-transitory, computer-readable medium, such as memory \n32\n implemented in a data processing system \n28\n, using processing circuitry, such as a processor \n30\n implemented in the data processing system \n28\n.', 'In general, the illustrated process \n50\n includes receiving (process block \n52\n) electromagnetic measurements from a set of frequencies (e.g., emitted by the electromagnetic well-logging tool \n12\n), and determining (process block \n54\n) one or more physical properties of the geological formation.', 'As described herein, in some embodiments, the set of frequencies emitted by the electromagnetic well-logging tool \n12\n may be determined based on the material and subsurface characterization model \n46\n.', 'For example, an operator may determine a number (e.g., 1, 2, 3, 4, 5 etc.) properties of a fluid-filled porous material to be estimated (e.g., determined) and provide these at inputs to a suitable computing system (e.g., the data processing system \n28\n).', 'In some embodiments, the properties to be estimated may include contact angle of conductive particles, contact angle of surface-charge-bearing particles, fluid saturations, fluid conductivity/salinity, surface conductance of solid particles, diffusion coefficients of charge carriers in various components of the material, and volume fractions of fluid and solid components in the materials.', 'Further, the operator may provide an initial assumption of the composition of the geological formation, and the properties of the fluid and solid components in the geological formation.', 'Based on the initial assumption, the operator may apply the material and subsurface characterization model \n46\n to identify the set of frequencies where frequency dispersions in conductivity and/or permittivity will be dominant and measureable (e.g., absent certain effects related to the complex conductivity and/or complex permittivity as described herein).', 'In some embodiments, the set of frequencies may be a range of frequencies or one or more discrete frequencies.', 'The identified frequency range may be provided as an output to the electromagnetic well-logging tool \n12\n.', 'For example, the data processing system \n28\n may provide an output that instructs the electromagnetic well-logging tool \n12\n to tune the electromagnetic (EM) measurement to measure multi-frequency complex conductivity/permittivity of the fluid-filled porous material within the identified frequency ranges, or at specific frequencies in the frequency range.', 'In some embodiments, the number of discrete frequencies included in the identified frequency range or the number of specific frequencies may be at least 3 times the number of physical properties to be estimated as described above.', 'As such, the electromagnetic well-logging tool \n12\n may perform the electromagnetic (EM) measurements of multi-frequency complex conductivity/permittivity on the fluid-filled porous material using the measurement settings tuned and finalized in the steps as described above.', 'In some embodiments, a Markov-Chain Monte-Carlo may be applied to the EM measurements received in process block \n52\n to determine properties such as the contact angles and other physical properties as described herein.', 'The material and subsurface characterization model \n46\n may include multiple relationships, or be generated based on multiple models.', 'For example, the material and subsurface characterization model \n46\n may include a first mechanistic model for a solid particle being preferentially surrounded by one of the fluid phases or fluid components surrounding the solid particle as a function of the contact angle of the solid particle.', 'Further, the material and subsurface characterization model \n46\n may include a second mechanistic model that quantifies the interfacial polarization due to a solid particle (conductive or surface-charge-bearing nonconductive particle) preferentially surrounded by one of the fluid phases/components surrounding the solid particle as function of the contact angle of the solid particle and the operating frequency of the externally applied electromagnetic field.', 'The material and subsurface characterization model \n46\n may be developed by solving the Young-Laplace equation for a spherical grain in a mixture of wetting and non-wetting fluids with a known proportion of the two fluids.', 'For example, Young-Laplace equation may be used to compute the shape of the wetting and non-wetting fluid interface (meniscus) at equilibrium by applying appropriate boundary conditions.', 'In this way, the following expressions may be obtained: the wetting angle of the conductive or surface-charge-bearing nonconductive particle as a function of contact angle of the solid particle and the properties of fluid phases/components surrounding the solid particle.', 'It should be noted that the interfacial polarization due to conductive and surface-charge-bearing nonconductive solid particles depends on the nature of preferential wetting of the solid particle.', 'As such, the subsurface characterization model \n46\n may be used to quantify the effects of contact angle (wettability) of solid grains/particles (conductive or surface-charge-bearing nonconductive particle) on the net charge transport and net charge accumulation as a function of the frequency of the external electromagnetic field at various fluid saturations and solid wettability.', 'The net charge transport determines the conductivity and net charge accumulation determines the permittivity that govern the electromagnetic measurements and log responses of the fluid-filled porous material.', 'At the representative volume level, developing the material and subsurface characterization model \n46\n, in accordance with the techniques of the present disclosure, may include assuming the non-wetting layer (e.g., oil) stays at the top, wetting layer (e.g., water) goes to the bottom, the two layers have (e.g., the non-wetting layer and the wetting layer) one common interface, and the two layers are spread across a length scale that is orders of magnitude larger than the size of the spherical solid particle.', 'The height of these two layers are in proportion to the corresponding fluid saturations.', 'The solid particle suspends at the interface of wetting and non-wetting fluids, as shown in the \nFIG.', '4\n, is discussed below.', 'The wetting phase may surround the solid particle to satisfy the contact angle.', 'The climb or height of the interface between the wetting layer and the non-wetting layer generates a wetting angle, which represents the degree of exposure of the particle to the wetting phase.', 'The interfacial polarization phenomena due to such solid particles are entirely governed by the extent to which the solid particle is surround by the wetting phase versus non-wetting phase, which is governed by the wettability and contact angle of the solid particle.', 'For example, when water wets a conductive mineral, its interfacial polarization effects on the complex conductivity/permittivity measurements will be enhanced.', 'In another example, when the conductive mineral is preferentially oil wet, its interfacial polarization effects on the complex conductivity/permittivity measurements will diminish.\n \nFIG.', '4\n is an example illustration of a cross-section of a volume \n56\n (e.g., within a geological formation) that includes a solid particle \n57\n suspended in an oil-water media, in accordance with an embodiment.', 'In general, the volume \n56\n may be assumed for developing the model, as discussed herein.', 'As shown, the solid particle \n57\n is a circle (e.g., a cross-section of a sphere); however, it should be noted that, in some embodiments, the solid particle may be ellipsoidal (e.g., a diameter \n58\n of the solid particle \n57\n may be greater than or less than a diameter \n59\n of the solid particle \n57\n) or have a radial normal distribution of radii.', 'In the illustrated cross-section of the volume \n56\n shown in \nFIG.', '4\n, C denotes the point where the oil-water interface (e.g., interface between the non-wetting layer and the wetting layer) contacts the particle surface; θ is the contact angle of conductive particle; φ is the wetting angle; ψ is the angle between oil-water interface and the horizon (x-axis) at point C; R is the radius of conductive particle; h\ni \nis the uniform height of oil-water interface in the absence of wetting of the conductive particle (far-field height); h\nc \nis the height where the oil-water interface contacts the particle surface, such that h\nc\n=R(1−cos φ); r is the horizontal distance perpendicular to the vertical axis z; and h(r) is the height of oil-water interface at any distance r away from the vertical axis z.\n \nYoung-Laplace Equation\n \nAs discussed herein, developing the material and subsurface characterization model \n46\n may include solving the Young-Laplace equation to quantify the shape of the oil-water interface.', 'For example, the shape of the oil-water interface, where oil is non-wetting phase and water is the wetting phase, at equilibrium may be described by the Young-Laplace equation: \n (ρ\nw\n−ρ\no\n)\ng\n[\nh\n(\nr\n)−\nh\ni\n]=2\nHσ\n \n where ρ\nw \nand ρ\n0 \nare the density of water and oil, respectively; g denotes gravitational acceleration; H is mean curvature of the meniscus surface; and σ is interfacial tension between oil and water.', 'Under a small slope assumption, where the Bond number,\n \n \n \n \n \n \n \nB\n \n0\n \n \n=\n \n \n \n \n(\n \n \n \nρ\n \nw\n \n \n-\n \n \nρ\n \no\n \n \n \n)\n \n \n\u2062\n \nℊ\n \n\u2062\n \n \n \n \n\u2062\n \n \nR\n \n2\n \n \n \nσ\n \n \n \n,\n \n \n \n \n is small, the gravity force is negligible, so the mean curvature may remain constant everywhere on the oil-water interface.', 'For the material and subsurface characterization model \n46\n, the meniscus surface is axisymmetric.', 'As a result, the Young-Laplace equation can be expressed in cylindrical coordinates as: \n \n \n \n \n \n \n \n \n(\n \n \n \nρ\n \nw\n \n \n-\n \n \nρ\n \no\n \n \n \n)\n \n \n\u2062\n \n \ng\n \n[\n \n \n \nh\n \n\u2061\n \n(\n \nr\n \n)\n \n \n-\n \n \nh\n \ni\n \n \n \n]\n \n \n \nσ\n \n \n=\n \n \n \nh\n \n″\n \n \n+\n \n \n \nh\n \n′\n \n \nr\n \n \n \n \n \n \n \nwhere h′ and h″ represents\n \n \n \n \n \n \n \ndh\n \ndr\n \n \n\u2062\n \n \n \nand\n \n\u2062\n \n \n \n \n \n \n \n\u2062\n \n \n \n \nd\n \n2\n \n \n\u2062\n \nh\n \n \n \ndr\n \n2\n \n \n \n \n,\n \n \n \n \n respectively.', 'By defining some dimensionless variables, such as\n \n \n \n \n \n \n \nr\n \n^\n \n \n=\n \n \nr\n \n \nL\n \nc\n \n \n \n \n,\n \n \n \nh\n \n^\n \n \n=\n \n \nh\n \n \nL\n \nc\n \n \n \n \n,\n \n \n \nG\n \n\u2061\n \n(\n \n \nr\n \n^\n \n \n)\n \n \n=\n \n \n \n \nh\n \n\u2061\n \n(\n \nr\n \n)\n \n \n-\n \n \nh\n \ni\n \n \n \n \nL\n \nc\n \n \n \n \n,\n \n \n \nwhere\n \n\u2062\n \n \n \n \nL\n \nc\n \n \n \n=\n \n \n \nσ\n \n \n \n(\n \n \n \nρ\n \nw\n \n \n-\n \n \nρ\n \no\n \n \n \n)\n \n \n\u2062\n \ng\n \n \n \n \n \n \n \n \n is capillary length, the Young-Laplace equation becomes a modified Bessel differential equation: \n \n \n \n \n \n \n \nG\n \n″\n \n \n+\n \n \n \nG\n \n′\n \n \n \nr\n \nˆ\n \n \n \n-\n \nG\n \n \n=\n \n0\n \n \n \n \n \nwhere G′ and G″ represents and\n \n \n \n \n \n \n \ndG\n \n \nd\n \n\u2062\n \n \nr\n \n^\n \n \n \n \n\u2062\n \n \n \nand\n \n\u2062\n \n \n \n \n \n \n \n\u2062\n \n \n \n \nd\n \n2\n \n \n\u2062\n \nG\n \n \n \nd\n \n\u2062\n \n \n \nr\n \n^\n \n \n2\n \n \n \n \n \n,\n \n \n \n \n respectively.', 'Boundary Conditions (BC)', 'As discussed herein, developing the material and subsurface characterization model \n46\n may include solving the Young-Laplace equation with certain boundary conditions.', 'For example, a first boundary condition may be the height of oil-water interface at infinite distance, h(r)|\nr→∞\n, is equal to h\ni\n.', 'lim\n \n \n \nr\n \nˆ\n \n \n→\n \n∞\n \n \n \nG\n \n \n=\n \n0\n \n \n \n \n (lim)\nT\n(\nr\n{circumflex over (\u2003)}→∞)', 'G=\n0 \n \nA secondary boundary condition may be the height of oil-water interface at distance r=R sin φ is h\nc\n.', 'G\n(\n{circumflex over (r)}=B\no \nsin φ)=\nĥ\nc\n−ĥ\ni \n \n Shape of the Oil-Water Interface \n \nThe Young-Laplace equation is solved using the boundary conditions to obtain the expression for the shape of the oil-water interface:\n \n \n \n \n \n \nh\n \nˆ\n \n \n=\n \n \n \n \nh\n \nˆ\n \n \ni\n \n \n+\n \n \n \n \n \n \nh\n \nˆ\n \n \nc\n \n \n-\n \n \n \nh\n \nˆ\n \n \ni\n \n \n \n \n \nK\n \n0\n \n \n(\n \n \n \n \nB\n \no\n \n \n \n\u2062\n \n \nsin\n \n\u2062\n \nφ\n \n \n \n)\n \n \n \n\u2062\n \n \n \nK\n \n0\n \n \n(\n \n \nr\n \nˆ\n \n \n)\n \n \n \n \n \n \n \n \nwhere K_0 is modified Bessel function of the second kind of order 0.', 'An Expression of Wetting Angle\n \nWetting angle may be expressed as:\n \n \n \n \n \nφ\n \n=\n \n \n180\n \n-\n \nθ\n \n-\n \n \n \n \n \n \nh\n \nˆ\n \n \nc\n \n \n-\n \n \n \nh\n \nˆ\n \n \ni\n \n \n \n \n \nK\n \n0\n \n \n(\n \n \n \n \nB\n \no\n \n \n \n\u2062\n \n \nsin\n \n\u2062\n \nφ\n \n \n \n)\n \n \n \n\u2062\n \n \n \nK\n \n1\n \n \n(\n \n \n \n \nB\n \no\n \n \n \n\u2062\n \n \nsin\n \n\u2062\n \nφ\n \n \n \n)\n \n \n \n \n \n \n \n \nwhere K_1 is modified Bessel function of the second kind of order 1.\n \nEffective Medium Model\n \nIn some embodiments, developing the material and subsurface characterization model \n46\n may include using an effective medium model.', 'For example, to simulate the wettability effects of solid particles constituting a fluid-filled porous material on the electromagnetic properties of the material (e.g., multi-frequency complex conductivity and complex permittivity), the newly developed model of wetting angle of a solid particle may include a petrophysical model to express the complex conductivity/permittivity due to the interfacial polarization of the solid particles at various saturations, wettability, and operating frequencies.', 'From an effective medium standpoint, the effective complex conductivity of a porous fluid-filled geomaterial containing conductive particles of any wettability (e.g., graphite particle) and fully wetted surface-charge-bearing nonconductive particles (e.g., water-wet sand and clay particles) at any saturation of the wetting phase (e.g., water) may be expressed as:\n \n \n \n \n \n \n \n \nK\n \neff\n \n \n-\n \n \nK\n \nw\n \n \n \n \n \nK\n \neff\n \n \n+\n \n \n2\n \n\u2062\n \n \nK\n \nw\n \n \n \n \n \n=\n \n \n \n \nϕ\n \nc\n \n \n\u2062\n \n \np\n \nw\n \n \n\u2062\n \n \n \nf\n \n \nc\n \n,\n \nw\n \n \n \n(\n \nω\n \n)\n \n \n \n+\n \n \n \n \nϕ\n \nc\n \n \n(\n \n \n1\n \n-\n \n \np\n \nw\n \n \n \n)\n \n \n\u2062\n \n \n \nf\n \n \nc\n \n,\n \nnw\n \n \n \n(\n \nω\n \n)\n \n \n \n+\n \n \n \nϕ\n \n \nn\n \n\u2062\n \n1\n \n \n \n\u2062\n \n \n \nf\n \n \nn\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)\n \n \n \n+\n \n \n \nϕ\n \n \nn\n \n\u2062\n \n2\n \n \n \n\u2062\n \n \n \nf\n \n \nn\n \n\u2062\n \n2\n \n \n \n(\n \nω\n \n)\n \n \n \n+\n \n \n \nϕ\n \nnw\n \n \n\u2062\n \n \n \nf\n \nnw\n \n \n(\n \nω\n \n)\n \n \n \n \n \n \n \n \nWhere K\neff \nis the effective complex conductivity of the porous fluid-filled geomaterial; K\nw \nis the complex conductivity of pore-filling wetting phase, which may be brine or saline water in some cases, with an assumption that the complex conductivity of pore-filling non-wetting phase, which is oil in in the illustration of the cross-section of the volume \n56\n, is negligible; f is the dipolarizability due to interfacial polarization of solid particle; ω is the angular frequency of the external EM field; ϕ is the volume fraction of solid particles or the fluid phases; p\nw \nis the proportion of a single solid particle surface that is covered by wetting phase (water) determined using the newly developed model of wetting angle of a solid particle; and subscripts c, n1, n2, nw, and w represent the conductive particle of any wettability (e.g., graphite), water-wet surface-charge-bearing nonconductive particle #1 (e.g., sand), water-wet surface-charge-bearing nonconductive particle #2 (e.g., clay), non-wetting phase (e.g., oil), and wetting phase (e.g., water), respectively.', 'When a solid particle is not fully wet, the interfacial polarization effect of such a solid particle is determined as a volumetric mixing of interfacial polarization when the solid particle is completely surrounded by non-wetting fluid phase, f\nc,n,w\n, and that when completely surround by wetting fluid phase, f\nc,w\n, expressed as pp\nw\nf\nc,w\n(ω)+ϕ\nc\n(1−p\nw\n)f\nc,nw\n(ω), where p\nw \nis the proportion of the solid particle surface that is covered by wetting phase (water) determined using the newly developed model of wetting angle of a solid particle.', 'The proportion of a single graphite surface that covered by water or oil may be expressed as:\n \n \n \n \n \n \np\n \nw\n \n \n=\n \n \n \n1\n \n-\n \ncosφ\n \n \n2\n \n \n \n \n \n where φ is the wetting angle.', 'Dipolarizability of conductive particle (e.g., graphite) completely immersed in wetting phase may be expressed as:\n \n \n \n \n \n \n \n \nf\n \nc\n \n \n(\n \nω\n \n)\n \n \n=\n \n \n \n-\n \n \n1\n \n2\n \n \n \n+\n \n \n \n3\n \n2\n \n \n\u2062\n \n \n \ni\n \n\u2062\n \nω\n \n \n \n[\n \n \n \n \n2\n \na\n \n \n\u2062\n \n \n \nσ\n \nw\n \n \n \nε\n \nw\n \n \n \n\u2062\n \n \n \nE\n \nw\n \n \n \nG\n \nw\n \n \n \n \n-\n \n \n \n2\n \na\n \n \n\u2062\n \n \n \nK\n \nw\n \n \n \nK\n \nc\n \n \n \n\u2062\n \n \n \nσ\n \nc\n \n \n \nε\n \nc\n \n \n \n\u2062\n \n \n \nF\n \nc\n \n \n \nH\n \nc\n \n \n \n \n+\n \n \n \ni\n \n\u2062\n \nω\n \n \n(\n \n \n \n \n2\n \n\u2062\n \n \nK\n \nw\n \n \n \n \nK\n \nc\n \n \n \n+\n \n1\n \n \n)\n \n \n \n]\n \n \n \n \n \n \n\u2062\n \n \n \n \n \nwhere\n \n:', 'E\n \nw\n \n \n \n=\n \n \n \nq\n \n \n \nγ\n \nw\n \n2\n \n \n\u2062\n \n \nε\n \nw\n \n \n \n \n\u2062\n \n \n \ne\n \n \n-\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n \n \n[\n \n \n \n1\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n \n+\n \n \n1\n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n)\n \n \n2\n \n \n \n \n]\n \n \n \n \n\u2062\n \n \n \n \n \nG\n \nw\n \n \n=\n \n \n \nq\n \n \n \nγ\n \nw\n \n \n\u2062\n \n \nε\n \nw\n \n \n \n \n\u2062\n \n \n \ne\n \n \n-\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n \n \n[\n \n \n \n1\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n)\n \n \n2\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n)\n \n \n3\n \n \n \n \n]\n \n \n \n \n\u2062\n \n \n \n \n \nF\n \nc\n \n \n=\n \n \n \nq\n \n \n \nγ\n \nc\n \n \n\u2062\n \n \nε\n \nc\n \n \n \n \n[\n \n \n \n \ncosh\n \n\u2061\n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n \n-\n \n \n \nsinh\n \n\u2061\n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n2\n \n \n \n \n]\n \n \n \n\u2062\n \n \n \n \n \nF\n \nc\n \n \n=\n \n \n \nq\n \n \n \nγ\n \nc\n \n \n\u2062\n \n \nε\n \nc\n \n \n \n \n[\n \n \n \n \n2\n \n\u2062\n \n \ncosh\n \n\u2061\n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n2\n \n \n \n-\n \n \n \nsinh\n \n\u2061\n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n \n-\n \n \n \n2\n \n\u2062\n \n \nsinh\n \n\u2061\n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nc\n \n \n)\n \n \n3\n \n \n \n \n]\n \n \n \n\u2062\n \n \n \n \n \n \nγ\n \nj\n \n \n=\n \n \n \n \n \ni\n \n\u2062\n \nω\n \n \n \nD\n \nj\n \n \n \n+\n \n \n \nσ\n \nj\n \n \n \n \nε\n \nj\n \n \n\u2062\n \n \nD\n \nj\n \n \n \n \n \n \n \n,\n \n \n \nfor\n \n\u2062\n \n \n \nj\n \n \n=\n \n \nw\n \n\u2062\n \n \n \nor\n \n\u2062\n \n \n \nc\n \n \n \n \n \n \n \n \nwhere ω is the angular frequency of the electric field; i is square root of −1; a is characteristic length of inclusion phase; λ is surface conductance of nonconductive particle; σ is electrical conductivity; ε is dielectric permittivity; and D is diffusion coefficient of charge carriers.', 'Dipolarizability of nonconductive particle (e.g., clay, sand, oil) completely immersed in wetting phase may be expressed as:\n \n \n \n \n \n \n \n \nf\n \nncond\n \n \n(\n \nω\n \n)\n \n \n=\n \n \n \n \nQ\n \n\u2061\n \n(\n \n \nR\n \n+\n \nA\n \n \n)\n \n \n-\n \nP\n \n \n \n \nQ\n \n\u2061\n \n(\n \n \nR\n \n-\n \n \n2\n \n\u2062\n \nA\n \n \n \n)\n \n \n+\n \n \n2\n \n\u2062\n \nP\n \n \n \n \n \n\u2062\n \n \n \n \n \nwhere\n \n:', 'A\n \n \n=\n \n \n1\n \n \na\n \n2\n \n \n \n \n\u2062\n \n \n \n \nP\n \n=\n \n \n \nγ\n \nw\n \n2\n \n \n+\n \n \n \nξ\n \nw\n \n2\n \n \n\u2062\n \n \n \nG\n \n*\n \n \n \nH\n \n*\n \n \n \n \n+\n \n \n \n2\n \n\u2062\n \n \nG\n \n*\n \n \n \n \n \na\n \n2\n \n \n\u2062\n \nL\n \n \n \n \n \n\u2062\n \n \n \n \nQ\n \n=\n \n \n \n1\n \n \niF\n \n+\n \n1\n \n \n \n[\n \n \n2\n \n-\n \n \n \n \n \na\n \n2\n \n \n\u2062\n \n \nξ\n \nh\n \n2\n \n \n \n \nH\n \n*\n \n \n \n\u2062\n \n \n(\n \n \n \nL\n \niF\n \n \n+\n \nE\n \n \n)\n \n \n \n-\n \n \n \n2\n \n\u2062\n \nE\n \n \nL\n \n \n \n]\n \n \n \n\u2062\n \n \n \n \nR\n \n=\n \n \n \nP\n \nQ\n \n \n\u2062\n \n \n(\n \n \n \niFE\n \n+\n \nL\n \n \n \niF\n \n+\n \n1\n \n \n \n)\n \n \n \n \n\u2062\n \n \n \n \n \n \nH\n \n*\n \n \n=\n \n \n \naL\n \nw\n \n \n \nF\n \nw\n \n \n \n \n,\n \n \n \nG\n \n*\n \n \n=\n \n \n \naG\n \nw\n \n \n \nE\n \nw\n \n \n \n \n,\n \n \nL\n \n=\n \n \n \n2\n \n\u2062\n \nλ\n \n \n \n \na\n \n\u2062\n \nσ\n \n \nw\n \n \n \n \n,\n \n \nE\n \n=\n \n \n \nε\n \nn\n \n \n \nε\n \nw\n \n \n \n \n,\n \n \nF\n \n=\n \n \n \nωε\n \nw\n \n \n \nσ\n \nw\n \n \n \n \n \n\u2062\n \n \n \n \n \nF\n \nw\n \n \n=\n \n \n \nq\n \n \n \nξ\n \nw\n \n2\n \n \n\u2062\n \n \nε\n \nw\n \n \n \n \n\u2062\n \n \n \ne\n \n \n-\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n \n \n[\n \n \n \n1\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n \n+\n \n \n1\n \n \n \n(\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n)\n \n \n2\n \n \n \n \n]\n \n \n \n \n\u2062\n \n \n \n \n \nL\n \nw\n \n \n=\n \n \n \nq\n \n \n \nξ\n \nw\n \n \n\u2062\n \n \nε\n \nw\n \n \n \n \n\u2062\n \n \n \ne\n \n \n-\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n \n \n[\n \n \n \n1\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n)\n \n \n2\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n)\n \n \n3\n \n \n \n \n]\n \n \n \n \n\u2062\n \n \n \n \n \n \nξ\n \nj\n \n \n=\n \n \n \n \ni\n \n\u2062\n \nω\n \n \n \nD\n \nj\n \n \n \n \n \n,\n \n \n \nfor\n \n\u2062\n \n \n \nj\n \n \n=\n \n \nn\n \n\u2062\n \n \n \n \n \n \n \n\u2062\n \nor\n \n\u2062\n \n \n \nw\n \n \n \n \n \n \n \n \nBased on certain assumptions of the properties of solid particles and fluid phases in the fluid-filled porous material and the list of unknown properties to be estimated, the new mechanistic model is used to identify the frequency range where frequency dispersions in conductivity and/or permittivity will be dominant and measurable for purposes of desired estimations.', 'Electromagnetic (EM) measurements in all the following cases (presented in \nFIGS.', '6\n to \n8\n) were tuned to be within the frequency range identified using the mechanistic model, such that the number of discrete frequencies as which the measurements were acquired is at least 3 times the number of physical properties to be estimated.', 'The following case demonstrates the use of mechanistic model to plan the electromagnetic (EM) data acquisition procedure.', 'TABLE 1\n \n \n \n \n \n \n \n \nExample properties of wetting phase\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nD\nw \n(m\n2\n/s)\n \nε\nr, w\n \nσ\nw \n(S/m)\n \nρ\nw \n(kg/m\n3\n)', 'σ (N/m)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nWater\n \n10\n−9\n \n70\n \n0.1\n \n1000\n \n0.05\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nTABLE 2\n \n \n \n \n \n \n \n \nExample properties of solid particles, i is c for conductive\n \n \n \nparticle (e.g., graphite), i is n for surface-charge-\n \n \n \nbearing nonconductive particle (e.g., clay and sand),\n \n \n \nand i is nw for non-wetting phase (e.g., oil).', 'σ\ni\n \n \n \n \n \n \nϕ\ni \n(%)', 'α\ni \n(μm)\n \nD\ni \n(m\n2\n/s)\n \nε\nr, i\n \n(S/m)', 'λ (S)\n \nθ (°)', 'Graphite\n \n10\n \n200\n \n5 × 10\n−5\n \n12\n \n500\n \n—\n \n0~180\n \n \n \nSand\n \n70\n \n1000\n \n—\n \n4\n \n—\n \n10\n−9\n \n—\n \n \n \nClay\n \n10\n \n100\n \n—\n \n8\n \n—\n \n10\n−8\n \n—\n \n \n \nOil\n \n1~9\n \n100\n \n—\n \n2\n \n—\n \n\u2002\n10\n−30\n \n—\n \n \n \n \n \n \n \n \n \n \nFIGS.', '5\nA and \n5\nB\n show graphs of effective conductivity and \nFIGS.', '5\nC and \n5\nD\n show graphs of effective permittivity for mixtures including a conductive solid particle.', 'More specifically, the curves in the graph \n62\n and graph \n64\n show effective conductivity, and the curves in the graph \n66\n and graph \n68\n show effective permittivity.', 'When comparing the different curves in graph \n62\n and graph \n66\n, or graph \n64\n and graph \n68\n, the frequency dispersion reduces as contact angle increases, which means the conductive particle becomes oil wet.', 'This is because, as contact angle increases, the graphite surface is covered more by oil, which has much fewer charge carriers than water and impedes the interfacial polarization in the fluid phase which lowers charge accumulation.', 'As oil saturation increases, both σ_eff and ε_(r,eff) will reduce due to the increase in the volume fraction of oil as nonconductive inclusion.', 'Both σ_eff and ε_(r,eff) will converge to a single value at high frequency because the charge carriers rapidly respond to the alternating external EM field and there is no net accumulation around particles, resulting in an apparent increase in conductivity.', 'Consequently, conductivity reaches to a high value and permittivity reaches to a low value (representing only dipole moment of water) at high frequency close to 1 GHz.', "In the contrast, at low frequency, the charge carriers quickly reach the equilibrium distribution around the conductive particles' interface, so that the polarized particles act as insulators, which lead to lower σ_eff and higher ε_(r,eff).", 'σ_eff at low frequency can be modeled using effective medium model assuming the conductive particles to be insulators.\n \nFIGS.', '6\nA, \n6\nB, and \n6\nC\n (i.e., \nFIGS.', '6\nA-C\n) show graphs of effective conductivity and \nFIGS.', '6\nD, \n6\nE, and \n6\nF\n (i.e., \nFIGS.', '6\nD-F\n) effective permittivity for mixtures including a conductive solid particle.', 'More specifically, the curves in the graph \n70\n, graph \n72\n, and graph \n74\n show effective conductivity, and the curves in the graph \n76\n, graph \n78\n, and graph \n80\n show effective permittivity.', 'When comparing the different curves in graph \n70\n and graph \n76\n, graph \n72\n and graph \n78\n, and graph \n74\n and graph \n80\n, the frequency dispersion reduces as oil saturation increases because graphite surface is covered more by oil, similar to the effect of contact angle.', 'It should be noted that as oil saturation increases, both σ_eff and ε_(r,eff) will reduce due to the increase in the volume fraction of oil because the oil behaves as nonconductive inclusion.', 'Also, by comparing the rate of change among curves in graph \n62\n and graph \n66\n (e.g., as shown in \nFIGS.', '5\nA and \n5\nC\n) and graph \n70\n and graph \n76\n (e.g., as shown in \nFIGS.', '6\nA and \n6\nD\n), it is evident that the effect of change in oil saturation from 10% to 70% on the frequency dispersion of conductivity and permittivity is much lower than the effect of change in contact angle from 0° to 180°.', 'This indicates that the contact angle plays a primary effect and oil saturation plays a secondary effect in controlling the multi-frequency behavior.', 'The following three cases demonstrate the efficacy of the electromagnetic (EM) data acquisition procedure followed by data processing workflow.', 'Based on some assumption of the properties of solid particles and fluid phases in the fluid-filled porous material and the list of unknown properties to be estimated, the new mechanistic model is used to identify the frequency range where frequency dispersions in conductivity and/or permittivity will be dominant and measurable for purposes of desired estimations.', 'Electromagnetic (EM) measurements in all the following cases (presented in \nFIGS.', '5\nA, \n5\nB, \n5\nC, and \n5\nD\n, \nFIGS.', '6\nA-C\n, \nFIGS.', '6\nD-F\n, and \nFIGS.', '7\nA, \n7\nB, and \n7\nC\n) were tuned to be within the frequency range identified using the mechanistic model, such that the number of discrete frequencies at which the measurements were acquired is at least 3 times the number of physical properties to be estimated.', 'Using the MCMC inversion coupled with the mechanistic model, several properties of the fluid-filled porous materials were estimated, the primary being the simultaneous estimations of oil saturation (or water saturation) and contact angle (or wettability).', 'FIGS.', '7\nA, \n7\nB, and \n7\nC\n (i.e., \nFIGS.', '7\nA-C\n) show a graph \n90\n, a graph \n92\n, and a graph \n94\n, which each depict a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates.', 'More specifically, the graph \n90\n, the graph \n92\n, and the graph \n94\n illustrate the MCMC inversion of multi-frequency EM measurements of conductivity and permittivity (shown in \nFIGS.', '9\nA and \n9\nB\n) to estimate clay surface conductance λ\nc \n(e.g., shown in graph \n90\n), graphite contact angle θ (e.g., shown in graph \n92\n), and water conductivity σ\nw \n(e.g., shown in graph \n90\n) for oil/water-filled porous material containing water-wet sand, clays, and graphite.', 'FIGS.', '8\nA, \n8\nB, and \n8\nC\n (i.e., \nFIGS.', '8\nA-C\n) show a graph \n96\n, a graph \n98\n, and a graph \n100\n, which each depict a histogram of MCMC inversion-derived estimates of clay surface conductance, graphite contact angle, and water conductivity.', 'The graph \n96\n, the graph \n98\n, and the graph \n100\n represent histograms of MCMC inversion-derived estimates of clay surface conductance λ\nc \n(e.g., shown in graph \n96\n), graphite contact angle θ (e.g., shown in graph \n98\n), and water conductivity σ\nw \n(e.g., shown in graph \n100\n).', 'A line \n102\n represents the original values of the properties and the region between lines \n104\n and \n106\n represent 90% highest posterior density (HPD) interval of the inversion-derived estimates.', 'FIGS.', '9\nA and \n9\nB\n show a graph \n108\n of multi-frequency EM measurements and a graph \n110\n of model predictions based on inversion-derived estimates.', 'More specifically, the graph \n108\n and the graph \n110\n illustrates a comparison of the multi-frequency EM measurements against the mechanistic model predictions for effective permittivity based on the inversion-derived estimates for effective conductance and effective permittivity.', 'FIGS.', '10\nA, \n10\nB, and \n10\nC\n show a graph \n112\n, a graph \n114\n, and a graph \n116\n, which each depict a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates.', 'More specifically, the graph \n112\n, the graph \n114\n, and the graph \n116\n illustrate the MCMC inversion of multi-frequency EM measurements of conductivity and permittivity (shown in \nFIGS.', '12\nA and \n12\nB\n) to estimate clay surface conductance λ\nc \n(e.g., shown in graph \n112\n), graphite contact angle θ (e.g., shown in graph \n114\n), and water conductivity σ\nw \n(e.g., shown in graph \n116\n) for oil/water-filled porous material containing water-wet sand and clays and slightly oil-wet graphite.', 'FIGS.', '11\nA, \n11\nB, and \n11\nC\n show a graph \n118\n, a graph \n120\n, and a graph \n122\n, which each depict a histogram of MCMC inversion-derived estimates of clay surface conductance, graphite contact angle, and water conductivity.', 'More specifically, the graph \n118\n, the graph \n120\n, and the graph \n120\n illustrate a histogram of MCMC inversion-derived estimates of clay surface conductance λ\nc \n(e.g., shown in graph \n118\n), graphite contact angle θ (e.g., shown in graph \n120\n), and water conductivity σ\nw \n(e.g., shown in graph \n122\n).', 'The line \n102\n represents the original values of the properties and the region between lines \n104\n and \n106\n represent 90% HPD interval of the inversion-derived estimates.', 'FIGS.', '12\nA and \n12\nB\n show a graph \n124\n of multi-frequency MS measurements and a graph \n126\n of model predictions based on inversion-derived estimates.', 'More specifically, the graph \n124\n and graph \n126\n illustrate a comparison of the multi-frequency EM measurements against the mechanistic model predictions based on the inversion-derived estimates of effective conductance and effective permittivity.\n \nFIGS.', '13\nA and \n13\nB\n show a graph \n128\n and a graph \n130\n that each history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates.', 'More specifically, the graph \n128\n and the graph \n130\n illustrate the MCMC inversion of multi-frequency EM measurements of conductivity and permittivity (shown in \nFIGS.', '15\nA and \n15\nB\n) to estimate graphite contact angle θ and oil saturation S\no \nfor oil/water-filled porous material containing water-wet sand and clays and oil-wet graphite.', 'FIGS.', '14\nA and \n14\nB\n show a graph \n132\n and a graph \n134\n that each depict a third histogram of MCMC inversion-derived estimates of clay surface conductance, graphite contact angle, and water conductivity.', 'More specifically, the graph \n132\n and the graph \n134\n illustrate the histogram of MCMC inversion-derived estimates of graphite contact angle θ and oil saturation S\no\n.', 'The line \n102\n represents the original values of the properties and the region between lines \n104\n and \n106\n represent 90% HPD interval of the inversion-derived estimates.', 'FIGS.', '15\nA and \n15\nB\n show a graph \n136\n of multi-frequency MS measurements and a graph \n138\n model predictions based on inversion-derived estimates.', 'More specifically, the graph \n136\n and the graph \n138\n illustrate a comparison of the multi-frequency EM measurements against the mechanistic model predictions based on the inversion-derived estimates of effective conductance and effective permittivity.', 'Accordingly, the present disclosure is directed to techniques for quantitatively determining effects of wettability (e.g., contact angle) of conductive particles on the multi-frequency complex conductivity of fluid-filled porous materials, such as a geological formation.', 'In some embodiments, the techniques include developing a material and subsurface characterization model \n46\n.', 'The material and subsurface characterization model \n46\n may be developed by solving the Young-Laplace equation as discussed herein.', 'Additionally, the material and subsurface characterization model \n46\n may be developed by applying, invoking, or utilizing the Poisson-Nernst-Planck (PNP) equation to quantify dipolarizability of a partially wetted graphite particle.', 'Further, developing the model may include using an effective medium model to combine the interfacial polarization effects of nonconductive particles (e.g., sand and clay) and conductive particles (e.g., graphite and pyrite) to compute the complex conductivity of fluid-filled porous material containing strongly water-wet nonconductive particles and conductive particles of any wettability.', 'NOMENCLATURE\n \nPPIP model=perfectly polarized interfacial polarization model\n \nSCAIP model=surface-conductance-assisted interfacial polarization model\n \na=characteristic length of inclusion phase (m)\n \nA\no\n=surface area of graphite particle covered by oil (m\n2\n)\n \nA\ns\n=surface area of graphite particle (m\n2\n)\n \nA\nw\n=surface area of graphite particle covered by water (m\n2\n)\n \nB\no\n=Bond number\n \nD\nj\n=diffusion coefficient of charge carriers of medium j (m\n2\n/s)', "e=Euler's number\n \nE\n0\n=amplitude of the electric field (V)\n \nE\n0\n=vacuum permittivity (8.854×10\n−12 \nF/m)\n \nε\neff\n=effective dielectric permittivity of the mixture (F/m)\n \nε\nj\n=dielectric permittivity of medium j (F/m)\n \nε\nr,j\n=relative permittivity of medium j\n \nf=frequency (Hz)\n \nf\nj \n(ω)=dipolarizability (dipolar field coefficient) of medium j\n \nf(φ)=a function of wetting angle φ\n \ng=gravitational acceleration (N/kg)\n \nG=dimensionless form of h−h\ni \n \nh(r)=height of oil-water interface at any distance r away from the vertical axis z (m)\n \nĥ=dimensionless form of h\n \nh\nc\n=height where the oil-water interface contacts the particle surface (m)\n \nh\ni\n=height of oil-water interface in the absence of wetting of graphite (far-field height) (m)\n \nH=mean curvature of the meniscus surface (m\n−1\n)", 'i=square root of −1\n \nI\n0\n=modified Bessel function of the first kind of order 0\n \nK\n0\n=modified Bessel function of the second kind of order 0\n \nK\n1\n=modified Bessel function of the second kind of order 1\n \nL\nc\n=capillary length (m)\n \nλ=surface conductance (S)\n \nω=angular frequency of the electric field (rad/s)\n \nΔp=Laplace pressure (Pa)\n \np\no\n=proportion of graphite surface that covered by oil (%)\n \np\nw\n=proportion of graphite surface that covered by water (%)\n \nφ=wetting angle (°)\n \nϕ=porosity of the porous media (%)\n \nϕ\nj\n=volume fraction of medium j in the mixture (%)\n \nϕ\no\n=volume fraction of oil in the mixture (%)\n \nψ=angle between oil-water interface and the horizon (x-axis) at contact point (°)\n \nq=elementary charge (1.6×10\n−19 \nC)\n \nr=distance from vertical axis z (m)\n \n{circumflex over (r)}=dimensionless form of r\n \nR=radius of graphite particle (m)\n \nρ\no\n=density of oil (kg/m\n3\n)\n \nρ\nw\n=density of water (kg/m\n3\n)\n \nS\no\n=oil saturation (%)\n \nσ=interfacial tension between oil and water (N/m)\n \nσ\neff\n=effective electrical conductivity of the mixture (S/m)\n \nσ\neff\n*=effective complex electrical conductivity of the mixture (S/m)\n \nσ\nj\n=electrical conductivity of medium j (S/m)\n \nσ\nj\n*=complex electrical conductivity of medium j (S/m)\n \nθ=contact angle (°)\n \nAnother aspect of the present disclosure relates to systems and methods for using a material and subsurface characterization model to quantify the effects of wettability of nonconductive particles.', 'Moreover, the model may be implemented to determine the wettability effects of the solid particles that produce interfacial polarization phenomena on multi-frequency electromagnetic measurements.', 'Further, the material and subsurface characterization model, in accordance with the present disclosure, provides a novel technique for identifying a range of operating frequencies for electromagnetic measurements to characterize the contact angle of solid particles that are present within a subsurface formation.', 'With the foregoing in mind, \nFIG.', '16\n is an example illustration of a cross-section of a volume \n140\n (e.g., within a geological formation) that includes a solid particle \n142\n suspended in an oil-water media, in accordance with an embodiment.', 'In general, the volume \n140\n may be assumed for developing the model, as discussed herein.', 'As shown, the solid particle \n142\n is a circle (e.g., a cross-section of a sphere); however, it should be noted that, in some embodiments, the solid particle may be ellipsoidal (e.g., a first diameter \n144\n of the solid particle \n142\n may be greater than or less than a diameter \n146\n of the solid particle \n142\n) or have a radial normal distribution of radii.', 'In the illustrated cross-section of the volume \n140\n shown in \nFIG.', '16\n, C denotes the point where the oil-water interface (e.g., interface between the non-wetting layer and the wetting layer) contacts the particle surface; θ is the contact angle of conductive particle; φ is the wetting angle; ψ is the angle between oil-water interface and the horizon (x-axis) at point C; R is the radius of conductive particle; h\ni \nis the uniform height of oil-water interface in the absence of wetting of the conductive particle (far-field height); h\nc \nis the height where the oil-water interface contacts the particle surface, such that h\nc\n=R(1−cos φ); r is the horizontal distance perpendicular to the vertical axis z; and h(r) is the height of oil-water interface at any distance r away from the vertical axis z.', 'The preferential spread/wetting of the wetting/non-wetting interface generates a wetting angle, which represents the surface area of the solid particle in contact with each of the two fluid phases.', 'The interfacial polarization the phenomena due to such solid particle in contact with two distinct fluid types are entirely governed by the extent to which solid particle is surround by the wetting phase versus non-wetting phase, which is governed by the wettability and contact angle of the solid particle.', 'For example, when water wets a clay particle, the interfacial polarization effects on the complex conductivity/permittivity measurements will be enhanced.', 'In another example, when the clay particle is preferentially oil wet, its interracial polarization effects on the complex conductivity/permittivity measurements will diminish.', 'From an effective medium standpoint, the effective complex conductivity of a porous fluid-filled geomaterial containing surface-charge-bearing nonconductive particles (e.g., water-wet sand and mixed-wet clay particles) at any saturation of the wetting phase (e.g., water) may be expressed as:\n \n \n \n \n \n \n \n \nK\n \neff\n \n \n-\n \n \nK\n \nw\n \n \n \n \n \nK\n \neff\n \n \n+\n \n \n2\n \n\u2062\n \n \nK\n \nw\n \n \n \n \n \n=\n \n \n \n∑\n \n \n \nϕ\n \n \nn\n \n\u2062\n \n1\n \n \n \n\u2062\n \n \n \nf\n \n \nn\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)', '+\n \n \n∑\n \n \n \nϕ\n \n \nn\n \n\u2062\n \n2\n \n \n \n\u2062\n \n \n \nf\n \n \n \nn\n \n\u2062\n \n2\n \n \n,\n \nw\n \n \n \n(\n \nω\n \n)\n \n \n\u2062\n \n \np\n \nw\n \n \n \n \n+\n \n \n∑\n \n \n \nϕ\n \n \nn\n \n\u2062\n \n2\n \n \n \n\u2062\n \n \n \nf\n \n \n \nn\n \n\u2062\n \n2\n \n \n,\n \nnw\n \n \n \n(\n \nω\n \n)\n \n \n\u2062\n \n \n(\n \n \n1\n \n-\n \n \np\n \nw\n \n \n \n)\n \n \n \n \n+\n \n \n \nϕ\n \nnw\n \n \n\u2062\n \n \n \nf\n \nnw\n \n \n(\n \nω\n \n)\n \n \n \n \n \n \n \n \nK\neff \nis the effective complex conductivity of the porous fluid-filled geomaterial; K\nw \nis the complex conductivity of pore-filling wetting phase, which is brine or saline water in our case, with an assumption that the complex conductivity of pore-filling non-wetting phase, which is oil in our case, is negligible; f is the dipolarizability due to interfacial polarization of solid particle; ωω is the angular frequency of the external EM field; ϕ is the volume fraction of solid particles or the fluid phases; p\nw \nis the proportion of a single solid particle surface that is covered by wetting phase (water) determined using the newly developed model of wetting angle of a solid particle; and Subscripts n1, n2, nw, and w represent water-wet surface-charge-bearing nonconductive particle #1 (e.g. sand), surface-charge-bearing nonconductive particle #2 of any wettability (e.g. clay), non-wetting phase (e.g. oil), and wetting phase (e.g. water), respectively.', 'When a surface-charge-bearing nonconductive solid particle is not fully wet, the interfacial polarization effect of the surface-charge-bearing nonconductive solid particle may be determined as a volumetric mixing of interfacial polarization when the solid particle is completely surrounded by non-wetting fluid phase, f\nc,nw, \nand that when completely surround by wetting fluid phase, f\nc,w\n, expressed as ϕ\nn2\nf\nn2,w\n(ω)p\nw\n+ϕ\nn2\nf\nn2,nw\n(ω)(1−p\nw\n), where p\nw \nis the proportion of the solid particle surface that is covered by wetting phase (water) determined using the newly developed model of wetting angle of a solid particle.', 'For example, the portion of a single clay surface that is covered by a wetting phase may be expressed as:\n \n \n \n \n \n \np\n \nw\n \n \n=\n \n \n \n1\n \n-\n \n \n \ncos\n \n\u2062\n \nφ\n \n \n \n \n2\n \n \n \n \n \n where φ is the wetting angle.', 'Dipolarizability of Nonconductive Particle (eg., Clay, Sand, Oil) Completely Immersed in Wetting Phase \n \n \n \n \n \n \n \n \nf\n \n \nnon\n \n-\n \nconductive\n \n \n \n(\n \nω\n \n)\n \n \n=\n \n \n \n \nQ\n \n\u2061\n \n(\n \n \nR\n \n+\n \nA\n \n \n)\n \n \n-\n \nP\n \n \n \n \nQ\n \n\u2061\n \n(\n \n \nR\n \n-\n \n \n2\n \n\u2062\n \nA\n \n \n \n)\n \n \n+\n \n \n2\n \n\u2062\n \nP\n \n \n \n \n \n\u2062\n \n \n \n \n \nwhere\n \n:', 'A\n \n \n=\n \n \n1\n \n \na\n \n2\n \n \n \n \n\u2062\n \n \n \n \nP\n \n=\n \n \n \nγ\n \nw\n \n2\n \n \n+\n \n \n \nξ\n \nw\n \n2\n \n \n\u2062\n \n \n \nG\n \n*\n \n \n \nH\n \n*\n \n \n \n \n+\n \n \n \n2\n \n\u2062\n \n \nG\n \n*\n \n \n \n \n \na\n \n2\n \n \n\u2062\n \nL\n \n \n \n \n \n\u2062\n \n \n \n \nQ\n \n=\n \n \n \n1\n \n \niF\n \n+\n \n1\n \n \n \n[\n \n \n2\n \n-\n \n \n \n \n \na\n \n2\n \n \n\u2062\n \n \nξ\n \nh\n \n2\n \n \n \n \nH\n \n*\n \n \n \n\u2062\n \n \n(\n \n \n \nL\n \niF\n \n \n+\n \nE\n \n \n)\n \n \n \n-\n \n \n \n2\n \n\u2062\n \nE\n \n \nL\n \n \n \n]\n \n \n \n\u2062\n \n \n \n \nR\n \n=\n \n \n \nP\n \nQ\n \n \n\u2062\n \n \n(\n \n \n \niFE\n \n+\n \nL\n \n \n \niF\n \n+\n \n1\n \n \n \n)\n \n \n \n \n\u2062\n \n \n \n \n \n \nH\n \n*\n \n \n=\n \n \n \naL\n \nw\n \n \n \nF\n \nw\n \n \n \n \n,\n \n \n \nG\n \n*\n \n \n=\n \n \n \naG\n \nw\n \n \n \nE\n \nw\n \n \n \n \n,\n \n \nL\n \n=\n \n \n \n2\n \n\u2062\n \nλ\n \n \n \n \na\n \n\u2062\n \nσ\n \n \nw\n \n \n \n \n,\n \n \nE\n \n=\n \n \n \nϵ\n \nn\n \n \n \nε\n \nw\n \n \n \n \n,\n \n \nF\n \n=\n \n \n \nσϵ\n \nw\n \n \n \nσ\n \nw\n \n \n \n \n \n\u2062\n \n \n \n \n \nF\n \nw\n \n \n=\n \n \n \nq\n \n \n \nγ\n \nw\n \n2\n \n \n\u2062\n \n \nϵ\n \nw\n \n \n \n \n\u2062\n \n \n \ne\n \n \n-\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n \n \n[\n \n \n \n1\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n \n+\n \n \n1\n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n)\n \n \n2\n \n \n \n \n]\n \n \n \n \n\u2062\n \n \n \n \n \ng\n \nw\n \n \n=\n \n \n \nq\n \n \n \nγ\n \nw\n \n \n\u2062\n \n \nϵ\n \nw\n \n \n \n \n\u2062\n \n \n \ne\n \n \n-\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n \n \n[\n \n \n \n1\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n)\n \n \n2\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nγ\n \n \nw\n \n \n)\n \n \n3\n \n \n \n \n]\n \n \n \n \n\u2062\n \n \n \n \n \nL\n \nw\n \n \n=\n \n \n \nq\n \n \n \nξ\n \nw\n \n \n\u2062\n \n \nϵ\n \nw\n \n \n \n \n\u2062\n \n \n \ne\n \n \n-\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n \n \n[\n \n \n \n1\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n)\n \n \n2\n \n \n \n+\n \n \n2\n \n \n \n(\n \n \n \na\n \n\u2062\n \nξ\n \n \nw\n \n \n)\n \n \n3\n \n \n \n \n]\n \n \n \n \n\u2062\n \n \n \n \n \nγ\n \nw\n \n \n=\n \n \n \n \n \ni\n \n\u2062\n \nω\n \n \n \nD\n \nw\n \n \n \n+\n \n \n \nσ\n \nw\n \n \n \n \nϵ\n \nw\n \n \n\u2062\n \n \nD\n \nw\n \n \n \n \n \n \n \n\u2062\n \n \n \n \n \nξ\n \nw\n \n \n=\n \n \n \n \ni\n \n\u2062\n \nω\n \n \n \nD\n \nw\n \n \n \n \n \n \n \n \n where a is characteristic length of inclusion phase; ω is the angular frequency of the electric field; i is square root of −1; λ is surface conductance of nonconductive particle; σ is electrical conductivity; ε is dielectric permittivity; and D is diffusion coefficient of charge carriers.', 'If the nonconductive particle is immersed in non-wetting phase, the surface conductance may be set to be a very small number.', 'It should be noted that the equations for the disclosed model above represent one example embodiment.', 'That is, there can be other alternative forms for the dipolarizability of nonconductive particle (e.g. clay, sand, oil) completely immersed in wetting phase.', 'Inversion Algorithm\n \nWe applied the Markov Chain Monte Carlo (MCMC) inversion algorithm for the purposes of estimating water saturation, wettability of solid particles, conductivity of water/brine filling the porous material, and clay surface conductance.', 'Implementation of the inversion scheme coupled with the new mechanistic model of wettability effects improves the interpretation and processing of subsurface electromagnetic log.', 'Mechanistic Model Predictions of Multi-Frequency Complex Conductivity\n \nBased on some assumption of the properties of solid particles and fluid phases in the fluid-filled porous material and the list of unknown properties to be estimated', ', the disclosed mechanistic model may be used to identify the frequency range where frequency dispersions in conductivity and/or permittivity will be dominant and measurable for purposes of desired estimations.', 'Electromagnetic (EM) measurements in all the following cases (presented in \nFIGS.', '17\nA-D\n, and \nFIGS.', '18\nA-D\n) were tuned to be within the frequency range identified using the mechanistic model, such that the number of discrete frequencies as which the measurements were acquired is at least 3 times the number of physical properties to be estimated.', 'FIGS.', '17\nA, \n17\nB, \n17\nC, and \n17\nD\n (i.e., \nFIGS.', '17\nA-\n17\nD\n) show graphs indicating the effect of contact angle on the properties of a nonconductive solid particle.', 'More specifically, the curves \n148\n, \n150\n, and \n152\n of \nFIG.', '17\nA\n show the effective conductivity at a contact angle of 30 degrees, 90 degrees, and 150 degrees for a mixture containing water-wet sand and clay particles with a surface conductance of 10\n−6 \nS, partially saturated with brine/water and an oil saturation of 10%.', 'The curves \n154\n, \n156\n, and \n158\n of \nFIG.', '17\nB\n show the effective conductivity at a contact angle of 30 degrees, 90 degrees, and 150 degrees for a mixture containing water-wet sand and clay particles with a surface conductance of 10\n−6 \nS, partially saturated with brine/water and an oil saturation of 90%.', 'The curves \n160\n, \n162\n, and \n164\n of \nFIG.', '17\nC\n show the effective permittivity at a contact angle of 30 degrees, 90 degrees, and 150 degrees for a mixture containing water-wet sand and clay particles with a surface conductance of 10\n−6 \nS, partially saturated with brine/water and an oil saturation of 10%.', 'The curves \n166\n, \n168\n, and \n170\n of \nFIG.', '17\nD\n show the effective permittivity at a contact angle of 30 degrees, 90 degrees, and 150 degrees for a mixture containing water-wet sand and clay particles with a surface conductance of 10\n−6 \nS, partially saturated with brine/water and an oil saturation of 90%.', 'In this example, the frequency dispersion of effective conductivity is relatively negligible for frequencies lower than 10 MHz, and the frequency dispersion for effective permittivity is relatively negligible for frequencies lower than 10 KHz.', 'As contact angle increases, i.e. the surface-charge bearing nonconductive particle becomes oil wet, the frequency dispersion of permittivity reduces.', 'This is because the clay surface is covered more by oil, which has much less charge carriers than water and impedes the interfacial polarization in the fluid phase.', 'The conductivity increases as contact angle decreases, because clay surface conductance will assist charge transport.', "At low frequency, the charge carriers quickly reach the equilibrium distribution around the surface-charge-bearing nonconductive particles' interface, so that the particles act as insulators, which lead to lower σ\neff \nand higher ε\nr,eff\n.", 'This model prediction shows that the EM measurements and log responses may be acquired at low frequencies and high frequencies to capture the frequency dispersions in both permittivity and conductivity, respectively.', 'Moreover, the effect of wettability on conductivity is higher at higher oil saturation.', 'FIGS.', '18\nA, \n18\nB, \n18\nC, and \n18\nD\n (i.e., \nFIGS.', '18\nA-\n18\nD\n) show graphs indicating the effect of oil saturation on the properties of a nonconductive solid particle.', 'More specifically, the curves \n172\n, \n174\n, and \n176\n of \nFIG.', '18\nA\n show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, 50%, and 90% for a with a surface conductance of 10\n−6 \nS with a contact angle of 30 degrees.', 'The curves \n178\n, \n180\n, and \n182\n of \nFIG.', '18\nB\n show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, 50%, and 90% for a with a surface conductance of 10\n−6 \nS with a contact angle of 150 degrees.', 'The curves \n184\n, \n186\n, and \n188\n of \nFIG.', '18\nC\n show the effective permittivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, 50%, and 90% for a with a surface conductance of 10\n−6 \nS with a contact angle of 30 degrees.', 'The curves \n190\n, \n192\n, and \n194\n of \nFIG.', '18\nD\n show the effective permittivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, 50%, and 90% for a with a surface conductance of 10\n−6 \nS with a contact angle of 150 degrees.', 'In this example, when comparing the different curves in \nFIGS.', '19\nA\n and C or \nFIGS.', '19\nB\n and C, there is negligible frequency dispersion of effective conductivity at frequency range of 100 Hz to 1 GHz, while effective permittivity shows some dispersion phenomena at frequency range of 100 Hz to 10 kHz.', "As oil saturation increases, both σ\neff \nand ε\nr,eff \nwill reduce, which has the similar trend as predicted by Archie's law and CRI model.", 'FIGS.', '19\nA, \n19\nB, \n19\nC, and \n19\nD\n (i.e., \nFIGS.', '19\nA-\n19\nD\n) show graphs indicating the effect of surface conductance on the properties of a nonconductive solid particle.', 'More specifically, the curves \n196\n, \n198\n, \n200\n of \nFIG.', '19\nA\n show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10% with a surface conductance of 10\n−5 \nS, 5×10\n−6 \nS, and 10\n−6\n, respectively, and with a contact angle of 30 degrees.', 'The curves \n202\n, \n204\n, and \n206\n of \nFIG.', '18\nB\n show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, with a surface conductance of 10\n−5 \nS, 5×10\n−6 \nS, and 10\n−6\n, respectively, and with a contact angle of 150 degrees.', 'The curves \n208\n, \n210\n, and \n212\n of \nFIG.', '18\nC\n show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, with a surface conductance of 10\n−5 \nS, 5×10\n−6 \nS, and 10\n−6\n, respectively, and with a contact angle of 30 degrees.', 'The curves \n214\n, \n216\n, and \n218\n of \nFIG.', '18\nD\n show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, with a surface conductance of 10\n−5 \nS, 5×10\n−6 \nS, and 10\n−6\n, respectively, and with a contact angle of 150 degrees.', 'When comparing the different curves in \nFIGS. \n19\nA-D\n, it may be observed that for the smaller the surface conductance of clay, the less obvious the conductivity dispersion will be, and permittivity exhibits dispersion.', 'As surface conductance decrease, the effective conductivity and permittivity also decrease.', 'At low values of contact angles, i.e., water-wet state, an increase in the surface conductance of clay leads to a drastic change in both conductivity and permittivity.', 'With the foregoing in mind, \nFIG. \n20\n illustrates an example process \n220\n that may be employed by the data processing system \n28\n to determine properties of a geological formation comprising certain types of solid particles (e.g., conductive and nonconductive) that may be used for certain oil and gas decisions, in accordance with embodiments described herein.', 'The steps of the process \n220\n may be stored in the memory \n32\n.', 'Before proceeding, it should be noted that the process \n220\n is described as being performed by the processor \n30\n of the data processing system \n28\n, but the process \n220\n may be performed by other suitable computing devices.', 'Although described in a particular order, which represents a particular embodiment, it should be noted that the process \n220\n may be performed in any suitable order.', 'Additionally, embodiments of the process \n220\n may omit process blocks and/or include additional process blocks.', 'At block \n222\n, the processor \n30\n may identify a type of solid particle within the geological formation.', 'In general, the processor \n30\n identifying the type of solid particle (e.g., particles) within the geological formation based on an input specifying the type of solid particles.', 'For example, an individual may provide an input specifying that the geological formation includes nonconductive particles (e.g., clay, calcite, and quartz) or conductive particles (e.g., graphite and pyrite).', 'In some embodiments, the processor \n30\n may identify the type of solid particle based on data associated with well logging measurements received by the processor.', 'For example, the processor \n30\n may receive elemental data from a well logging measurement that indicates a relative percentage of certain elements.', 'The processor \n30\n may compare the relative percentages to reference elemental data that indicates types of solid particles (e.g., stored in the memory \n32\n).', 'As such, the processor \n30\n may identify a type of solid particle when the received elemental data matches a particular reference elemental data for a type of solid particle.', 'In some embodiments, the processor may\n \nAt block \n224\n, the processor \n30\n may receive electromagnetic measurements at a set of frequencies.', 'In general, block \n222\n may occur in a general similar manner as block \n52\n of the process \n50\n of \nFIG. \n3\n.', 'For example, the processor \n30\n may identify a set of frequencies to perform an electromagnetic measurement based on the identified type of solid particle.', 'That is, and as discussed herein, the material and subsurface characterization model \n46\n may be utilized by the processor \n30\n of the data processing system \n28\n to determine a set of frequencies that the electromagnetic well-logging tool \n12\n may operate to acquire electromagnetic measurements.', 'In some embodiments, the processor \n30\n may determine a type of material and subsurface characterization model \n46\n to use to identify the set of frequencies based on the identified type of solid particles within the geological formation.', 'For example, the processor \n30\n may determine the type of material and subsurface characterization model \n46\n to use based on a relative conductivity (e.g., conductive, nonconductive, above or below a conductivity threshold) of regions of the geological formation, particles identified in the geological formation, or particles suspected of being in the geological formation.', 'That is, if the identified type of solid particle corresponds to a conductive type of solid particle (e.g., graphite and pyrite), the material and subsurface characterization model \n46\n may be based upon the effective complex conductivity of a porous fluid-filled geomaterial containing conductive particles of any wettability (e.g., graphite particle) and fully wetted surface-charge-bearing nonconductive particles (e.g., water-wet sand and clay particles), as discussed herein.', 'Additionally or alternatively, if the identified type of solid particle corresponds to a nonconductive type of solid particle, the material and subsurface characterization model \n46\n may be based upon the effective complex conductivity of a porous fluid-filled geomaterial containing surface-charge-bearing nonconductive particles (e.g., water-wet sand and mixed-wet clay particles) at any saturation of the wetting phase (e.g., water) also discussed herein.', 'That is, the processor \n30\n may select one of the models described herein to determine the set of frequencies for the electromagnetic well-logging tool \n12\n.', 'In some embodiments, the memory \n32\n of the data processing system \n28\n may store both models (e.g., a first model based on the nonconductive particles and a second model based on the conductive particles).', 'As such, when a received input, determination by the processor \n30\n, or other indication specifies that the processor \n30\n should utilized the first model or the second model, the processor \n30\n may retrieve the model.', 'At block \n226\n, the processor \n30\n may determine one or more physical properties of the geological formation using the received electromagnetic measurements as generally described with respect to block \n54\n of the process \n50\n of \nFIG. \n4\n.', 'For example, a Markov-Chain Monte-Carlo may be applied to the EM measurements received in process block \n224\n to determine properties such as the contact angles and other physical properties as described herein.', 'As one nonlimiting example of how the above-described techniques may be applied, the processor \n30\n may use the mechanistic model to identify the range of operating frequency within which the EM measurements and logs may be acquired for purposes of reliably estimating the desired properties of the fluid-filled porous material.', 'According to the identified range of operating frequencies, an EM tool/equipment may be tuned to acquire the multi-frequency electromagnetic measurements and log responses.', 'Following that, an inversion scheme coupled with a mechanistic model processes the multi-frequency electromagnetic (EM) measurements or log responses of fluid-filled porous materials to estimate the desired properties of the fluid-filled porous material.', 'The mechanistic model is coupled with a Markov-Chain Monte Carlo (MCMC) inversion scheme to simultaneously estimate the water saturation, clay surface conductance, brine/pore-filling-fluid salinity/conductivity, and the contact angle of the particles giving rise to interfacial polarization phenomena.', 'Accordingly, aspects of the present disclosure provide techniques to quantify the multi-frequency complex conductivity and/or complex permittivity of fluid-filled porous materials so as to account the effects of contact angle or wettability of conductive or surface-charge-bearing nonconductive particles (or other types of solid particles that give rise to interfacial polarization) on the conductivity and permittivity and their frequency dispersions (i.e., frequency-dependent behavior).', 'Estimate the contact angle (wettability) of conductive particles (e.g. graphite and pyrite) and surface-charge-bearing nonconductive particles (e.g. clay, calcite, and quartz) in fluid-filled porous geomaterials (in subsurface or on surface) or other fluid-filled porous materials.', 'The disclosed techniques may be used to simultaneously estimate fluid saturations, contact angle of conductive particles, contact angle of surface-charge-bearing particles, fluid conductivity/salinity, surface conductance of solid particles, diffusion coefficients of charge carriers in various material constituents, and volume fractions of fluid and solid components in the material.', 'Further, the disclosure techniques may enable for simultaneously estimation wettability (i.e., depends on contact angle) and oil saturation (i.e., depends on water saturation).', 'Further still, the disclosed techniques may be used to estimate contact angle of solid particles/grains that can give rise to interfacial polarization when surrounded by fluid phases/components for various wettability scenarios.', 'Even further, the disclosed techniques may be used to quantify the effects of contact angle or wettability of solid grains/particles (i.e., conductive or surface-charge-bearing nonconductive particle) on the net charge transport and net charge accumulation as a function of the frequency of the external electromagnetic field.', 'The net charge transport determines the conductivity and net charge accumulation determines the permittivity that govern the electromagnetic measurements and log responses of the fluid-filled porous material.', 'Additionally, the disclosed techniques may be used to quantify the multi-frequency complex conductivity and/or complex permittivity of fluid-filled porous materials so as to account the effects of contact angle or wettability of conductive or surface-charge-bearing nonconductive particles (e.g., other types of solid particles that give rise to interfacial polarization) on the conductivity and permittivity and their frequency dispersions (i.e., frequency-dependent behavior).', 'The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical.', 'Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ”', 'or “step for [perform]ing [a function] . . .', '”, it is intended that such elements are to be interpreted under 35 U.S.C. 112(f).', 'However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. 112(f).', 'The specific embodiments described above have been shown by way of example, and it should be understood that these embodiments may be susceptible to various modifications and alternative forms.', 'It should be further understood that the claims are not intended to be limited to the particular forms disclosed, but rather to cover all modifications, equivalents, and alternatives falling within the spirit and scope of this disclosure.']

['1.', 'A method comprising:\nidentifying at least one type of solid particle within the geological formation;\nidentifying a frequency range for an electromagnetic measurement based on the identified at least one type of solid particle within the geological formation;\nconveying an electromagnetic well-logging tool into a wellbore within a geological formation, wherein the electromagnetic well-logging tool includes a transmitter and a receiver;\nproducing one or more electromagnetic waves using the transmitter of the electromagnetic well-logging tool, wherein the one or more electromagnetic waves interact with the geological formation;\nreceiving, by the receiver, the one or more electromagnetic waves after the one or more electromagnetic waves have interacted with the geological formation;\ngenerating a plurality of electromagnetic (EM) measurements associated with the geological formation based on the one or more electromagnetic waves received by the receiver, wherein the plurality of EM measurements are within the identified frequency range;\ndetermining a contact angle associated with solid particles within the geological formation based on the generated plurality of EM measurements, wherein the contact angle quantifies a wettability of the at least one type of solid particle within the geological formation.', '2.', 'The method of claim 1, wherein the at least one type of solid particle comprises a conductive particle.', '3.', 'The method of claim 1, wherein the at least one type of solid particle comprises a surface-charge bearing nonconductive particle.', '4.', 'The method of claim 1, wherein identifying the frequency range is performed using a mechanistic model, wherein the mechanistic model is based upon an effective complex conductivity of a porous fluid-filled geomaterial containing conductive particles of any wettability and fully wetted surface-charge-bearing nonconductive particles.', '5.', 'The method of claim 1, wherein identifying the frequency range is performed using a mechanistic model, wherein the mechanistic model is based upon an effective complex conductivity of a porous fluid-filled geomaterial containing surface-charge-bearing nonconductive particles at a saturation of a wetting phase.', '6.', 'The method of claim 1, comprising:\nproviding as an input to a mechanistic model, one or more properties to be determined using the plurality of EM measurements and data indicative of a composition of the geological formation, wherein the one or more properties comprise the contact angle, and wherein the mechanistic model correlates one or more fluid phases, compositions, or both, to the contact angle of the at least one type of solid particle and correlates an interfacial polarization of the at least one type of solid particle to the contact angle of the at least one type of solid particle; and\nreceiving, as an output generated from the mechanistic model, the frequency range.', '7.', 'The method of claim 6, wherein the mechanistic model is developed based on solving a Young-Laplace equation to determine a spreading of oil and water phase around a conductive particle, invoking a Poisson-Nernst-Planck (PNP) equation to quantify a dipolarizability of a partially wetted graphite particle, and using an effective medium model to combine the interfacial polarization effects of nonconductive particles and conductive particles.', '8.', 'The method of claim 1, wherein the contact angle is determined based on the generated plurality of EM measurements using a frequency-dependent complex conductivity, a frequency-dependent complex permittivity, or both associated with the type of solid particle within the geological formation.', '9.', 'The method of claim 1, wherein the frequency range corresponds to where frequency dispersions in conductivity, permittivity, or both of the at least one type of solid particle are measureable.', '10.', 'A system, comprising:\na non-transitory machine-readable medium storing a first mechanistic model and a second mechanistic model;\na processor configured to execute instructions stored in the non-transitory, machine readable medium to perform operations, comprising: identifying a type of solid particle present within a geological formation; identifying at least one model to use based on a relative conductivity of the type of the solid particle, wherein the model comprises the first mechanistic model, the second mechanistic model, or both; receiving, as an input to the identified at least one model, one or more inputs indicative of estimated properties of the porous, fluid-filled geological formation, wherein the mechanistic model correlates one or more fluid phases, compositions, or both, to a contact angle of at least one type of solid particle and correlates an interfacial polarization of the at least one type of solid particle to the contact angle of the at least one type of solid particle; generating, as an output by the identified at least one model, a set of frequencies to measure by an electromagnetic well-logging tool, wherein the set of frequencies corresponds to where frequency dispersions in conductivity, permittivity, or both are measureable, and\nthe electromagnetic well-logging tool having a transmitter and a receiver, wherein: the transmitter is configured to produce one or more electromagnetic waves; the one or more electromagnetic waves interact with the geological formation; the receiver is configured to receive the one or more electromagnetic waves after the one or more electromagnetic waves have interacted with the geological formation; and the electromagnetic well-logging tool is configured to generate a plurality of electromagnetic (EM) measurements within the set of frequencies based on the one or more electromagnetic waves received by the receiver.', '11.', 'The system of claim 10, wherein the set of frequencies comprises a plurality of discrete frequencies.']

['FIG.', '1 is an example of a neutron-induced gamma-ray spectroscopy system, in accordance with an embodiment;; FIG.', '2 is an example of a neutron-induced gamma-ray spectroscopy downhole tool, in accordance with an embodiment;; FIG.', '3 is an example of a process for determining properties of a fluid-filled formation, in accordance with an embodiment;; FIG.', '4 is an example illustration of a cross section of a volume that includes a solid suspended in an oil-water media, in accordance with an embodiment;; FIG.', '5A shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;; FIG.', '5B shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;; FIG.', '5C shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;; FIG.', '5D shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;; FIG.', '6A shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different oil saturations with a contact angle of 30°, in accordance with an embodiment;; FIG.', '6B shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different oil saturations with a contact angle of 90°, in accordance with an embodiment;; FIG.', '6C shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different oil saturations with a contact angle of 150°, in accordance with an embodiment;; FIG.', '6D shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different oil saturations with a contact angle of 30°, in accordance with an embodiment;; FIG.', '6E shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different oil saturations with a contact angle of 90°, in accordance with an embodiment;; FIG.', '6F shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different oil saturations with a contact angle of 150°, in accordance with an embodiment;; FIG.', '7A shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates of clay surface conductance for oil-water-filled porous material containing water-wet sands, clays, and graphite, in accordance with an embodiment;; FIG.', '7B shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates of graphite contact angle for oil-water-filled porous material containing water-wet sands, clays, and graphite, in accordance with an embodiment;; FIG.', '7C shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates of water conductivity for oil-water-filled porous material containing water-wet sands, clays, and graphite, in accordance with an embodiment;; FIG.', '8A shows graphs depicting a histogram of MCMC inversion-derived estimates of clay surface conductance of FIG.', '7A, in accordance with an embodiment;; FIG.', '8B shows graphs depicting a histogram of MCMC inversion-derived estimates of graphite contact angle of FIG.', '7B, in accordance with an embodiment;; FIG.', '8C shows graphs depicting a histogram of MCMC inversion-derived estimates of water conductivity of FIG.', '7C, in accordance with an embodiment;; FIG.', '9A shows multi-frequency electromagnetic (EM) measurements and model predictions based on inversion-derived estimates of effective conductivity associated with FIGS.', '7A, 7B, and 7C and FIGS.', '8A, 8B, and 8C, in accordance with an embodiment;; FIG.', '9B shows multi-frequency electromagnetic (EM) measurements and model predictions based on inversion-derived estimates of effective permittivity associated with FIGS.', '7A, 7B, and 7C and FIGS.', '8A, 8B, and 8C, in accordance with an embodiment;; FIG.', '10A shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for clay surface conductance for oil-water-filled porous material containing water-wet sands, clays, and slightly oil-wet graphite, in accordance with an embodiment;; FIG.', '10B shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for graphite contact angle for oil-water-filled porous material containing water-wet sands, clays, and slightly oil-wet graphite, in accordance with an embodiment;; FIG.', '10C shows graphs depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for water conductivity for oil-water-filled porous material containing water-wet sands, clays, and slightly oil-wet graphite, in accordance with an embodiment;; FIG.', '11A shows graphs depicting a histogram of MCMC inversion-derived estimates of clay surface conductance of FIG.', '10A, in accordance with an embodiment;; FIG.', '11B shows graphs depicting a histogram of MCMC inversion-derived estimates of graphite contact angle of FIG.', '10B, in accordance with an embodiment;; FIG.', '11C shows graphs depicting a histogram of MCMC inversion-derived estimates of water conductivity of FIG.', '10C, in accordance with an embodiment;; FIG.', '12A shows multi-frequency EM measurements and model predictions for effective conductivity based on inversion-derived estimates associated with FIGS.', '10A, 10B, and 10C and FIGS.', '11A, 11B, and 11C, in accordance with an embodiment;; FIG.', '12B shows multi-frequency EM measurements and model predictions for effective permittivity based on inversion-derived estimates associated with FIGS.', '10A, 10, and IOC and FIGS.', '11A, 11B, and 11C, in accordance with an embodiment;; FIG.', '13A shows a graph depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for contact angle for oil/water-filled porous material containing water-wet sand and clays and oil-wet graphite, in accordance with an embodiment;; FIG.', '13B shows a graph depicting a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates for contact angle for oil saturation oil/water-filled porous material containing water-wet sand and clays and oil-wet graphite, in accordance with an embodiment;; FIG.', '14A shows a graph depicting a histogram of MCMC inversion-derived estimates of clay surface conductance of FIG.', '13A, in accordance with an embodiment;; FIG.', '14B shows a graph depicting a histogram of MCMC inversion-derived estimates of oil saturation of FIG.', '13B, in accordance with an embodiment;; FIG.', '15A shows multi-frequency EM measurements and model predictions for effective conductance based on inversion-derived estimates associated with FIGS.', '13A and 13B, and FIGS.', '14A and 14B, in accordance with an embodiment;', '; FIG.', '15B shows multi-frequency EM measurements and model predictions for effective permittivity based on inversion-derived estimates associated with FIGS.', '13A and 13B, and FIGS.', '14A and 14B, in accordance with an embodiment;', '; FIG.', '16 is an example illustration of a cross section of a volume that includes a solid suspended in an oil-water media, in accordance with an embodiment;; FIG.', '17A shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;; FIG.', '17B shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;; FIG.', '17C shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 10% oil saturation, in accordance with an embodiment;; FIG.', '17D shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different contact angles with a 90% oil saturation, in accordance with an embodiment;; FIG.', '18A shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 30 degrees, in accordance with an embodiment;; FIG.', '18B shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 150 degrees, in accordance with an embodiment;; FIG.', '18C shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 30 degrees, in accordance with an embodiment;; FIG.', '18D shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different amounts of oil saturation for a contact angle of 150 degrees, in accordance with an embodiment;; FIG.', '19A shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different surface conductance with a contact angle of 30 degrees, in accordance with an embodiment;; FIG.', '19B shows a graph illustrating an example of determined effective conductivity for fluid-filled porous material for different surface conductance with a contact angle of 150 degrees, in accordance with an embodiment;; FIG.', '19C shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different surface conductance with a contact angle of 30 degrees, in accordance with an embodiment;; FIG.', '19D shows a graph illustrating an example of determined effective permittivity for fluid-filled porous material for different surface conductance with a contact angle of 150 degrees, in accordance with an embodiment; and; FIG.', '20 is a second example of a process for determining properties of a fluid-filled formation, in accordance with an embodiment.; FIG.', '2 shows an example of an electromagnetic well-logging tool 12 that may acquire electromagnetic measurements.', 'The illustrated embodiment of the electromagnetic well-logging tool 12 includes a transmitter 40 and a receiver 42.', 'While only one transmitter 40 and one receiver 42 are shown, it should be noted that the number of transmitters and receivers is not a limit on the scope of the present disclosure.', 'Generally speaking, the transmitter 40 induces electric eddy currents to produce electromagnetic waves 44 having a set of frequencies in a direction of the magnetic dipole moment of the transmitter 40.', 'The electromagnetic waves 44 that interact with the geological formation 14 are subsequently received by the receiver 42 to generate electromagnetic measurements.; FIG.', '3 illustrates a process 50 for determining one or more physical properties of a fluid-filled geological formation.', 'Although described in a particular order, which represents a particular embodiment, it should be noted that the process 50 may be performed in any suitable order.', 'Additionally, embodiments of the process 50 may omit process blocks and/or include additional process blocks.', 'Moreover, in some embodiments, the process 50 may be implemented at least in part by executing instructions stored in a tangible, non-transitory, computer-readable medium, such as memory 32 implemented in a data processing system 28, using processing circuitry, such as a processor 30 implemented in the data processing system 28.; FIG.', '4 is an example illustration of a cross-section of a volume 56 (e.g., within a geological formation) that includes a solid particle 57 suspended in an oil-water media, in accordance with an embodiment.', 'In general, the volume 56 may be assumed for developing the model, as discussed herein.', 'As shown, the solid particle 57 is a circle (e.g., a cross-section of a sphere); however, it should be noted that, in some embodiments, the solid particle may be ellipsoidal (e.g., a diameter 58 of the solid particle 57 may be greater than or less than a diameter 59 of the solid particle 57) or have a radial normal distribution of radii.; FIGS.', '5A and 5B show graphs of effective conductivity and FIGS.', '5C and 5D show graphs of effective permittivity for mixtures including a conductive solid particle.', 'More specifically, the curves in the graph 62 and graph 64 show effective conductivity, and the curves in the graph 66 and graph 68 show effective permittivity.', 'When comparing the different curves in graph 62 and graph 66, or graph 64 and graph 68, the frequency dispersion reduces as contact angle increases, which means the conductive particle becomes oil wet.', 'This is because, as contact angle increases, the graphite surface is covered more by oil, which has much fewer charge carriers than water and impedes the interfacial polarization in the fluid phase which lowers charge accumulation.', 'As oil saturation increases, both σ_eff and ε_(r,eff) will reduce due to the increase in the volume fraction of oil as nonconductive inclusion.', 'Both σ_eff and ε_(r,eff) will converge to a single value at high frequency because the charge carriers rapidly respond to the alternating external EM field and there is no net accumulation around particles, resulting in an apparent increase in conductivity.', 'Consequently, conductivity reaches to a high value and permittivity reaches to a low value (representing only dipole moment of water) at high frequency close to 1 GHz.', "In the contrast, at low frequency, the charge carriers quickly reach the equilibrium distribution around the conductive particles' interface, so that the polarized particles act as insulators, which lead to lower σ_eff and higher ε_(r,eff).", 'σ_eff at low frequency can be modeled using effective medium model assuming the conductive particles to be insulators.; FIGS.', '6A, 6B, and 6C (i.e., FIGS.', '6A-C) show graphs of effective conductivity and FIGS.', '6D, 6E, and 6F (i.e., FIGS.', '6D-F) effective permittivity for mixtures including a conductive solid particle.', 'More specifically, the curves in the graph 70, graph 72, and graph 74 show effective conductivity, and the curves in the graph 76, graph 78, and graph 80 show effective permittivity.', 'When comparing the different curves in graph 70 and graph 76, graph 72 and graph 78, and graph 74 and graph 80, the frequency dispersion reduces as oil saturation increases because graphite surface is covered more by oil, similar to the effect of contact angle.', 'It should be noted that as oil saturation increases, both σ_eff and ε_(r,eff) will reduce due to the increase in the volume fraction of oil because the oil behaves as nonconductive inclusion.', 'Also, by comparing the rate of change among curves in graph 62 and graph 66 (e.g., as shown in FIGS. 5A and 5C) and graph 70 and graph 76 (e.g., as shown in FIGS.', '6A and 6D), it is evident that the effect of change in oil saturation from 10% to 70% on the frequency dispersion of conductivity and permittivity is much lower than the effect of change in contact angle from 0° to 180°.', 'This indicates that the contact angle plays a primary effect and oil saturation plays a secondary effect in controlling the multi-frequency behavior.;', 'FIGS.', '7A, 7B, and 7C (i.e., FIGS.', '7A-C) show a graph 90, a graph 92, and a graph 94, which each depict a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates.', 'More specifically, the graph 90, the graph 92, and the graph 94 illustrate the MCMC inversion of multi-frequency EM measurements of conductivity and permittivity (shown in FIGS.', '9A and 9B) to estimate clay surface conductance λc (e.g., shown in graph 90), graphite contact angle θ (e.g., shown in graph 92), and water conductivity σw (e.g., shown in graph 90) for oil/water-filled porous material containing water-wet sand, clays, and graphite.; FIGS.', '8A, 8B, and 8C (i.e., FIGS.', '8A-C) show a graph 96, a graph 98, and a graph 100, which each depict a histogram of MCMC inversion-derived estimates of clay surface conductance, graphite contact angle, and water conductivity.', 'The graph 96, the graph 98, and the graph 100 represent histograms of MCMC inversion-derived estimates of clay surface conductance λc (e.g., shown in graph 96), graphite contact angle θ (e.g., shown in graph 98), and water conductivity σw (e.g., shown in graph 100).', 'A line 102 represents the original values of the properties and the region between lines 104 and 106 represent 90% highest posterior density (HPD) interval of the inversion-derived estimates.;', 'FIGS.', '9A and 9B show a graph 108 of multi-frequency EM measurements and a graph 110 of model predictions based on inversion-derived estimates.', 'More specifically, the graph 108 and the graph 110 illustrates a comparison of the multi-frequency EM measurements against the mechanistic model predictions for effective permittivity based on the inversion-derived estimates for effective conductance and effective permittivity.; FIGS.', '10A, 10B, and 10C show a graph 112, a graph 114, and a graph 116, which each depict a history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates.', 'More specifically, the graph 112, the graph 114, and the graph 116 illustrate the MCMC inversion of multi-frequency EM measurements of conductivity and permittivity (shown in FIGS.', '12A and 12B)', 'to estimate clay surface conductance λc (e.g., shown in graph 112), graphite contact angle θ (e.g., shown in graph 114), and water conductivity σw (e.g., shown in graph 116) for oil/water-filled porous material containing water-wet sand and clays and slightly oil-wet graphite.', '; FIGS.', '11A, 11B, and 11C show a graph 118, a graph 120, and a graph 122, which each depict a histogram of MCMC inversion-derived estimates of clay surface conductance, graphite contact angle, and water conductivity.', 'More specifically, the graph 118, the graph 120, and the graph 120 illustrate a histogram of MCMC inversion-derived estimates of clay surface conductance λc (e.g., shown in graph 118), graphite contact angle θ (e.g., shown in graph 120), and water conductivity σw (e.g., shown in graph 122).', 'The line 102 represents the original values of the properties and the region between lines 104 and 106 represent 90% HPD interval of the inversion-derived estimates.; FIGS.', '12A and 12B show a graph 124 of multi-frequency MS measurements and a graph 126 of model predictions based on inversion-derived estimates.', 'More specifically, the graph 124 and graph 126 illustrate a comparison of the multi-frequency EM measurements against the mechanistic model predictions based on the inversion-derived estimates of effective conductance and effective permittivity.; FIGS.', '13A and 13B show a graph 128 and a graph 130 that each history of Markov Chain Monte Carlo (MCMC) inversion-derived estimates.', 'More specifically, the graph 128 and the graph 130 illustrate the MCMC inversion of multi-frequency EM measurements of conductivity and permittivity (shown in FIGS.', '15A and 15B) to estimate graphite contact angle θ and oil saturation So for oil/water-filled porous material containing water-wet sand and clays and oil-wet graphite.;', 'FIGS.', '14A and 14B show a graph 132 and a graph 134 that each depict a third histogram of MCMC inversion-derived estimates of clay surface conductance, graphite contact angle, and water conductivity.', 'More specifically, the graph 132 and the graph 134 illustrate the histogram of MCMC inversion-derived estimates of graphite contact angle θ and oil saturation So.', 'The line 102 represents the original values of the properties and the region between lines 104 and 106 represent 90% HPD interval of the inversion-derived estimates.;', 'FIGS.', '15A and 15B show a graph 136 of multi-frequency MS measurements and a graph 138 model predictions based on inversion-derived estimates.', 'More specifically, the graph 136 and the graph 138 illustrate a comparison of the multi-frequency EM measurements against the mechanistic model predictions based on the inversion-derived estimates of effective conductance and effective permittivity.; FIGS.', '17A, 17B, 17C, and 17D (i.e., FIGS.', '17A-17D) show graphs indicating the effect of contact angle on the properties of a nonconductive solid particle.', 'More specifically, the curves 148, 150, and 152 of FIG.', '17A show the effective conductivity at a contact angle of 30 degrees, 90 degrees, and 150 degrees for a mixture containing water-wet sand and clay particles with a surface conductance of 10−6 S, partially saturated with brine/water and an oil saturation of 10%.; FIGS.', '18A, 18B, 18C, and 18D (i.e., FIGS.', '18A-18D) show graphs indicating the effect of oil saturation on the properties of a nonconductive solid particle.', 'More specifically, the curves 172, 174, and 176 of FIG.', '18A show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10%, 50%, and 90% for a with a surface conductance of 10−6 S with a contact angle of 30 degrees.; FIGS.', '19A, 19B, 19C, and 19D (i.e., FIGS.', '19A-19D) show graphs indicating the effect of surface conductance on the properties of a nonconductive solid particle.', 'More specifically, the curves 196, 198, 200 of FIG.', '19A show the effective conductivity for a mixture containing water-wet sand and clay particles partially saturated with brine/water and an oil saturation of 10% with a surface conductance of 10−5 S, 5×10−6 S, and 10−6, respectively, and with a contact angle of 30 degrees.']

US11789170

Induced seismicity

Jun 15, 2016

Bogdan Bocaneala, Michael Welch, Murat Zhiyenkulov, Vincenzo De Gennaro, Kamshat Ussenova, David Cameron

Schlumberger Technology Corporation

Maxewell et al; Geomechanical modeling of induced seismicity resulting from hydraulic fracturing; Special Section: Injection-induced seismicity; The Leading Edge Jun. 2015; pp. 678-683 (Year: 2015).; Hajati, T., C. Langenbruch, and S. A. Shapiro (2015), A statistical model for seismic hazard assessment of hydraulic-fracturing-induced seismicity, Geophys. Res. Lett., 42, pp. 10,601-10,606, doi:10.1002/2015GL066652.; Dec. 23, 2015 (Year: 2015).; William L. Ellsworth ,Injection-Induced Earthquakes.Science341,1225942(2013).DOI:10.1126/science.1225942 p. 8 (Year: 2013).; Zhao et al., “Numberical Simulation of Seismicity Induced by Hydraulic Fracturing in Naturally Fractured Reservoirs”, SPE 124690, SPE Annual Technical Conference and Exhibtion, Oct. 2009, 17 pages.; Santos et al., “Modeling hydraulic fracturing and induced seismicity in unconventional reservoirs using multphase fluid-flow simulations”, SEG Technical Program Expanded Abstracts, Aug. 19, 2015, pp. 5053-5057.; International Search Report and Written Opinion issued in International Patent Application No. PCT/IB2016/000985 dated Apr. 18, 2017; 20 pages.

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['A stimulation includes an injection of a volume of fluid into a formation.', 'A method includes obtaining a mechanical earth model of the formation, modeling a hydraulic fracture growth pattern in the formation from a stimulation of the formation, determining an increase in pressure in the formation resulting from the stimulation, and predicting whether a seismic event will occur in the formation based on the increase in pressure.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nHydrocarbons (oil, natural gas, etc.) may be obtained from a subterranean geological formation, or reservoir, by drilling a well that penetrates the hydrocarbon-bearing formation.', 'This provides a partial flowpath for the hydrocarbon to reach the surface.', 'In order for the hydrocarbon to be produced, that is travel from the formation to the wellbore and ultimately to the surface, a sufficiently unimpeded flowpath should be formed from the formation to the wellbore.', 'Hydraulic fracturing may improve well productivity by extending reservoir contact between the borehole and the reservoir.', 'This operation may be performed by perforating a wellbore penetrating the formation and hydraulically injecting a fracturing fluid into the wellbore and forcing the fracturing fluid against the formation strata by pressure.', 'The formation strata or rock is forced to crack and fracture, thereby increasing flow paths between the reservoir and the borehole.', 'Proppant may be placed in the fracture to prevent the fracture from closing and thus, provide improved flow of the recoverable hydrocarbons.', 'Once a fracture is initiated, enough bottomhole pressure may be maintained to propagate the fracture further away from the wellbore and generate the necessary fracture width for it to be filled with the propping material that will keep the fracture open once the pumping has stopped.', 'The initial breakdown pressure may be higher than the minimum pressure needed to re-open the same fracture due to the tectonic stress in the rock that has to be initially overcome.', 'Hydraulic fracturing, including perforating and fluid injection into a formation, may induce or trigger seismic activity.', 'Fluid withdrawal (e.g., pumping hydrocarbons from the formation) from hydraulic fracturing operations may also induce seismic activity.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'In one aspect, embodiments of the present disclosure relate to a method that includes obtaining a mechanical earth model of a formation, modeling a hydraulic fracture growth pattern in the formation from a stimulation of the formation, the stimulation including an injection of a volume of fluid into the formation, determining an increase in pressure in the formation resulting from the stimulation, and predicting whether a seismic event will occur in the formation based on the increase in pressure.', 'In another aspect, embodiments disclosed herein relate to a method that includes obtaining a mechanical earth model of a formation, modeling a hydraulic fracture growth pattern in the formation from a stimulation of the formation, the stimulation being performed in a plurality of stages along a borehole extending through the formation, determining an increase in pressure in the formation resulting from the stimulation, generating a stress profile for each of the plurality of stages, each stress profile including a map of stress over an area of the formation, performing at least one of the stages of the stimulation, measuring stress within the area of the formation around a completed stage of the stimulation to generate a measured stress profile of the completed stage, and calibrating the completed stage of the stimulation prior to performing a subsequent stage of the stimulation, where calibrating includes updating one or more input parameters of the model to match the modeled stress profile of the completed stage with the measured stress profile of the completed stage.', 'In yet another aspect, embodiments disclosed herein relate to system for generating a model of a formation that includes a computer processor and memory comprising instructions executing on the computer processor with functionality to perform: receiving parameters of the formation, modeling a mechanical earth model of the formation based on the parameters, simulating a stimulation of the formation, the stimulation including an injection of a volume of fluid into the formation, modeling a hydraulic fracture growth pattern in the formation from the stimulation of the formation, and presenting, on a graphical user interface, a stress profile of the formation including changes in stress through the formation resulting from a change in pressure through the reservoir, the stress profile generated from the mechanical earth model and the hydraulic fracture growth pattern model.', 'Other aspects of the invention will be apparent from the following description and the appended claims.', 'BRIEF DESCRIPTION OF DRAWINGS\n \nFIG.', '1\n depicts an example of a formation having geological features therein.\n \nFIG.', '2\n shows a diagram of a multistage stimulation of a formation according to methods of the present disclosure.\n \nFIG.', '3\n depicts a system with which one or more embodiments of the present disclosure may be implemented.\n \nFIG.', '4\n shows a system according to embodiments of the present disclosure.', 'DETAILED DESCRIPTION\n \nEmbodiments of the present disclosure relate generally to methods for evaluating the potential of generating induced seismicity caused by hydraulic fracturing operations or large volume water injection operations.', 'Evaluating potential of induced seismicity may facilitate planning permissions for shale gas operators in sensitive areas, such as high population density areas.', 'Methods of the present disclosure may provide recommendations for well planning to mitigate the risk of generating induced seismicity, such as drilling direction, fracture initiation point locations, fracture fluid volume, fracturing fluid type, and maximum proppant concentration.', 'Methods according to embodiments of the present disclosure may be initially completed with relatively little data and high uncertainty.', 'The level of uncertainty may be reduced as well construction operations progress and additional well data is collected, for example, through data acquisition from drilling, wireline logs, core analysis, and surface analysis.', 'Uncertainty of generating induced seismicity during hydraulic fracturing operations may be further reduced by updating and calibrating the model using offset well data.', 'According to embodiments of the present disclosure, methods of evaluating and/or predicting induced seismic activity may include evaluating natural fractures, faults and other geological features in a target reservoir or formation.', 'Properties of a target formation, including but not limited to material properties, natural fractures, faults and other geological features in the target formation, may be characterized using available core data, borehole imaging data, outcrop analogues, seismic data, and other wellsite data, for example.', 'For example, outcrop analogues may be used to understand fracture density, distribution, orientation, geometry and connectivity in the subsurface of the formation.', 'Evaluation of natural fractures and faults may include data acquisition from subsurface measurement tools and/or surface measurement tools.', 'For example, subsurface tools, such as logging tools, may be sent down a hole drilled through a formation to measure properties of the formation below the surface, such as density, porosity, and resistivity.', 'In downhole logging, instruments (e.g., magnetic induction sensors or gamma-ray sensors) may be attached to a downhole tool that transmits sensed data up a wireline or via another communication channel to a data processing system.', 'Surface measurement tools may measure different properties of the formation from the surface of the formation.', 'For example, seismometers along a surface of a formation may measure seismic waves generated by seismic activity of the formation.', 'In some embodiments, surface analysis may include analyzing surficial geology, such as by characterizing layers between rock volumes with different properties, analyzing changes in rock types at the surface, and/or analyzing changes in geological features at the surface, such as fault lines.', 'Many types of data acquisition may be used for gathering data related to formation properties, including but not limited to seismic data acquisition (e.g., activating a seismic source, such as airguns, vibrators or explosives, generating sufficient acoustic energy to penetrate the earth, and recording reflected or refracted parts of this energy by seismic receivers such as hydrophones and geophones), logging or drilling operations of the oil and gas industry, and of interpretations made from these measurements.', "The data may be gathered above, on, or below the earth's surface.", 'As the duration or number of sub-surface operations increases, more data may be gathered.', 'Further, in some embodiments, seismic activity (including micro-seismic events and/or macro-seismic events) in a formation of interest may be measured for a time period to determine if the formation has an active fault.', 'Monitoring of seismic activity in a formation of interest may be conducted prior to stimulation operations in the formation, for example, to determine preexisting conditions in the formation that may be relevant for modeling mechanical earth models and when modeling fracturing networks, as described more below.', 'Seismic activity in the formation of interest may continue to be monitored after conducting stimulation operations, for example, for collecting data useful in calibration of one or more models of the formation.', 'Mechanical earth models of a formation may be generated based on data acquired from the formation and may include a map of both the geological features (e.g., micro- and macro-scale natural fractures and faults) and the mechanical properties in the formation of interest.', 'For example, mechanical earth models, such as boundary element, finite element and discrete element models, may be used to predict fracture distribution and orientation around larger structures such as faults and folds.', 'In faulted settings, a formation may be modeled multiple times, once in each block of the formation containing a fault, with a different deformed shape in each block.\n \nFIG.', '1\n shows an example of a formation \n100\n having fault lines \n102\n extending below the surface of the formation \n100\n.', 'A volume of interest of the formation \n100\n is shown in \nFIG.', '1\n, which may vary depending on, for example, the seismic survey coverage or how engineers define their models (e.g., by the entire reservoir or part of a reservoir).', 'For example, a volume of interest may include part of a reservoir or an entire reservoir, which may range, for example, from several cubic kilometers or more.', 'The fault lines \n102\n through the volume of interest may be used to define fault blocks.', 'The technique of designating fault lines through a volume of interest in a formation is referred to as fault splitting, where the faults separate the volume of interest into fault blocks.', 'The fault blocks may or may not contain one or more wellbores.', 'For example, as shown in \nFIG.', '1\n, a wellbore \n104\n extends through a fault block in the formation \n100\n between two fault lines \n102\n.', 'A structural framework model of the volume of interest may be generated by partitioning the fault blocks into a set of blocks units (e.g., by partitioning the fault blocks with horizon lines) and organizing geological data (obtained through data acquisition from above or below the surface of the formation, such as described above) into several sub-regions of the formation \n100\n.', 'For example, surface and sub-surface data points lying inside a fault block may be isolated and extrapolated past the boundaries of the block unit under investigation, and material properties may be assigned to each of the subregions.', 'Modeling software may be used to generate mechanical earth models of a formation based on data acquired from the formation.', 'For example, modeling software may be used to predict fracture density, vertical connectivity and aperture in a mechanically layered sequence based on well log data from a formation.', 'According to some embodiments, a system for generating a model of a formation may include a computer processor and memory having instructions executing on the computer processor with functionality to receive parameters of the formation (e.g., from data acquisition) and to model a mechanical earth model of the formation based on the parameters.', 'In some embodiments, a system may also include at least one sensor in communication (e.g., wired or wireless communication) with a computer processor running modeling software, where the sensor(s) may measure at least one parameter of the formation.', 'Modeling software useful for modeling a formation may include but is not limited to GeoFrame™, Petrel™, and RDR Fault Modeler™ software, marketed by Schlumberger, for example.', 'Other modeling software may be used to model geomechanical models of a formation of interest, such as FluvSim™, Roxar™ by Emerson, SKUA™ by Paradigm, IHS Kingdom™ by IHS, and Jewel Suite™ by Baker Hughes.', 'In addition to obtaining a mechanical earth model of a formation of interest, embodiments of the present disclosure may include modeling a hydraulic fracture growth pattern in the formation (modeled by the mechanical earth model) resulting from a stimulation in the formation.', 'The interaction of hydraulic fractures resulting from a stimulation, fractures from drilling operations, natural fractures and faults may be included in a hydraulic fracture growth pattern model.', 'FIG.', '2\n, discussed in detail below, shows a diagram of an example of simulating a multistage stimulation in a formation \n210\n of interest.', 'In the simulation of the stimulation, both the mechanical earth model and the hydraulic fracture growth pattern in the formation \n210\n may be used to predict changes in pressure and stress throughout the formation \n210\n, and thus may be used to predict seismic activity.', 'As used herein, stimulation may refer to selectively placing wellbore stimulation fluids (e.g., acids) downhole during a stimulation operation (or treatment) to facilitate the production of fluids from subsurface reservoirs.', 'Stimulation operations may involve, for example, acid treatments, such as matrix acidizing, or hydraulic fracturing.', 'Matrix acidizing may involve pumping an acid into an oil or gas-producing well to remove some of the formation damage along a wall of the wellbore caused by the drilling and completion fluids and drill bits during the drilling and completion process.', 'Hydraulic fracturing may involve injecting a volume of fluid into the formation to create fractures that define larger pathways for fluid to pass from subsurface reservoirs and into the wellbore.', 'Stimulation fluids may be placed in select zones along the wellbore based on an understanding of operational objectives, such as maximum production rate, maximum fluid recovery, uniform placement of fluids across zones, and/or other objectives, for performing the stimulation operation.', 'The stimulation fluids may also be applied using various stimulation parameters, such as flow rates, concentrations, composition, etc.', 'Other considerations may be taken into account, such as the skin surrounding the wellbore and/or other wellsite parameters.', 'Modeling software may be used to simulate a stimulation in a formation of interest.', 'According to embodiments of the present disclosure, the modeling software for simulating a stimulation may take into account stress anisotropy through the formation as well as the interactions of the hydraulic fractures with the natural fractures in the formation.', 'For example, an unconventional fracture model (UFM) (or complex model) may be used to simulate complex fracture network propagation in a formation with pre-existing natural fractures.', 'Multiple fracture branches can propagate simultaneously and intersect/cross each other.', 'Each open fracture may exert additional stresses on the surrounding rock and adjacent fractures, which may be referred to as “stress shadow” effect.', 'The stress shadow can cause a restriction of fracture parameters (e.g., width), which may lead to, for example, a greater risk of proppant screenout.', 'The stress shadow can also alter the fracture propagation path and affect fracture network patterns.', 'The stress shadow may affect the modeling of the fracture interaction in a complex fracture model.', 'Thus, to simulate the propagation of multiple or complex fractures, a fracture model may take into account an interaction among adjacent hydraulic fracture branches (the stress shadow effect).', 'When a single planar hydraulic fracture is opened under a finite fluid net pressure, it may exert a stress field on the surrounding rock that is proportional to the net pressure.', 'Fracture interaction, including planar and complex fractures propagating from multiple perforation clusters along a borehole in stimulation operations, may control the fracture dimension and propagation pattern.', 'In a formation with small stress anisotropy, fracture interaction may lead to dramatic divergence of the fractures as they may tend to repel each other.', 'However, even when stress anisotropy is large and fracture turning due to fracture interaction is limited, stress shadowing may have a strong effect on fracture width, which may affect the injection rate distribution into multiple perforation clusters, and hence overall fracture network geometry and proppant placement.', 'The dynamics of simultaneously propagating multiple fractures may also depend on the relative positions of the initial fractures.', 'If the fractures are parallel, e.g. in the case of multiple fractures that are orthogonal to a horizontal wellbore, the fractures may repel each other, resulting in the fractures curving outward.', 'However, if the multiple fractures are arranged in an en echelon pattern, e.g. for fractures initiated from a horizontal wellbore that is not orthogonal to the fracture plane, the interaction between the adjacent fractures may be such that their tips attract each other and even connect.', 'When a hydraulic fracture intersects a secondary fracture oriented in a different direction, it may exert an additional closure stress on the secondary fracture that is proportional to the net pressure.', 'This stress may be derived and be taken into account in the fissure opening pressure calculation in the analysis of pressure-dependent leakoff in fissured formation.', 'For more complex fractures, a combination of various fracture interactions as discussed above may be present.', 'To properly account for these interactions and remain computationally efficient so it can be incorporated in the complex fracture network model, a proper modeling framework may be constructed.', 'A method based on an enhanced 2D Displacement Discontinuity Method (2D DDM) may be used for computing the induced stresses on a given fracture and in the rock from the rest of the complex fracture network.', 'Fracture turning may also be modeled based on the altered local stress direction ahead of the propagating fracture tip due to the stress shadow effect.', 'According to embodiments of the present disclosure, simulations of a hydraulic fracture network may include an UFM model that incorporates fracture interaction modeling.', 'For example, fracture interaction may be taken into account to model hydraulic fracture propagation in naturally fractured reservoirs.', 'This includes, for example, the interaction between hydraulic fractures and natural fractures, as well as interaction between hydraulic fractures.', 'In some embodiments, a wiremesh model may be used to simulate nonplanar complex hydraulic fractures in reservoirs and model a hydraulic fracture growth pattern.', 'A wiremesh model is a mathematical representation of the hydraulic fracture network, which may provide an estimation of fracture network dimensions.', 'A hydraulic fracture growth pattern may be modeled in a mechanical earth model to obtain a combined fracture growth and mechanical earth model.', 'The combined fracture growth and mechanical earth model may be used for analysis of effects in the formation from a stimulation.', 'According to some embodiments of the present disclosure, methods of formation analysis may include obtaining a mechanical earth model of a formation, modeling a hydraulic fracture growth pattern in the formation from a stimulation of the formation, determining an increase in pressure in the formation resulting from the stimulation, and predicting whether a seismic event will occur in the formation based on the increase in pressure.', 'Using a generated mechanical earth model and hydraulic fracture growth pattern model of a formation, pressure changes in the formation as a result of a stimulation (e.g., fluid injection during a hydraulic fracturing operation) may be determined.', 'For example, initial pressure measurements may be determined in a formation of interest prior to conducting and/or simulating a stimulation within the formation.', 'Initial pressure measurements may be calculated from a mechanical earth model of the formation and/or may be calculated based on downhole data, such as data acquired through logging or other downhole measurement devices.', 'Post-stimulation pressure measurements from a simulated stimulation in the formation may be determined after and/or during the simulation of the stimulation.', 'The change in pressure between initial pressure measurements and post-stimulation pressure measurements may be used, for example, to predict if there may be a seismic event.', 'Pore pressure within a volume of interest in a formation may be determined, for example, by using overlay charts to empirically match well log data to drilling fluid weights, using physical characteristics of the borehole, such as measuring density, measuring electrical characteristics, e.g., resistivity or conductivity, or measuring chemical characteristics, e.g., salinity, elemental cationic concentration, sulfate or carbonate ions concentration, or changes in rate of escape of atomic particles, or by measuring acoustic emissions.', 'In some embodiments, data for calculating pore pressure may be obtained using measurement-while-drilling (MWD) techniques or after drilling by using recorded data or openhole wireline data.', 'Increases in pore pressure resulting from injection of fracturing fluid may be modeled over the combination of natural and manmade fractures.', 'According to methods of the present disclosure, initial pore pressures may be calculated prior to an injection of fracturing fluid or prior to a simulation of injecting fracturing fluid.', 'A model of a fracture growth pattern in the formation, including interaction of hydraulic fractures, natural fractures and faults, after injection of fracturing fluid may then be constructed.', 'Resulting pore pressures after simulation of the injection of fracturing fluid may be calculated based on the model.', 'The change in pore pressure between initial pore pressures and resulting pore pressures may be used to predict whether a seismic event may occur.', 'According to some embodiments of the present disclosure, an increase in pressure from initial pressure within a formation model prior to stimulation to resulting pressure within the formation after a stimulation is simulated may be calculated based on the volume of fluid that is simulated as being injected into the formation.', 'In such embodiments, the volume of stimulation fluid injected may be related to the increase in pressure, where the larger volume of stimulation fluid injected, the larger the increase in pressure, and vice versa.', 'The volume of fluid that flows into the formation may be calculated based, in part, on the porosity of the formation, and the extent of the fluid flow (how far it goes into the formation away from the point of injection) may be calculated, in part, based on the permeability of the formation.', 'Prediction of whether a seismic event may occur based on a modeled increase in pressure within a formation may include comparing the modeled increase in pressure with previously conducted drilling operations having the same or similar increases in pressure.', 'For example, if a previously conducted physical drilling operation experienced increases in pressure within 10 percent of the modeled increases in pressure, and did not result in any measured seismic events, it may be predicted that the modeled increases in pressure would not result in seismic events, and vice versa.', 'Other factors that may be considered when predicting whether a seismic event may occur based on a modeled increase in pressure within a formation may include the type of formation or formation composition.', 'For example, formation compositions that have been shown in physical drilling operations to have higher likelihoods of seismic activity may be an indication that a modeled formation having the same or similar composition may have a higher likelihood of a seismic event when exposed to increased pressures.', 'In some embodiments, calculated material properties for a modeled formation composition may be used to predict effects of the increased pressure on the formation composition, including strain or movement in the formation, which may indicate a predicted seismic event in the formation.', 'According to some embodiments, prediction of whether a seismic event may occur based on a modeled pressure increase within a formation may be performed using a computer software program.', 'For example, due to the complexity of the hydraulic fracture geometry and its interaction with the natural fractures, computer software programs using unstructured grids to explicitly model and simulate hydraulic fracture networks fluid flow may be used for increased accuracy and performance to predict effects from an increase in pressure within the modeled formation.', 'Computer software programs that may be useful for such purposes may include but are not limited to INTERSECT™ or ECLIPSE™ software by Schlumberger, VIP™ or Nexus™ software by Halliburton, IME™ by CMG, or Tempest MORE™ by Emerson.', 'Further evaluation of rock failure from a simulated stimulation in a formation may be conducted using 3D static or 4D flow-, pressure-, and temperature-coupled calculations for rock stresses, deformations, and failure using simulation software, such as VISAGE by Schlumberger or Abaqus™ by SIMULIA/Baker Hughes.', 'According to embodiments of the present disclosure, further evaluation of rock failure from a simulated stimulation in a formation to determine generation of micro-seismic events may include generating a stress profile of the formation based on a modeled increase in pressure.', 'As used herein, a stress profile may refer to a map of stress magnitudes over an area of the formation.', 'Coupling 3D reservoir geomechanics (e.g., a mechanical earth model) and hydraulic fracturing modeling may allow for a more accurate stress profile generation, reflecting the structure, heterogeneity/anisotropy, pressure, and temperature effects from well to reservoir scale.', 'Coupling 3D reservoir geomechanics and hydraulic fracturing modeling may also enable tracking fracture complexity, including the effect of real 3D state of stress, and may define the right conditions prior to and during early stimulation and during medium/long term production.', 'According to one or more embodiments, a stress profile may be mapped on a combined fracture growth and mechanical earth model of a formation based on calculated pressure changes in the formation as a result of a stimulation.', 'A stress field may then be defined on the stress profile, where the stress field may identify a selected stress criterion.', 'For example, a stress field may be defined on a stress profile delineating a distance through the formation subjected to a minimum amount of stress increase from the stimulation.', 'In one or more embodiments, a stress field may be defined on a stress profile delineating a distance through the formation subjected to a minimum amount of stress from the increase in pressure.', 'In some embodiments, calculated change in pore pressure may be used to predict if a seismic event will occur from the stimulation, while a calculated stress profile may be used to predict the magnitude of the seismic event.', 'For example, a preselected value for a change in pore pressure in a formation from stimulation may be selected based on, for example, detected seismic events resulting from physically performed and/or simulated stimulations having similar designs and pore pressure change.', 'If a change in calculated pore pressure from a simulated stimulation is greater than the preselected value, a seismic event may be predicted.', 'The stress profile may then be calculated for the simulated stimulation, which may be used to predict the magnitude of the predicted seismic event, for example, by determining if a stress field extends through a geological feature and/or by further calculating strain or movement in the formation resulting from the increase in stress.', 'Based on the resulting stress profile, rock failure analysis may be performed on a formation model to analyze failure of rock in the formation resulting from the changes in stress and determine movement in the formation due to rock failure.', 'Rock failure analysis may include identifying critically stressed regions within a stress profile (e.g., by defining a stress field on the stress profile as areas experiencing a minimum amount of stress), predicting fracture intensity, inspecting zones close to shear or tensile mobilization, and/or determining strain, slip and other deformation in the rock.', 'In some embodiments, failure planes, such as from shear and/or tensile mobilization, may be generated in a mechanical earth model of a formation.', 'Rock failure analysis and modeling of rock failure may be performed using rock failure analysis software.', 'For example, rock failure analysis software, such as Mechanical Fracture Intensity Predictor by Schlumberger or RocPlane, may be used to identify critically stressed regions in formation from a hydraulic fracturing operation, generate failure planes in a mechanical earth model of the formation, and predict fracture intensity based on well log data accessible to the software.', 'Using a stress profile of a formation based on the increase in pressure from a stimulation, tensile and shear mobilization in the formation may be calculated.', "For instance, assuming that the formation obeys an isotropic elastic behavior, before pumped fluid penetrates the formation, the tensile strength of the rock T\no \ncan be derived from Kirsch's solution, which reads: T\no\n=P\nw\n+σ\nH\n−3 σ\nh\n+P\np\n, where P\nw \nis the wellbore pressure at fracture initiation, P\np \nis the formation pressure (i.e. pore pressure) and σ\nH \nand σ\nh \nthe maximum and minimum total horizontal stress, respectively.", 'Similarly, when wellbore pressure P\nw \nchanges, shear failure is triggered when: P\nw\n=P\np\n+(3σ\nH\n−σ\nh\n−2P\np\n−UCS)/(1+N), where UCS is the unconfined compression strength of the rock, N=(1+sin Φ)/(1−sin Φ) is the friction coefficient and Φ is the rock internal friction angle.', 'Micro-seismic activity in a formation may be generated by geomechanical strain or slip or other deformation in the formation.', 'Strain or movement in the formation may be calculated using the stress profile (the stress the formation is under from the stimulation, continuously mapped throughout the formation area being simulated) and estimated rock mechanical properties.', 'The rock mechanical properties do not change from a stimulation, and thus, the rock mechanical properties estimated prior to simulation of the stimulation (e.g., collected to generate the mechanical earth model) may be used for calculating strain.', 'By calculating deformation type and magnitude of rock in a formation, micro-seismic activity may be predicted, including the magnitude of the micro-seismic activity.', 'Further, micro-seismic activity in the formation from the calculated tensile and shear mobilization may be predicted and mapped onto a combined fracture growth and mechanical earth model.', 'According to embodiments of the present disclosure, micro-seismic events resulting from a failure of rock in a formation may be described by seismic moment tensors.', 'For example, stresses and deformation induced in a formation by a stimulation of an injection of fluid into the formation may be used and applied in a similar way to micro-seismic data in order to derive a moment tensor enabling visualization of micro-seismic events.', 'Seismic moment tensors include symbols (e.g., spherical or “beach ball” symbols) that may be used to represent the type of failure that occurred, such as shearing or tearing failures, opening or closing fractures (changes in volume) or a combination of failures.', 'For example, seismic moment tensors may be decomposed into independent parameters, including three geometric parameters representing the orientation of the fracture and slip, a total seismic moment parameter representing the strength of the event, and parameters representing the relative strengths of double-couple (produced from slip on a planar fault surface), compensated linear vector dipole (produced from outward motion in a single plane due to normal shortening) and isotropic components (produced from explosive or implosive mechanism).', 'According to embodiments of the present disclosure, seismic moment tensors may provide a way to represent strain at a source of a micro-seismic event resulting from a determined stress profile in the formation, as discussed above.', 'Determination of micro-seismic activity in a formation resulting from stimulation (injection of a volume of fluid into the formation) may be used to predict seismic activity (on a macro scale) of the formation.', 'Surface or downhole micro-seismic information acquired from a physical stimulation operation may be used to calibrate a previously generated model of the stimulation operation.', 'Calibrating the model may include matching the predicted micro-seismicity to the measured micro-seismicity from the physical stimulation.', 'For example, micro-seismic data from sensor arrays in a formation may be collected, complex sets of recorded acoustic waveforms may be analyzed, and the spatial and temporal evolution of fracture networks in 4D, relative to the location of the fracturing treatment, may be monitored and analyzed using visualization and interpretation techniques to provide measured micro-seismicity data from a physical stimulation.', 'Measured micro-seismicity data may be updated in real time.', 'Upon predicting seismic events from a stimulation design in a formation, one or more parameters of the stimulation design may be altered to mitigate risk of the seismic event.', 'For example, a recommendation for mitigating the risk of generating induced seismicity, may include but is not limited to, altering drilling direction, fracture initiation point locations, fracture fluid volume, fracturing fluid type, and maximum proppant concentration.', 'According to embodiments of the present disclosure, methods may be used for evaluating the potential of generating induced seismicity caused by fluid injection operations conducted in multiple stages.', 'For example, according to some embodiments of the present disclosure, a method for evaluating the potential of generating induced seismicity may include obtaining a mechanical earth model of a formation and modeling a hydraulic fracture growth pattern in the formation from a stimulation of the formation, where the stimulation may be performed in a plurality of stages along a borehole extending through the formation.', 'Performing a stimulation in multiple stages may include perforating and injecting a volume of fluid into sections of the borehole, where fluid is injected into a single section before injection of fluid into another section.', 'Mechanical plugs or other isolating or diverting techniques may be used to seal off sections of a borehole (each section extending a distance along the borehole).', 'For example, a first section of a wellbore may be perforated, and after a volume of fluid is injected into the perforated first section, the first section may be sealed off with a mechanical plug.', 'After the first section is sealed, a second section may be perforated and stimulated with an injection of fluid.', 'The second section may then be sealed with a second mechanical plug, and one or more subsequent sections may be perforated, stimulated and sealed.', 'Once each stage (or section) is completed, the mechanical plugs may be removed to allow hydrocarbons or other retrievables to flow from the formation to the surface through the wellbore.', 'An increase in pressure in the formation resulting from the stimulation may be determined, for example, based on the volume of fluid being injected into the formation.', 'A stress profile may be generated for each of the stages over which the stimulation is completed, where each stress profile includes a map of stress values over an area of the formation.', 'For example, a stimulation design may include injecting a volume of fluid into the formation in multiple stages, where a first volume of fluid is injected into a first section along a wellbore, and subsequent volumes of fluid are injected into subsequent sections along the wellbore.', 'Different or equal volumes of fluid may be injected into different sections along the wellbore.', 'After obtaining a mechanical earth model of a formation and modeling a hydraulic fracture growth pattern in the formation from a stimulation of the formation performed in multiple stages, at least one of the stages of the stimulation may be physically performed.', 'According to embodiments of the present disclosure, at least one stage of a multistage stimulation may be physically performed after simulation of one stage in the multistage stimulation, after simulation of more than one stage but less than all stages of the stimulation, or after simulation of each stage in the multistage stimulation.', 'Stress within the area of the formation around a physically completed stage (perforated and injected with a volume of fluid) of the stimulation may be measured to generate a measured stress profile of the physically completed stage.', 'The area of formation around a physically completed stage of the stimulation experiencing an increase in stress from the stimulation stage may vary, for example, depending on the volume of fractures generated from perforating and the volume of fluid injected.', 'Each stage of the simulation that is physically completed in the multistage stimulation may be calibrated prior to physically performing a subsequent stage of the stimulation.', 'Calibrating may include updating one or more input parameters of the combined fracture growth and mechanical earth model to match the modeled stress profile of the physically completed stage with the measured stress profile of the physically completed stage.', 'Calibrating stages in a multistage stimulation as they are completed with a simulation of the multistage stimulation may allow for correction in the simulation model and provide greater accuracy in predicting micro-seismic events resulting from the multistage stimulation.', 'For example, if a physically completed stage of a multistage stimulation results in higher than expected stress or micro-seismic activity than predicted, one or more subsequent stages of the multistage stimulation may be adjusted to reduce stress or micro-seismic activity from the subsequent stages.', 'In some embodiments, a rock failure analysis may be performed on the formation based on the stress profile for at least one stage in a multistage stimulation to predict micro-seismic activity.', 'As discussed above, rock failure analysis may include analysis of rock failure (e.g., type of failure) and movement of rock in the formation resulting from the changes in stress from the stimulation.', 'Rock failure analysis may include identifying critically stressed regions within a stress profile (e.g., by defining a stress field on the stress profile as areas experiencing a minimum amount of stress), predicting fracture intensity, inspecting zones close to shear or tensile mobilization, and/or determining strain, slip and other deformation in the rock.', 'In some embodiments, failure planes, such as from shear and/or tensile mobilization, may be generated in a mechanical earth model of a formation.', 'Rock failure analysis and modeling of rock failure may be performed using rock failure analysis software.', 'After conducting a rock failure analysis for a stage of a multistage stimulation, the stage may be physically completed, and the micro-seismic activity from the physically completed stage may be measured and compared with the predicted micro-seismic activity of the simulation of the stage.', 'For example, a first stage in a multistage stimulation may be simulated in a combined fracture growth and mechanical earth model, and rock failure analysis may be conducted on the simulated first stage to predict micro-seismic activity resulting from the first stage stimulation.', 'The first stage may then be physically completed in a section of a borehole, and micro-seismic activity from the physically completed first stage may be measured.', 'The simulation of the multistage stimulation may be calibrated using the physically completed first stage by updating one or more input parameters of the multistage stimulation model to match the predicted micro-seismic activity of the first stage with the measured micro-seismic activity of the first stage.', 'One or more subsequent simulated stages of the multistage stimulation may then be physically performed and used to further calibrate the multistage stimulation simulation.', 'In some embodiments of simulating a multistage stimulation, rates of stress propagation may be calculated for each simulated stage of the stimulation based on the increase in pressure from injecting a volume of fluid into each stage of the stimulation.', 'For example, a first rate of stress propagation may be calculated in a first stage of a multistage stimulation based on the increase in pressure in the simulated first stage of the stimulation resulting from injection of a first volume of fluid into the section of the borehole defined by the first stage.', 'The simulated increase in pressure in the simulated first stage may be predicted based on the first volume of fluid, where the increase in pressure is proportional to the first volume of fluid.', 'Rates of stress propagation in subsequent stages of the multistage stimulation may be calculated and compared with the rate of stress propagation calculated in the other simulated stages.', 'Depending on the rate of stress propagation calculated in one or more stages of a multistage stimulation, parameters of the stimulation may be altered, for example, the volume of fluid injected into one or more stages, the volume of fractures generated in one or more stages, and the size of one or more stages (the distance the defined section of the stage extends along the borehole).', 'A stress profile may be determined for one or more stages of a multistage stimulation and mapped on a combined fracture growth and mechanical earth model of the multistage stimulation.', 'A stress field may then be defined on the stress profile for one or more of the simulated stages.', 'The stress field may delineate a distance through the formation subjected to a minimum amount of stress from the increase in pressure.', 'In some embodiments, the stress field may delineate a distance through the formation subjected to a minimum amount of change in stress resulting from an injection of fluid during one or more stages of the multistage stimulation.', 'The extent of a stress field may depend on, for example, the reservoir pressure and mechanical properties of the rock.', 'Based on the extent of a stress field, a seismic event may be predicted.', 'For example, if a stress field is calculated to extend a distance into the formation that hits one or more geological features, such as a fault in the formation, a seismic event may be predicted.', 'For example, \nFIG.', '2\n shows a diagram of a method for predicting whether a seismic event may occur in a multistage stimulation.', 'As shown, a borehole \n200\n may extend through a formation \n210\n of interest.', 'A multistage stimulation may be designed along a horizontally extending section of a borehole, as shown, or along a section of a borehole extending a different direction, e.g., extending at an angle from the surface of the formation.', 'The multistage stimulation design may include multiple stages \n220\n, \n222\n that are sectioned off, for example, using plugs \n230\n, and selected perforation locations in each stage.', 'A simulation of the multistage stimulation may include simulating perforating a first stage \n220\n at the selected perforation locations and injecting a first volume of fluid into the section of the borehole in the first stage \n220\n, resulting in a fracture growth pattern \n240\n.', 'The simulation of the multistage stimulation may be modeled in a combined fracture growth and mechanical earth model, as described above.', 'The pressure change in the formation resulting from the injection of the first volume of fluid may be modeled in the combined fracture growth and mechanical earth model.', 'The first volume of fluid is the volume used for calculating the pressure increase in the formation from the first stage.', 'From the calculated increase in pressure (as well as modeled fracture pattern and geomechanics of the formation), a stress profile may be modeled.', 'One or more stress fields may then be defined on the stress profile.', 'As shown in \nFIG.', '2\n, stress fields \n250\n, \n252\n, \n254\n may define different areas of the formation subjected to different ranges of increase in stress from the first stage of the stimulation.', 'For example, stress field \n250\n may be drawn to delineate an area of the formation subjected to a first amount of increase in stress from the first stage stimulation.', 'Stress field \n252\n may be drawn to delineate an area of the formation subjected to at least a second amount of stress increase, but less than the first amount of stress increase, from the first stage stimulation.', 'Stress field \n254\n may be drawn to delineate an area of the formation subjected to at least a third amount of stress increase, but less than the second amount of stress increase, from the first stage stimulation.', 'If a stress field subjected to a selected minimum value of stress or stress increase extends into a geological feature, such as the fault \n260\n shown in \nFIG.', '2\n, it may be predicted that a seismic event may occur in the formation, depending on, for example, the nature and size of the geological feature and the minimum value of stress or stress increase selected to define the stress field.', 'If a seismic event is predicted, a recommendation for mitigating the risk of generating induced seismicity may be provided, including, for example, altering the drilling direction of the borehole, altering fracture initiation point locations (perforation locations), altering fracturing fluid volume (the amount of fluid being injected into one or more stages), altering fracturing fluid type, and/or altering the maximum proppant concentration in the fluid being injected.', 'In some embodiments, when a seismic event is predicted from a first stage of a multistage, one or more parameters of a subsequent stage of the multistage stimulation may be altered, for example, altering the perforation locations of the subsequent stage and/or altering the volume of fluid injected into the subsequent stage.', 'An altered stimulation design (e.g., one or more parameters altered as a response to a predicted seismic event in a first simulation of a stimulation) may be simulated according to methods disclosed herein in a subsequent simulation.', 'In some embodiments, a seismic event may be predicted when a stress field delineating an area of a formation subjected to a selected minimum value of stress or stress increase resulting from an injection of fluid extends into an active fault.', 'An active fault may be determined by monitoring the formation of interest for a duration of time to determine if and which portions of the formation are moving relative to other portions of the formation.', 'For example, a plurality of seismic measuring devices, such as seismometers, may be disposed at different locations along a formation of interest.', 'The seismic measuring devices may measure motion of the ground, include micro-seismic events, over a period of time to determine if the formation of interest has an active fault.', 'A multistage stimulation may be calibrated in real time.', 'For example, referring again to \nFIG.', '2\n, the first stage \n220\n may be calibrated prior to physically conducting the second stage \n222\n.', 'In such embodiments, a simulation of the multistage stimulation may be generated, including a simulation of the first stage \n220\n and the second stage \n222\n.', 'One or more predictions resulting from the multistage stimulation may be made for the first and second stages \n220\n, \n222\n, including, for example, a prediction of an increase in pressure, a prediction of one or more stress fields, and/or a prediction of micro-seismic activity.', 'After simulation of the multistage stimulation, the first stage \n220\n of the multistage stimulation may be physically completed.', 'Measurements of one or more parameters (e.g., stress, pressure, micro-seismic activity) may be taken from the physically completed first stage \n220\n and compared to the predicted parameters of the simulated first stage \n220\n in order to determine accuracy of the simulation model.', 'In some embodiments, when differences between predicted parameters and measured parameters are determined from the first stage, the first stage of the simulation may be calibrated by matching the predicted parameters to the measured parameters.', 'After calibrating the first stage \n220\n, the simulation of the multistage stimulation may be repeated to determine one or more predictions in the second stage \n222\n.', 'Based on changes in predictions from the calibrated simulation of the multistage stimulation, one or more stimulation parameters (e.g., perforation locations and/or volume of fluid injected) of the second stage \n222\n may be altered to mitigate risk of induced seismic activity.', 'In some embodiments, a first stage of a multistage stimulation may be modeled, and the propagation of pressure increase may be monitored over a period of time.', 'The simulated first stage may be physically conducted over the period of time and calibrated in real time to match predicted parameters with the measured parameters.', 'If predicted and/or measured parameters result in an induced seismic event, one or more stimulation parameters may be altered prior to physically conducting a subsequent stage of the multistage stimulation.', 'For example, upon predicting an induced seismic event from simulation of a first stage in a multistage stimulation and prior to physically conducting the subsequent stage of the multistage stimulation, an amount of fluid being physically injected into the first stage of the stimulation may be flowed back to the surface of the formation to decrease pressure effects from the first stage stimulation.', 'As used throughout this disclosure, “first” may be used to refer to an initial occurrence (prior to all other occurrences of the same type) or may be used to refer to a previous occurrence (prior to one or more occurrences of the same type).', 'For example, a first stage may be the first of all stages in a multistage stimulation or may refer to any stage prior to a subsequent stage.', 'Systems that may be used for evaluating the potential of generating induced seismicity according to embodiments of the present disclosure may include a computer processor and memory with instructions executing on the computer processor with functionality to model a stimulation of a formation, as described herein.', 'For example, the memory may include instructions for receiving parameters of the formation.', 'Parameters of the formation that may be received and processed may include, for example, wellbore data collected from logging or other data collecting operations, such as rock material properties, porosity, density, conductivity, and other formation data types described above.', 'The instructions may further generate a mechanical earth model of the formation based on the received parameters of the formation.', 'The instructions further have functionality to perform a simulation of a stimulation of the formation using generated the mechanical earth model to provide a combined fracture growth and mechanical earth model.', 'The combined fracture growth and mechanical earth model includes a model of a hydraulic fracture growth pattern in the modeled formation resulting from the simulated stimulation of the formation.', 'The combined fracture growth and mechanical earth model and/or predictions of resulting changes in pressure and/or stress in the formation from the stimulation may be presented on a graphical user interface.', 'FIG.', '3\n depicts a computing system with which one or more embodiments of the present disclosure may be implemented.', 'In one or more embodiments, one or more of the modules and elements shown in \nFIG. \n3\n may be omitted, repeated, and/or substituted.', 'Accordingly, embodiments of the present disclosure should not be considered limited to the specific arrangements of modules shown in \nFIG.', '3\n.', 'As shown in \nFIG.', '3\n, a computing system \n1100\n includes a computing device \n1102\n having one or more computing processors \n1106\n, one or more storage devices \n1108\n (e.g., a hard disk, an optical drive such as a compact disk (CD) drive or digital versatile disk (DVD) drive, a flash memory stick, etc.), memory \n1110\n (e.g., random access memory (RAM), cache memory, flash memory, etc.), and a graphical user interface (GUI) \n1112\n.', 'The computing processor(s) \n1106\n may be an integrated circuit for processing instructions.', 'For example, the computing processor(s) may be one or more cores, or micro-cores of a processor.', 'The storage device(s) \n1108\n (and/or any information stored therein) may be a data store such as a database, a file system, one or more data structures (e.g., arrays, link lists, tables, hierarchical data structures, etc.) configured in a memory, an extensible markup language (XML) file, any other suitable medium for storing data, or any suitable combination thereof.', 'The storage device(s) \n1108\n may be a device internal to the computing device \n1102\n, or the storage device(s) \n1108\n may be an external storage device operatively connected to the computing device \n1102\n.', 'According to some embodiments, the storage device(s) \n1108\n may include a data repository having stored parameters from real/physical drilling systems and/or stored parameters from previously performed simulations, where at least one of the stored parameters may be submitted parameters for simulation of a drilling system.', 'Additionally, the computing device \n1102\n may include numerous other elements and functionalities.', 'The computing device \n1102\n may be communicatively coupled to a network \n1104\n (e.g., a local area network (LAN), a wide area network (WAN) such as the Internet, mobile network, or any other type of network) through wires, cables, fibers, optical connectors, a wireless connection, or a network interface connection (not shown).', 'The computing system \n1100\n may also include one or more input device(s) \n1114\n, such as a touchscreen, keyboard, mouse, microphone, touchpad, electronic pen, or any other type of input device.', 'Further, the computing system \n1100\n may include one or more output device(s) \n1116\n, such as a screen (e.g., a liquid crystal display (LCD), a plasma display, touchscreen, cathode ray tube (CRT) monitor, projector, 2D display, 3D display, or other display device), a printer, external storage, or any other output device.', 'One or more of the output device(s) \n1116\n may be the same or different from the input device(s).', 'The input and output device(s) may be locally or remotely (e.g., via the network \n1104\n) connected to the computer processor(s) (\n1106\n), memory (\n1110\n), storage device(s) (\n1108\n), and GUI \n1112\n.', 'Many different types of computing systems exist, and the aforementioned input and output device(s) may take other forms.', 'Further, one or more elements of the computing system \n1100\n may be located at a remote location and connected to the other elements over a network \n1104\n.', 'Further, embodiments of the disclosure may be implemented on a distributed system having nodes, where each portion of the disclosure may be located on a different node within the distributed system.', 'In one embodiment of the disclosure, the node corresponds to a distinct computing device.', 'In another embodiment, the node may correspond to a computer processor with associated physical memory.', 'In another embodiment, the node may correspond to a computer processor or micro-core of a computer processor with shared memory and/or resources.', 'The GUI \n1112\n may be operated by a user (e.g., an engineer, a designer, an operator, an employee, or any other party) using one or more input devices \n1114\n and the GUI \n1112\n may be visualized one or more output devices \n1116\n coupled to the computing device \n1102\n.', 'The GUI may include one or more buttons (e.g., radio buttons), data fields (e.g., input fields), banners, menus (e.g., user input menus), boxes (e.g., input or output text boxes), tables (e.g., data summary tables), sections (e.g., informational sections or sections capable of minimizing/maximizing), screens (e.g., welcome screen or home screen), and/or user selection menus (e.g., drop down menus).', 'In addition, the GUI may include one or more separate interfaces and may be usable in a web browser or as a standalone application.', 'Although the output device(s) \n1116\n is shown as being communicatively coupled to the computing device \n1102\n, the output device(s) \n1116\n may also be a component of the computing device \n1102\n.', 'The computing device \n1102\n may execute instructions on the computing processor(s) \n1106\n to perform a simulation based on the formation and stimulation parameters selected or submitted by the user.', 'Executing the simulation generates a set of predicted parameters (e.g., combined natural and hydraulic fracture pattern through the formation, pressure increase through the formation from the stimulation, stress profiles through the formation, and micro-seismic activity, as discussed above).', 'After simulation, one or more predicted parameters may be visualized by the GUI \n1112\n on the output device(s) \n1116\n.', 'In one embodiment, the visual outputs may include a combined fracture growth and mechanical earth model of the stimulated formation.', 'Additionally, the outputs may be in the form of tabular data of one or more predicted parameters and/or graphs and may be represented as percentages or ratios.', 'Once presented with the predicted parameters, the user may modify one or more of the input parameters to reduce potential of generating induced seismicity from a stimulation.', 'Modification may involve selecting a parameter from pre-existing values or inputting the parameter to obtain a modified value.', 'For example, a different volume of fluid injected into the formation may be inputted in the simulation of a stimulation.', 'According to some embodiments, at least one of the parameters submitted into a computer processor for designing a stimulation of a formation may be modified based on one or more predicted parameters from a previous stimulation simulation performed by the computer processor, wherein modifying includes changing a value of at least one input parameter to obtain a modified input parameter.', 'A second predicted parameter from a subsequent simulation may be presented on a graphical user interface, where the subsequent simulation is based on the modified input parameter.', 'The predicted parameters from each simulation may be compared to determine optimized input parameters.', 'In one or more embodiments, an input parameter may be modified using an optimizer \n1118\n.', 'The optimizer \n1118\n may be connected to the computing device \n1102\n, or may be integral with the computing device \n1102\n.', 'The optimizer \n1118\n may also be connected to the computing device \n1102\n or accessibly by the computing device \n1102\n using network \n1104\n.', 'The optimizer \n1118\n may modify one or more input parameters during a simulation.', 'For example, a simulation of a multistage stimulation in a formation may be performed and the optimizer \n1118\n may modify one or more input parameters (e.g., input parameters for subsequent stages in the multistage stimulation) during simulation.', 'After modification, and while the simulation is being performed, the simulation may continue based on the one or more input parameters modified by the optimizer \n1118\n.', 'Further, a user may specify particular constraints with respect to one or more input parameters during simulation.', 'When modifying, the optimizer \n1118\n may consider the constraints imposed by the user and may modify one or more input parameters based on the constraints.', 'For example, a user may specify a range for the volume of fluid to be injected in the formation for stimulation.', 'Once specified, a simulation may be performed and the optimizer \n1118\n may modify one or more input parameters such that the modification falls within the constraints specified by the user.', 'Further, the optimizer \n1118\n may modify one or more input parameters such that a particular performance is achieved during simulation.', 'For example, a user may specify an area that a stress field may extend through the formation (the stress field defined as the area of the formation subjected to a minimum amount of stress or stress increase due to the stimulation).', 'The user may specify the area, for example, to avoid extending into one or more known geological features that may induce seismicity if subjected to the increase in stress.', 'Once specified, a simulation may be performed and the optimizer \n1118\n may modify one or more input parameters until the performance is achieved.', 'In some embodiments, the drilling direction or orientation of a borehole through which the stimulation is to be conducted may be altered such that the area of a stress field does not extend into one or more geological features (e.g., active or non-active faults).', 'In some embodiments, the location of stimulation along a borehole may be altered such that the area of a stress field does not extend into one or more geological features (e.g., active or non-active faults).', 'After modification, a second simulation may be executed by the computing device \n1102\n.', 'The second simulation may include the modified input parameter.', 'The second simulation may be executed by the computing device \n1102\n using the processor(s) \n1106\n to generate a second set of predicted parameters.', 'The second simulation may be performed using one or more of the methods set forth above.', 'Once generated, the initial set of predicted parameters along with the second set of predicted parameters may be presented using GUI \n1112\n and output device(s) \n1116\n.', 'The sets of predicted parameters may be presented to the user for comparison and may be presented separately or combined.', 'The sets of predicted parameters may be presented or visualized, for example, using models, plots, graphs, charts, and logs.', 'Additionally, a second simulation may occur simultaneously with the first simulation.', 'For example, an engineer may select any number of input parameters of a stimulation of a formation to operate in particular operating conditions.', 'The engineer may then run a number of simulations and compare resulting outputs (e.g., predicted parameters) to one another.', 'Furthermore, the simulation and thus, the comparison, may be done in real-time.', 'More specifically, the engineer may run a number of simulations for a given stimulation scenario and observe performance as the simulation progresses.', 'Furthermore, the predicted parameters may be acquired and/or measured in the field.', 'The results from one or more simulations may then be used to compare to one or more field acquired/measured parameters.', 'Referring now to \nFIG.', '4\n, an example of a system \n400\n according to embodiments of the present disclosure is shown.', 'The system \n400\n may include a computing system \n410\n having a computer processor and memory with instructions executing on the computer processor with functionality to receive parameters from a formation \n420\n.', 'The memory may run on the computer processor instructions for modeling a mechanical earth model based on the received parameters of the formation, such as by using one or more computer programs for generating a mechanical earth model.', 'The memory may also run on the computer processor instructions for simulating a stimulation of the formation, where the stimulation includes injecting a volume of fluid into the formation.', 'The memory may include instructions, such a computer program described herein, with functionality to model a hydraulic fracture growth pattern from the stimulation of the formation in a combined fracture growth and mechanical earth model.', 'Upon simulating a stimulation of a formation and providing a combined fracture growth and mechanical earth model, a stress profile of the formation may be presented on a graphical user interface, where the stress profile shows changes in stress through the formation resulting from a change in pressure through the formation (from injection of the volume of fluid during the stimulation).', 'The stress profile may be generated in the combined fracture growth and mechanical earth model from the mechanical earth model and the hydraulic fracture growth pattern model simulated by the computing system \n410\n.', 'In some embodiments, the computing system may further perform rock analysis from the combined fracture growth and mechanical earth model and the generated stress profile to predict rock failure, which may cause seismic activity.', 'Based on the generated stress profile and/or based on the rock analysis, the potential of generating induced seismicity may be predicted.', 'In some embodiments, a system may include one or more sensors or measuring devices measuring at least one of the parameters of the formation, where the sensors or measuring devices may be in wireless or wired communication with the computer processor.', 'For example, as shown in \nFIG.', '4\n, measurement devices \n425\n may be used to measure material properties of the formation, such as through logging operations down a borehole \n422\n extending through the formation \n420\n.', 'For example, a sonic logging tool may be sent down a borehole \n422\n (e.g., a current well being drilled, an offset well, or an exploration borehole) to measure orientation of natural fractures, porosity, density, and other formation properties.', 'In some embodiments, measurement devices \n425\n may be used on the surface of the formation \n420\n to measure one or more parameters of the formation.', 'For example, seismometers may be disposed at one or more locations on the surface of the formation to monitor micro-seismic activity in the formation, which may be used to determine if there are any active faults \n424\n within the formation.', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this disclosure.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.']

['1.', 'A method, comprising:\nmeasuring, for a time period, micro-seismic events from a formation to determine if the formation has an active or non-active fault;\nobtaining a mechanical earth model of a formation;\nmodeling, using the mechanical earth model, a hydraulic fracture growth pattern in the formation from a stimulation of the formation thereby generating a combined fracture growth and mechanical earth model, wherein the stimulation comprising an injection of a volume of fluid into the formation;\ndetermining a first increase in pressure in the formation resulting from the stimulation based on the combined fracture growth and mechanical earth model;\nreceiving data indicating a second increase in pressure in the formation associated with a previously conducted drilling operation;\ncomparing the first and second increases in pressures to determine if the first and second increases in pressure are within a pressure threshold relative to one another;\npredicting whether a seismic event will occur in the formation when the first and second increases in pressure are within the pressure threshold, wherein predicting comprises: predicting that the seismic event will occur in the formation when the second increase in pressure resulted in a previous seismic event; predicting that the seismic event will not occur when the second increase in pressure did not result in a previous seismic event; and\naltering at least one parameter of the stimulation to mitigate risk of the seismic event if the seismic event is predicted.', '2.', 'The method of claim 1, further comprising generating a stress profile of the formation based on the first increase in pressure, the stress profile comprising a map of stress magnitudes over an area of the formation.', '3.', 'The method of claim 2, wherein a stress field is defined on the stress profile, the stress field delineating a distance through the formation subjected to a minimum amount of stress from the increase in pressure.', '4.', 'The method of claim 2, further comprising calculating tensile and shear mobilization in the formation based on the stress profile.', '5.', 'The method of claim 4, further comprising modeling micro-seismic activity in the formation from the calculated tensile and shear mobilization.', '6.', 'The method of claim 1, further comprising, prior to obtaining the mechanical earth model, characterizing a plurality of properties of the formation, wherein characterizing comprises obtaining wellsite data from at least one of core data, borehole imaging data, outcrop analogues, and seismic data.', '7.', 'The method of claim 1, wherein the first increase in pressure is calculated based on the volume of fluid injected into the formation.', '8.', 'The method of claim 1, further comprising calibrating the mechanical earth model to match measured micro-seismicity from the stimulation.', '9.', 'The method of claim 1, further comprising physically performing the stimulation.', '10.', 'A method, comprising:\nobtaining a mechanical earth model of a formation;\nmodeling, using the mechanical earth model, a hydraulic fracture growth pattern in the formation from a stimulation of the formation thereby generating a combined fracture growth and mechanical earth model, wherein, the stimulation is performed in a plurality of stages along a borehole extending through the formation;\ndetermining an increase in pressure in the formation resulting from the stimulation based on the combined fracture growth and mechanical earth model;\ncomparing the increase in pressure in the formation and an additional increase in pressure in the formation resulting from a previous stimulation in the formation;\ngenerating a stress profile for each of the plurality of stages based on the comparison of the increase in pressure in the formation, the additional increase in pressure in the formation, and an increase in pressure for a previous stage of the plurality of stages, each stress profile comprising a map of stress over an area of the formation;\nphysically performing at least one of the stages of the stimulation;\nphysically measuring stress within the area of the formation around a physically completed stage of the stimulation to generate a measured stress profile of the physically completed stage; and\ncalibrating the completed stage of the stimulation prior to physically performing a subsequent stage of the stimulation, the calibrating comprising updating one or more input parameters of the model to match the modeled stress profile of the completed stage with the measured stress profile of the completed stage, wherein updating the one or more input parameters mitigates risk of induced seismic activity in the subsequent state of the simulation.', '11.', 'The method of claim 10, further comprising calculating a first rate of stress propagation in a first stage of the stimulation based on the increase in pressure.', '12.', 'The method of claim 10, further comprising performing a first rock failure analysis on the formation based on the stress profile for at least one of the plurality of stages of the stimulation to predict micro-seismic activity.', '13.', 'The method of claim 12, further comprising measuring micro-seismic activity from the completed stage, and wherein the calibrating further comprises updating the one or more input parameters of the model to match the predicted micro-seismic activity with the measured micro-seismic activity.', '14.', 'The method of claim 10, further comprising defining a stress field on the stress profile, the stress field delineating a distance through the formation subjected to a minimum amount of stress from the increase in pressure.', '15.', 'The method of claim 14, further comprising predicting whether a seismic event will occur in the formation based on whether the stress field extends into a geological feature.', '16.', 'The method of claim 10, wherein updating comprises providing a recommendation for mitigating the risk of generating induced seismicity, the recommendation comprising altering at least one of a drilling direction, fracture initiation point locations, fracturing fluid volume, fracturing fluid type, and maximum proppant concentration.', '17.', 'The method of claim 1, wherein altering comprises altering in real time.', '18.', 'The method of claim 10, wherein calibrating comprises calibrating in real time.']

['FIG.', '1 depicts an example of a formation having geological features therein.; FIG.', '2 shows a diagram of a multistage stimulation of a formation according to methods of the present disclosure.', '; FIG.', '3 depicts a system with which one or more embodiments of the present disclosure may be implemented.', '; FIG.', '4 shows a system according to embodiments of the present disclosure.', '; FIG.', '1 shows an example of a formation 100 having fault lines 102 extending below the surface of the formation 100.', 'A volume of interest of the formation 100 is shown in FIG.', '1, which may vary depending on, for example, the seismic survey coverage or how engineers define their models (e.g., by the entire reservoir or part of a reservoir).', 'For example, a volume of interest may include part of a reservoir or an entire reservoir, which may range, for example, from several cubic kilometers or more.', 'The fault lines 102 through the volume of interest may be used to define fault blocks.', 'The technique of designating fault lines through a volume of interest in a formation is referred to as fault splitting, where the faults separate the volume of interest into fault blocks.', 'The fault blocks may or may not contain one or more wellbores.', 'For example, as shown in FIG. 1, a wellbore 104 extends through a fault block in the formation 100 between two fault lines 102.', 'A structural framework model of the volume of interest may be generated by partitioning the fault blocks into a set of blocks units (e.g., by partitioning the fault blocks with horizon lines) and organizing geological data (obtained through data acquisition from above or below the surface of the formation, such as described above) into several sub-regions of the formation 100.', 'For example, surface and sub-surface data points lying inside a fault block may be isolated and extrapolated past the boundaries of the block unit under investigation, and material properties may be assigned to each of the subregions.', '; FIG.', '3 depicts a computing system with which one or more embodiments of the present disclosure may be implemented.', 'In one or more embodiments, one or more of the modules and elements shown in FIG.', '3 may be omitted, repeated, and/or substituted.', 'Accordingly, embodiments of the present disclosure should not be considered limited to the specific arrangements of modules shown in FIG.', '3.']

US11922522

Oilfield data loading services request handling and completion system

Sep 2, 2020

Vishvesh Paranjape, Vishakha Vijay Bhoite, Jeremy Campbell, Sayani Kumar

SCHLUMBERGER TECHNOLOGY CORPORATION

NPL References not found.

6389426; May 14, 2002; Turnbull; 7669133; February 23, 2010; Chikirivao; 8818833; August 26, 2014; Druyan; 20080208475; August 28, 2008; Karr; 20120005333; January 5, 2012; Beattie, Jr.; 20140229698; August 14, 2014; Sivasubramanian; 20150347542; December 3, 2015; Sullivan; 20190265375; August 29, 2019; Aqrawi; 20200265375; August 20, 2020; Azad; 20200334613; October 22, 2020; Palazzo

Foreign Citations not found.

['A method for tracking, managing, and fulfilling data loading service request includes: receiving a data loading service request for loading oilfield-related data to an application; generating a service ticket based on the request, the service ticket identifying details of the data loading service request; assigning one or more tasks associated with the service ticket to one or more resources; receiving, from the one or more resources, information regarding status of completion of the requested service; and providing one or more updates on the status of the requested server to the user through an oilfield-related user interface.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority to U.S. Provisional Patent Application 62/899,106, which was filed Sep. 11, 2019, and is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nExploration and Production (E&P) software platforms are used to collect, analyze, and/or consume data (e.g., petrotechnical data) in an effort to facilitate a variety of tasks (e.g., locating, planning, drilling, and producing hydrocarbons from a well, etc.).', 'Such E&P platforms may be collaborative, providing an environment in which teams of experts in different locations and/or different disciplines can work together to enhance the likelihood of success of a project.', 'Clients may submit requests for data services, such as locating and locating well logs, seismic data, performing simulations, etc.', 'SUMMARY\n \nIn one example aspect, a method for tracking, managing, and fulfilling data loading service request includes: receiving a data loading service request for loading oilfield-related data to an application; generating a service ticket based on the request, the service ticket identifying details of the data loading service request; assigning one or more tasks associated with the service ticket to one or more resources; receiving, from the one or more resources, information regarding status of completion of the requested service; and providing one or more updates on the status of the requested server to the user through an oilfield-related user interface.', 'In an example aspect, a computing system, includes: one or more processors; and a memory system having one or more non-transitory computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations.', 'The operations include: receiving a data loading service request for loading oilfield-related data to an application; generating a service ticket based on the request, the service ticket identifying details of the data loading service request; assigning one or more tasks associated with the service ticket to one or more resources; receiving, from the one or more resources, information regarding status of completion of the requested service; and providing one or more updates on the status of the requested server to the user through an oilfield-related user interface.', 'In an example aspect, a non-transitory computer-readable medium storing instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations.', 'The operations include receiving a data loading service request for loading oilfield-related data to an application; generating a service ticket based on the request, the service ticket identifying details of the data loading service request; assigning one or more tasks associated with the service ticket to one or more resources; receiving, from the one or more resources, information regarding status of completion of the requested service; and providing one or more updates on the status of the requested server to the user through an oilfield-related user interface.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings.', 'In the figures:\n \nFIG.', '1\n illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.\n \nFIG.', '2\n illustrates an example petrotechnical processing environment according to an embodiment.\n \nFIG.', '3\n illustrates a flowchart of a process for processing a request to access a data loading service, according to an embodiment.\n \nFIG.', '4\n illustrates a flowchart of a process for processing a data loading services request handling, according to an embodiment.\n \nFIG.', '5\nA\n illustrates an example of request form that may be presented to a user within a UI for submitting a data loading services request.\n \nFIG.', '5\nB\n illustrates an example custom form generator for generating a form that may be presented to a user for receiving a data loading service request.\n \nFIG.', '6\n illustrates an example GUI tracking dashboard identifying the progress of workflow for completing a data loading service request.\n \nFIG.', '7\n illustrates a schematic view of a computing system, according to an embodiment.', 'DETAILED DESCRIPTION\n \nExploration and Production (E&P) and/or', 'petrotechnical software platforms may be used to collect, analyze, and/or consume data (e.g., petrotechnical data) in an effort to facilitate a variety of tasks (e.g., locating, planning, drilling, and producing hydrocarbons from a well, etc.).', 'For example, a client may request data to be loaded (e.g., copied, synced, and/or transferred) into a database or other repository for use in an application (e.g., a petrotechnical application).', 'Initiating the request, tracking the progress of the request, and loading the data in accordance with request may involve an extensive level of manual and time-consuming effort, while also being error prone.', 'Further, the sheer volume of available data that may potentially be loaded for use in an application may be difficult to identify for data loading services.', 'For example, existing data loading techniques may involve identifying the physical location of a physical site where data is stored, conducting in-person site visits to submit requests for the data, obtaining the data in physical storage media, and loading the data from the physical storage media to an application.', 'These techniques are not only time consuming, but are also error-prone, as incorrect data may be loaded, and relevant data for an application may be inadvertently omitted.', 'Accordingly, aspects of the present disclosure may include a cloud-based data loading service system to facilitate the initiation of data loading requests, track the progress of the data loading requests, and accurately execute the data loading request.', 'Further, the techniques described herein may be used to facilitate collaboration between team members (e.g., by providing an interface for team members to comment on data loading requests and progress).', 'As one illustrative example, the data loading service system may be used to facilitate requests to load data into a petrotechnical application (e.g., a request to load 2D seismic data, 3D seismic data, well data, etc.).', 'Additionally, or alternatively, the data loading service system may be used to facilitate requests to load any other type of data into any variety of application.', 'Once data has been loaded into the application, the data may be used by the application to perform a task (e.g., a task relating to oil and gas recovery, exploration, well drilling, etc.).', 'In some embodiments, a data loading service provider may host a data loading service application for receiving a data loading service request from a user or client.', 'In some embodiments, the data loading service application may present a form (e.g., a Data Management Services Request Form, also referred to herein as a “request form”).', 'In some embodiments, the request form may include a variety of fields, dropdown menus, radio buttons, checkboxes, etc. to receive the parameters of the data loading service request.', 'In some embodiments, the request form may be customized by the data loading services provider.', 'In some embodiments, the request form may be customized for different users/clients.', 'Additionally, or alternatively, the different request forms may be exported/saved and later be imported and used as a start point when generating a new custom request form for a new user or client.', 'In some embodiments, a workflow for completing a data loading service request may be customized for different clients or different request forms used to submit/receive data loading services requests.', 'That is, different request forms may be linked to different users/clients, and different workflows may be linked to different request forms.', "In this way, each user may be provided with a unique and custom-tailored experience for requesting data based on the user's preferences.", 'In some embodiments, the data loading service provider may also host a variety of additional services in addition to data loading services.', 'In some embodiments, service requests may be submitted and tracked for these additional services.', 'For example, additional types of services may include application workflow support, application user support, workflow support, training services, tailored workflow generation, application management, application packaging, release management, data management, data quality control, data management governance, data provisioning, data ecosystem ingestion services, petrotechnical infrastructure support, database management, and infrastructure optimization.', 'In some embodiments, the service request may identify the type of service requested.', 'Reference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures.', 'In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention.', 'However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details.', 'In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms are only used to distinguish one element from another.', 'For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the present disclosure.', 'The first object or step, and the second object or step, are both, objects or steps, respectively, but they are not to be considered the same object or step.', 'The terminology used in the description herein is for the purpose of describing particular embodiments and is not intended to be limiting.', 'As used in this description and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will also be understood that the term “and/or” as used herein refers to and encompasses any possible combinations of one or more of the associated listed items.', 'It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.', 'Attention is now directed to processing procedures, methods, techniques, and workflows that are in accordance with some embodiments.', 'Some operations in the processing procedures, methods, techniques, and workflows disclosed herein may be combined and/or the order of some operations may be changed.\n \nFIG.', '1\n illustrates an example of a system \n100\n that includes various management components \n110\n to manage various aspects of a geologic environment \n150\n (e.g., an environment that includes a sedimentary basin, a reservoir \n151\n, one or more faults \n153\n-\n1\n, one or more geobodies \n153\n-\n2\n, etc.).', 'For example, the management components \n110\n may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment \n150\n.', 'In turn, further information about the geologic environment \n150\n may become available as feedback \n160\n (e.g., optionally as input to one or more of the management components \n110\n).', 'In the example of \nFIG.', '1\n, the management components \n110\n include a seismic data component \n112\n, an additional information component \n114\n (e.g., well/logging data), a processing component \n116\n, a simulation component \n120\n, an attribute component \n130\n, an analysis/visualization component \n142\n and a workflow component \n144\n.', 'In operation, seismic data and other information provided per the components \n112\n and \n114\n may be input to the simulation component \n120\n.', 'In an example embodiment, the simulation component \n120\n may rely on entities \n122\n.', 'Entities \n122\n may include earth entities or geological objects such as wells, surfaces, bodies, reservoirs, etc.', 'In the system \n100\n, the entities \n122\n can include virtual representations of actual physical entities that are reconstructed for purposes of simulation.', 'The entities \n122\n may include entities based on data acquired via sensing, observation, etc. (e.g., the seismic data \n112\n and other information \n114\n).', 'An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property).', 'Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.', 'In an example embodiment, the simulation component \n120\n may operate in conjunction with a software framework such as an object-based framework.', 'In such a framework, entities may include entities based on pre-defined classes to facilitate modeling and simulation.', 'A commercially available example of an object-based framework is the MICROSOFT® .NET® framework (Redmond, Washington), which provides a set of extensible object classes.', 'In the .NET® framework, an object class encapsulates a module of reusable code and associated data structures.', 'Object classes can be used to instantiate object instances for use in by a program, script, etc.', 'For example, borehole classes may define objects for representing boreholes based on well data.', 'In the example of \nFIG.', '1\n, the simulation component \n120\n may process information to conform to one or more attributes specified by the attribute component \n130\n, which may include a library of attributes.', 'Such processing may occur prior to input to the simulation component \n120\n (e.g., consider the processing component \n116\n).', 'As an example, the simulation component \n120\n may perform operations on input information based on one or more attributes specified by the attribute component \n130\n.', 'In an example embodiment, the simulation component \n120\n may construct one or more models of the geologic environment \n150\n, which may be relied on to simulate behavior of the geologic environment \n150\n (e.g., responsive to one or more acts, whether natural or artificial).', 'In the example of \nFIG. \n1\n, the analysis/visualization component \n142\n may allow for interaction with a model or model-based results (e.g., simulation results, etc.).', 'As an example, output from the simulation component \n120\n may be input to one or more other workflows, as indicated by a workflow component \n144\n.', 'As an example, the simulation component \n120\n may include one or more features of a simulator such as the ECLIPSE™ reservoir simulator (Schlumberger Limited, Houston Texas), the INTERSECT™ reservoir simulator (Schlumberger Limited, Houston Texas), etc.', 'As an example, a simulation component, a simulator, etc. may include features to implement one or more meshless techniques (e.g., to solve one or more equations, etc.).', 'As an example, a reservoir or reservoirs may be simulated with respect to one or more enhanced recovery techniques (e.g., consider a thermal process such as SAGD, etc.).', 'In an example embodiment, the management components \n110\n may include features of a commercially available framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Texas).', 'The PETREL® framework provides components that allow for optimization of exploration and development operations.', 'The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).', 'In an example embodiment, various aspects of the management components \n110\n may include add-ons or plug-ins that operate according to specifications of a framework environment.', 'For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Texas) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow.', 'The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user-friendly interfaces for efficient development.', 'In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'FIG.', '1\n also shows an example of a framework \n170\n that includes a model simulation layer \n180\n along with a framework services layer \n190\n, a framework core layer \n195\n and a modules layer \n175\n.', 'The framework \n170\n may include the commercially available OCEAN® framework where the model simulation layer \n180\n is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.', 'As an example, a framework may include features for implementing one or more mesh generation techniques.', 'For example, a framework may include an input component for receipt of information from interpretation of seismic data, one or more attributes based at least in part on seismic data, log data, image data, etc.', 'Such a framework may include a mesh generation component that processes input information, optionally in conjunction with other information, to generate a mesh.', 'In the example of \nFIG.', '1\n, the model simulation layer \n180\n may provide domain objects \n182\n, act as a data source \n184\n, provide for rendering \n186\n and provide for various user interfaces \n188\n.', 'Rendering \n186\n may provide a graphical environment in which applications can display their data while the user interfaces \n188\n may provide a common look and feel for application user interface components.', 'As an example, the domain objects \n182\n can include entity objects, property objects and optionally other objects.', 'Entity objects may be used to geometrically represent wells, surfaces, bodies, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters.', 'For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).', 'In the example of \nFIG.', '1\n, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks.', 'The model simulation layer \n180\n may be configured to model projects.', 'As such, a particular project may be stored where stored project information may include inputs, models, results and cases.', 'Thus, upon completion of a modeling session, a user may store a project.', 'At a later time, the project can be accessed and restored using the model simulation layer \n180\n, which can recreate instances of the relevant domain objects.', 'In the example of \nFIG.', '1\n, the geologic environment \n150\n may include layers (e.g., stratification) that include a reservoir \n151\n and one or more other features such as the fault \n153\n-\n1\n, the geobody \n153\n-\n2\n, etc.', 'As an example, the geologic environment \n150\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n152\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n155\n.', 'Such information may include information associated with downhole equipment \n154\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n156\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n155\n that may be configured for communications, noting that the satellite may additionally or instead include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n150\n as optionally including equipment \n157\n and \n158\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n159\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n157\n and/or \n158\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As mentioned, the system \n100\n may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable in the PETREL® software, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, a workflow may be a process implementable in the OCEAN® framework.', 'As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).', 'Embodiments of the disclosure may provide a software application (e.g., a computer-readable medium storing computer-executable instructions) for data management services in an E&P software platform, such as DELFI® (commercially-available from Schlumberger Technology Corporation).', 'The data management services application allows users to request services such as 3D or 2D seismic data loading or well data loading, e.g., for petrotechnical suite applications.', 'The data management services application may provide a user interface through which users can request a service from a services team along with the ability to track the service request through its lifecycle.', 'For example, the interface may include a dashboard that is personalized to both service providers and to clients.', "Thus, the interface dashboard may deliver both an internal or “service provider's” view and an external or “client's” view.", 'The data management application may also be integrated with billing systems, so as to automatically invoice clients for services provided once they are completed.', 'The external view allows the client to request a service, thereby generating a ticket to be acted upon by the service provider.', 'It also provides the client with tracking information, e.g., in real time on the status of the request through its lifecycle from ticket assignment to resolution.', 'It may also facilitate communication between the service provider and the client, e.g., by allowing the service provider to add comments at any stage to update the client on progress.', "In a specific embodiment, service requests may be saved in a “My Requests” section of the user interface, thereby providing a record of the user's service requests.", 'The internal view allows the service provider to assign a ticket (service request) internally and provide the client with tracking information in real time on the status of the request through its full lifecycle from ticket assignment to resolution.', 'In some embodiments, it also allows the service provider to communicate with the client through text messaging within the user interface in real time, thereby updating the client on progress and any other information required.', 'Upon resolution a billing event is created, and the client is automatically billed, e.g., based on the time taken to carry out the service request.', "Service requests may be saved, e.g., in a “My Tasks” section as a record of the service provider's service requests.", 'FIG.', '2\n illustrates an example petrotechnical processing environment in accordance with aspects of the present disclosure.', 'As shown in \nFIG.', '2\n, environment \n200\n includes a client device \n210\n, a data loading application server \n220\n, data sources \n230\n, a traffic management and authentication server \n240\n, a data processing application server \n250\n, and a network \n260\n.', 'The client device \n210\n may include a computing device capable of communicating via a network, such as the network \n260\n.', 'In example embodiments, the client device \n210\n corresponds to a portable computer device (e.g., a laptop or a tablet computer), a desktop computer, a server computer and/or another type of computing device.', 'In some embodiments, the client device \n210\n may be used to access a data loading application hosted by the data loading application server \n220\n to request a data loading service from the data loading application server \n220\n (e.g., a request to load data from one or more data sources \n230\n to a database, repository, and/or application).', 'Additionally, or alternatively, the client device \n210\n may be used to execute an application hosted by the data processing application server \n250\n.', 'In some embodiments, the client device \n210\n may be used to access the data loading application hosted by the data loading application server \n220\n to monitor and/or track the progress of data loading requests.', 'The data loading application server \n220\n may include one or more computing devices that hosts a data loading application and processes data loading requests received from one or more users (e.g., from the client device \n210\n).', 'In some embodiments, the data loading application server \n220\n may receive a data loading request (e.g., via a request form presented to the user within the data loading application), including an identification of data to load (e.g., data stored by one or more data sources \n230\n), the location of the identified data, and/or the location where the data should be loaded (e.g., a database, repository, application, etc.).', 'In some embodiments, the data loading application hosted by the data loading application server \n220\n may receive information tracking the progress of a data loading request (e.g., by a service provider that processes the request) and may publish the progress to the application for viewing by a user associated with the request.', 'As one illustrative example, the data loading application may process a request to load petrotechnical data, such as 2D seismic data, 3D seismic data, well-related data, or the like.', 'In some embodiments, the data loading application may process the request to load the petrotechnical data to a petrotechnical application (e.g., hosed by the data processing application server \n250\n) that uses or consumes the loaded data.', 'In some embodiments, the data loading application server \n220\n may be used to generate a custom data loading request form and/or a custom workflow for fulfilling/completing a data loading request.', 'The data loading application server \n220\n may save custom data loading request forms and/or custom workflows, which may be used as templates for generating a new data loading request form and/or custom workflow for a new user/client.', 'The data sources \n230\n may include one or more computing devices that stores any variety of types of data (e.g., structured or unstructured data).', 'In some embodiments, the data sources \n230\n may be available in a cloud or distributed computing environment, and the types of data available may be published such that a user may identify the data that may be available for loading (e.g., by searching and/or filtering by data type, geographic location associated with the data, etc.).', 'The traffic management and authentication server \n240\n may include one or more computing devices that manage access requests to the data loading application server \n220\n (e.g., access requests made by the client device \n210\n to access the data loading application and initiate data loading requests).', 'For example, the traffic management and authentication server \n240\n may act as a gatekeeper when the client device \n210\n access the data loading application server \n220\n.', 'In some embodiments, the traffic management and authentication server \n240\n may perform any variety of authentication and/or traffic management tasks, such as restricting access to the data loading application server \n220\n by a restricted client device \n210\n (e.g., a client device \n210\n located in a restricted geographic location, a client device \n210\n from a restricted network, etc.).', 'Additionally, or alternatively, the traffic management and authentication server \n240\n may perform authentication to permit or restrict the client device \n210\n from access the data loading application server \n220\n (e.g., credential verification, certificate verification, hash verification, encryption/decryption-based verification, etc.).', 'The data processing application server \n250\n may include one or more computing devices that host an application that may use or consume data loaded from one or more data sources \n230\n.', 'As one illustrative example, the data processing application server \n250\n may host a petrotechnical application to consume 2D seismic data, 3D seismic data, well-related data, etc. loaded form the data sources \n230\n as part of a data loading request.', 'Additionally, or alternatively, the data processing application server \n250\n may host any other variety of application that may consume data loaded from the data sources \n230\n as part of a data loading request.', 'The network \n260\n may include network nodes and one or more wired and/or wireless networks.', 'For example, the network \n260\n may include a cellular network (e.g., a second generation (2G) network, a third generation (3G) network, a fourth generation (4G) network, a fifth generation (2G) network, a long-term evolution (LTE) network, a global system for mobile (GSM) network, a code division multiple access (CDMA) network, an evolution-data optimized (EVDO) network, or the like), a public land mobile network (PLMN), and/or another network.', 'Additionally, or alternatively, the network \n260\n may include a local area network (LAN), a wide area network (WAN), a metropolitan network (MAN), the Public Switched Telephone Network (PSTN), an ad hoc network, a managed Internet Protocol (IP) network, a virtual private network (VPN), an intranet, the Internet, a fiber optic-based network, and/or a combination of these or other types of networks.', 'In embodiments, the network \n260\n may include copper transmission cables, optical transmission fibers, wireless transmission, routers, firewalls, switches, gateway computers and/or edge servers.', 'The quantity of devices and/or networks in the environment \n200\n is not limited to what is shown in \nFIG.', '2\n.', 'In practice, the environment \n200\n may include additional devices and/or networks; fewer devices and/or networks; different devices and/or networks; or differently arranged devices and/or networks than illustrated in \nFIG. \n2\n.', 'Also, in some implementations, one or more of the devices of the environment \n200\n may perform one or more functions described as being performed by another one or more of the devices of the environment \n200\n.', 'Devices of the environment \n200\n may interconnect via wired connections, wireless connections, or a combination of wired and wireless connections.\n \nFIG.', '3\n illustrates a flowchart of a process \n300\n for processing a request to access a data loading service, according to an embodiment.', 'As shown in \nFIG. \n3\n, the process \n300\n may include receiving a request to access a data loading service (as at \n310\n).', 'For example, the traffic management and authentication server \n240\n may receive a request to access a data loading service from the client device \n210\n.', 'In some embodiments, the client device \n210\n may provide the request via an application or web portal used to submit data loading requests to the data loading application server \n220\n.', 'The process \n300\n may further include determining properties of the requestor (as at \n320\n).', 'For example, the traffic management and authentication server \n240\n may determine properties of the requestor (e.g., the requesting client device \n210\n), such as an IP address, a geographic location, a network location, a device identifier, etc.', 'In some embodiments, the traffic management and authentication server \n240\n may determine properties of the requestor using an IP address detection application from which a geographic location may be deciphered.', 'Additionally, or alternatively, the traffic management and authentication server \n240\n may obtain network location information from a network locator service.', 'The process \n300\n may also include determining whether the requestor is authorized to access the data loading application server \n220\n (as at \n330\n).', 'For example, the traffic management and authentication server \n240\n may determine whether the requesting client device \n210\n is authorized access the data loading application server \n220\n based on the properties of the client device \n210\n (e.g., determined at \n320\n).', 'In some embodiments, the traffic management and authentication server \n240\n may use a lookup table having information identifying the properties of authorized requestors and match the properties of the requestor to the lookup table.', 'If, for example, the requestor is not authorized (as at \n330\n-NO), such as when the client device \n210\n is from a restricted geographic location, restricted network location, etc., the process \n300\n may further include preventing access (as at block \n340\n).', 'For example, the traffic management and authentication server \n240\n may prevent access to the data loading application server \n220\n by the client device \n210\n (e.g., by redirecting the client device \n210\n to another address away from the data loading application server \n220\n, presenting an error message, etc.).', 'If, on the other hand, the requestor is authorized (as at \n330\n-YES), the process \n300\n may also include authenticating a user (as at \n350\n).', 'For example, the traffic management and authentication server \n240\n may authenticate the user of the client device \n210\n using any variety of authentication techniques (e.g., credential verification, certificate verification, hash verification, encryption/decryption-based verification, etc.).', 'The process \n300\n may also include determining whether the user is authenticated (as at \n360\n).', 'For example, the traffic management and authentication server \n240\n may determine whether the user is authenticated based on performing user authentication (from \n350\n).', 'If, for example, the user is not authenticated (as at \n360\n-NO), the process \n300\n may return to \n340\n in which the traffic management and authentication server \n240\n may prevent access to the data loading application server \n220\n.', 'If, on the other hand, the user is authenticated (as at \n360\n-YES), the process \n300\n may continue to \n370\n in which the data loading application server \n220\n may permit access to the traffic management and authentication server \n240\n and present a data loading application interface for the user of the client device \n210\n to initiate a data loading request (as further described in \nFIG.', '4\n).', 'FIG.', '4\n illustrates a flowchart of a process \n400\n for processing a data loading services request handling, according to an embodiment.', 'As shown in \nFIG.', '4\n, the process \n400\n may begin at node A which may occur subsequent to the traffic management and authentication server \n240\n granting access to the data loading application server \n220\n by the client device \n210\n and presenting the data loading application interface (e.g., the UI as described above with respect to \nFIG.', '3\n).', 'The process \n400\n may include receiving a data loading service request (as at \n402\n).', 'In some embodiments, the request may be submitted by a client/user through a user interface (UI) and using the client device \n210\n (e.g., using a data loading services application and accessing the data loading application server \n220\n).', 'For example, the user may log into the data loading services application and may be presented with a UI of the application.', 'In some embodiments, the UI may provide a Data Management Services Request Form.', 'The request form may include fields in which the user may request one or more of data loading services for loading (e.g., copying, syncing, and/or transferring) oilfield-related data (e.g., to an application, a database, a repository, etc.).', 'Oilfield-related data refers to data that represents one or more aspects of an oilfield (e.g., geological data, seismic data, drilling data, production data, etc.).', 'As illustrative, non-limiting examples, the user may use the request form to request 2D seismic data loading, 3D seismic data loading, well data loading, etc.', 'In some embodiments, the data loading request may include information identifying the requested data and the destination of the data (e.g., a database, repository, application, etc.).', 'In some embodiments, the data loading request application may include a search/filter feature in which the user may search for types of data available on the data sources \n230\n that may be loaded.', 'In some embodiments, the user may specify loading procedures (e.g., loading times, network resource consumption limits, etc.).', 'As described herein, the request form may be customized by the data loading services provider.', 'In some embodiments, the request form and the workflows associated with the different workflows may be customized for different users/clients.', 'In response to receiving the service request, the process \n400\n may proceed to generating a service ticket in a ticketing system, as at \n404\n.', 'In some embodiments, the data loading application server \n220\n may host a service ticketing system in which the data loading application server \n220\n may generate a ticket representing the data loading service request.', 'In some embodiments, the ticket may identify details of the data loading service request (e.g., an identifier of a client or user that initiated the request, the requested data, the location of the data, and/or the destination of the data, an application type for which the data is to be used, etc.).', 'Additionally, or alternatively, the service ticket may identify a workflow for completing the data loading service request.', 'For example, the data loading application server \n220\n may store multiple different custom workflows for fulfilling different data loading service requests.', 'Accordingly, the data loading application server \n220\n may identify a particular custom workflow associated with the data loading service request identified by the service ticket.', 'Further, it will be appreciated that the data loading services application may be integrated with any service management ticketing system.', 'In this way, the ticket may be shared with any variety of stakeholders and the stakeholders may be notified when a ticket is created.', 'The process \n400\n may further include assigning the data loading service request to one or more resources (as at \n406\n).', 'For example, the data loading application server \n220\n may assign the service request to the one or more resources.', 'In some embodiments, a resource may include an operator, a system, and/or automated system.', 'In some embodiments, the data loading application server \n220\n may select the resource based on the details of the service request and/or information included in the ticket (e.g., an identity of the requesting user/client, the type of data requested for loading, the volume of data requested to be loaded, the application type to receive the data, the workflow associated with the request, etc.).', 'In this way, the data loading service request may be assigned to the best-suited resource(s) having knowledge and/or capabilities of how to best handle and complete the service request (e.g., operators with knowledge, training, and/or experience with the application associated with the request, the client associated with the request, etc.).', 'In some embodiments, any variety of rules and/or criteria may be implemented to determine which operator or group of operators with whom to assign the data loading service request.', 'In some embodiments, the data loading application server \n220\n may assign the data loading service request to an automated system in addition to, or instead of an operator in which the automated system may process the data loading service request without operator involvement.', 'In some embodiments, the data loading application server \n220\n may assign the data loading service request based on resource availability, current workload, etc.', 'That is, the data loading application server \n220\n may perform load balancing when selecting resource(s) to assign the ticket.', 'In this way, the data loading application server \n220\n may assign the service ticket to one or more resources by matching the resources with the details of the data loading service request identified in the service ticket.', 'In some embodiments, the data loading application server \n220\n may provide the assigned resource with information identifying the workflow (e.g., a particular custom workflow) associated with the request such that the assigned resource may fulfill/complete the request in accordance with the identified workflow.', 'As described herein, the workflow for different requests and clients may be customized.', 'In some embodiments, the data loading application server \n220\n may determine the workflow based on the details of the data loading service request included in the service ticket.', 'For example, the data loading application server \n220\n may store rules that define workflows based on the details of the data loading service request and/or the type of custom request form that was used to receive the data loading service request.', 'The process \n400\n may also include receiving and providing updates on the status of the processing of the request through a user interface (as at \n408\n).', 'For example, the data loading application server \n220\n may receive information regarding the progress of the processing of the request from a variety of sources, such as operator input indicating the progress, input from an automated system involved in processing the request, etc.', 'In other words, the data loading application server \n220\n may receive updates as the workflow for completing the data loading services request progresses.', 'In some embodiments, the updates may be provided at any or all times from assignment to resolution, e.g., (using a GUI tracking dashboard), thereby providing visibility on service status.', 'In some embodiments, the GUI tracking dashboard may present information regarding the progression of workflow stages, milestones, and/or subtasks of the request after the request is submitted by the user.', 'As a non-limiting, illustrative example, the GUI tracking dashboard may present information regarding workflow stages, such as: \n \n \n \nNew Request: notifying the user that a ticket has been generated against their request;\n \nAssigned: notifying the user that the ticket has been assigned to a service provider operator, (e.g., including the contact information of that operator);\n \nTask Duration: notifying the user of the time the request will take to complete;\n \nResolved: notifying the user that the request is resolved and the data has been loaded for them;\n \nClose request: requesting that the user now close the request if satisfied with the service;\n \nNew events: messages from the service provider operator;\n \nOn Hold: if the request is on hold for a particular reason;\n \nAwaiting user response: if the service provider operator requires more information from the user;\n \nEscalated to Third-Party or to Engineering, if appropriate.', 'In this way the user or requestor of the data loading service may track the progress of their request from the point of request initiation or ticket generation to completion, as the system may continuously provide updates on the status through the user interface.', 'In some embodiments, the data loading application server \n220\n may provide an internal dashboard including the status and tracking of tasks that may not be visible to the user, but rather solely to the service provider.', 'For example, the internal dashboard may assist operators in managing and/or completing the service request.', 'In such an internal dashboard, the service provider may assign a ticket to an operator, set the task duration, send communications to the user, set the task status at various stages of the request lifecycle to the statuses previously mentioned, etc.', 'The process \n400\n may also include notifying the user when the requested service is complete (as at \n410\n), and closing the ticket and/or initiating billing upon a certain amount of time (or another trigger) after notifying the user that the task is complete (as at \n412\n).', 'In some embodiments, the data loading application server \n220\n may close the ticket upon completion of all milestones or subtasks associated with the request have been completed.', 'Additionally, or alternatively, a ticket may close automatically after a certain number of days (e.g., five days) in a situation in which the user has not responded to a query or request for additional information.', 'Upon closing of the ticket, the data loading application server \n220\n may notify the user (e.g., via e-mail, text messaging, through a team collaboration application, etc.).', 'In some embodiments, the data loading application server \n220\n may notify the user upon completion of each milestone or stage.', 'The data loading application server \n220\n may further initiate billing upon completion of a ticket in which a bill is generated based on the service requested, the milestones or stages completed, and/or other billing rules, rates, and/or parameters identified in a service level agreement (SLA).', 'In some embodiments, aspects of the present disclosure may be used to track requests for a variety of oil/gas domain and/or petrotechnical data services.', 'For example, aspects of the present disclosure may be used to track request relates to application workflow support, application user support, workflow support, training services, tailored workflow generation, application management, application packaging, release management, data management, data quality control, data management governance, data provisioning, data ecosystem ingestion services, petrotechnical infrastructure support database management, and/or infrastructure optimization.\n \nFIG.', '5\nA\n illustrates an example of request form that may be presented to a user within a UI for submitting a data loading services request.', 'As shown in \nFIG.', '5\nA\n, the request form \n500\n may include a field area \n510\n in which a user may provide inputs defining parameters and details of the data loading service request.', 'In the example shown in \nFIG.', '5\nA\n, the request form \n500\n may include a drop-down menu for selecting the type of data to load (e.g., 2D seismic data, 3D seismic data, well-related data, etc.), as at \n512\n.', 'In some embodiments, the request form \n500\n may further include a set of radio buttons to select an application with which to load the data, as at \n514\n.', 'In some embodiments, the request form \n500\n may further include a radio button for selecting whether the data is to be loaded to a new project or exiting project, as at \n516\n, and a field to enter a name of the project, as at \n518\n.', 'Additionally, or alternatively, the request form \n500\n may include a field for selecting a path or link to the input data to be loaded, as at \n520\n.', 'Additionally, or alternatively, the data loading application server \n220\n may provide a filtering or search tool to search for data to be loaded based on attributes of the data, and information identifying the selected data may inputted into the request form.', 'Based on the details inputted into the request form \n500\n, the data loading application server \n220\n may generate a ticket with the details of the request, identify an appropriate workflow for fulfilling/completing the request, assign the ticket to one or more resources, and track/report the progress of the workflow completion.', 'The example shown in \nFIG.', '5\nA\n is provided as an illustrative example.', 'In practice, the request form may differ than what is shown in \nFIG.', '5\nA\n.', 'Further, as described herein, the request form may be customized for different users and clients using a custom form generator.\n \nFIG.', '5\nB\n illustrates an example custom form generator for generating a form that may be presented to a user for receiving a data loading service request.', 'For example, as described herein, different forms may be used to receive data loading service request from different users whose data loading needs may differ (e.g., based on the nature of their industry, applications used with loaded data, etc.).', 'As shown in \nFIG.', '5\nB\n, a custom form generator \n550\n may include an objects area in which a user may select a variety of objects to include the custom form, as at \n552\n.', 'In some embodiments, the objects may include a text box, a text area, a checkbox, a radio button, a selection option, etc.', 'In some embodiments, an object may be dragged and dropped to the custom form.', 'As one example, the checkbox object may be dragged and dropped, as at \n554\n.', 'The label of the checkbox title may be inputted, as at \n556\n (e.g., “Select Country”, and the labels of each checkbox may be inputted, as at \n558\n (e.g., “India,” and “USA”).', 'As further shown in the example of \nFIG. \n5\nB\n, a text area may be dragged and dropped to the form, as at \n560\n.', 'The label of the text area may be inputted, as at \n562\n (e.g., “Name”).', 'In this example, the custom form may include a field for the user to entire a name associated with the request.', 'As described herein, the custom form may include any variety of fields, textboxes, radio buttons, checkboxes, etc. for the purposes of generating a custom request form for a particular client or group of clients so that different information may be inputted into the request forms for different clients/users.', 'Further, the custom forms may be saved and used as templates (e.g., used as-is, or as a basis for generating a different custom form).', 'FIG.', '6\n illustrates an example GUI tracking dashboard identifying the progress of workflow for completing a data loading service request.', 'As shown in \nFIG. \n6\n, the GUI tracking dashboard \n600\n may present the progression status of a ticket corresponding to a workflow for the data loading service request (e.g., a request to load well data from a data source \n230\n to an application).', 'The GUI tracking dashboard \n600\n may include a tracking area \n610\n in which each workflow stage or milestone of the ticket is presented, along with status of each stage.', 'Each stage may be timestamped and described with a narrative.', 'In this way, the user may easily view the status of their data loading service request ticket without the need for extensive physical site visits, service calls, etc.', 'Further, the user may comment on various stages of the ticket to communicate with the operator and/or other team members involved with the ticket.', 'As described herein, the workflow for completing the request may be customized and thus, in practice, the workflow may appear different than the example shown in \nFIG.', '6\n.', 'In some embodiments, the methods of the present disclosure may be executed by a computing system.', 'FIG.', '7\n illustrates an example of such a computing system \n700\n, in accordance with some embodiments.', 'The computing system \n700\n may include a computer or computer system \n701\nA, which may be an individual computer system \n701\nA or an arrangement of distributed computer systems.', 'The computer system \n701\nA includes one or more analysis modules \n702\n that are configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein.', 'To perform these various tasks, the analysis module \n702\n executes independently, or in coordination with, one or more processors \n704\n, which is (or are) connected to one or more storage media \n706\n.', 'The processor(s) \n704\n is (or are) also connected to a network interface \n707\n to allow the computer system \n701\nA to communicate over a data network \n709\n with one or more additional computer systems and/or computing systems, such as \n701\nB, \n701\nC, and/or \n701\nD (note that computer systems \n701\nB, \n701\nC and/or \n701\nD may or may not share the same architecture as computer system \n701\nA, and may be located in different physical locations, e.g., computer systems \n701\nA and \n701\nB may be located in a processing facility, while in communication with one or more computer systems such as \n701\nC and/or \n701\nD that are located in one or more data centers, and/or located in varying countries on different continents).', 'A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'The storage media \n706\n may be implemented as one or more computer-readable or machine-readable storage media.', 'Note that while in the example embodiment of \nFIG.', '7\n storage media \n706\n is depicted as within computer system \n701\nA, in some embodiments, storage media \n706\n may be distributed within and/or across multiple internal and/or external enclosures of computing system \n701\nA and/or additional computing systems.', 'Storage media \n706\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY® disks, or other types of optical storage, or other types of storage devices.', 'Note that the instructions discussed above may be provided on one computer-readable or machine-readable storage medium, or may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture).', 'An article or article of manufacture may refer to any manufactured single component or multiple components.', 'The storage medium or media may be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In some embodiments, computing system \n700\n contains one or more data management module(s) \n708\n.', 'In the example of computing system \n700\n, computer system \n701\nA includes the data management module \n708\n.', 'In some embodiments, a single data management module may be used to perform some aspects of one or more embodiments of the methods disclosed herein.', 'In other embodiments, a plurality of data management modules may be used to perform some aspects of methods herein.', 'It should be appreciated that computing system \n700\n is merely one example of a computing system, and that computing system \n700\n may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of \nFIG.', '7\n, and/or computing system \n700\n may have a different configuration or arrangement of the components depicted in \nFIG. \n7\n.', 'The various components shown in \nFIG.', '7\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices.', 'These modules, combinations of these modules, and/or their combination with general hardware are included within the scope of the present disclosure.', 'Computational interpretations, models, and/or other interpretation aids may be refined in an iterative fashion; this concept is applicable to the methods discussed herein.', 'This may include use of feedback loops executed on an algorithmic basis, such as at a computing device (e.g., computing system \n700\n, \nFIG. \n7\n), and/or through manual control by a user who may make determinations regarding whether a given step, action, template, model, or set of curves has become sufficiently accurate for the evaluation of the subsurface three-dimensional geologic formation under consideration.', 'The foregoing description, for purpose of explanation, has been described with reference to specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or limiting to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'Moreover, the order in which the elements of the methods described herein are illustrate and described may be re-arranged, and/or two or more elements may occur simultaneously.', 'The embodiments were chosen and described in order to best explain the principals of the disclosure and its practical applications, to thereby enable others skilled in the art to best utilize the disclosed embodiments and various embodiments with various modifications as are suited to the particular use contemplated.']

['1.', 'A method comprising:\nreceiving a data loading service request for loading oilfield-related data to an application;\ngenerating a service ticket in response to the request, the service ticket identifying details of the data loading service request;\nassigning one or more tasks associated with the service ticket to one or more resources comprising one or more automated systems and one or more operators, wherein assigning the one or more tasks comprises selecting the one or more resources based on information included in the service ticket, wherein the information comprises a type of data associated with the data loading service request, a volume of the data to be loaded, and an application type to receive the data, and wherein the one or more resources are selected based on: one or more availability schedules of the one or more operators; one or more training profiles of the one or more operators with respect to the application type; and one or more capabilities of the one or more automated systems to complete the data loading service request with respect to the type of data and the volume of the data;\nreceiving, from the one or more resources, additional information regarding a status of completion of the data loading service request after the one or more tasks are assigned to the one or more resources, wherein the additional information comprises a new request, a request assigned, a request resolved, a close request, or any combination thereof; and\nproviding one or more updates of the status of the requested service to a user through a user interface, wherein the data is used by the application to perform an oil/gas recovery or exploration task.', '2.', 'The method of claim 1, wherein the data loading service request is received from the user via a custom form presented in the user interface associated with a data loading services application.', '3.', 'The method of claim 2, further comprising:\nsaving the custom form; and\ngenerating another custom form for a different user using the saved custom form.', '4.', 'The method of claim 1, wherein the details of the data loading service request include a type of service or a type of service request,\nwherein the type of data includes at least one selected from the group consisting of: 2D seismic data; 3D seismic data; and well-related data, and\nwherein the type of service includes at least one selected from the group consisting of: application workflow support; application user support; workflow support; training services; tailored workflow generation; application management; application packaging; release management; data management; data quality control; data management governance; data provisioning; data ecosystem ingestion services; petrotechnical infrastructure support; database management; and infrastructure optimization.', '5.', 'The method of claim 1, further comprising identifying a custom workflow, of a plurality of saved custom workflows, associated with the service ticket, wherein assigning the one or more tasks is based on the identifying the custom workflow.', '6.', 'A computing system, comprising:\none or more processors; and\na memory system comprising one or more non-transitory computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations, the operations comprising: receiving a data loading service request for loading oilfield-related data to an application; generating a service ticket in response to the request, the service ticket identifying details of the data loading service request; assigning one or more tasks associated with the service ticket to one or more resources comprising one or more automated systems and one or more operators, wherein assigning the one or more tasks comprises selecting the one or more resources based on information included in the service ticket, wherein the information comprises a type of data associated with the data loading service request, a volume of the data to be loaded, and an application type to receive the data, and wherein the one or more resources are selected based on: one or more availability schedules of the one or more operators; one or more training profiles of the one or more operators with respect to the application type; and one or more capabilities of the one or more automated systems to complete the data loading service request with respect to the type of data and the volume of data; receiving, from the one or more resources, additional information regarding a status of completion of the data loading service request after the one or more tasks are assigned to the one or more resources, wherein the additional information comprises a new request, a request assigned, a request resolved, a close request, or any combination thereof; and providing one or more updates of the status of the requested service to a user through a user interface, wherein the data is used by the application to perform an oil/gas recovery or exploration task.', '7.', 'The system of claim 6, wherein the data loading service request is received from the user via a custom form presented in the user interface associated with a data loading services application.', '8.', 'The system of claim 7, wherein the operations further comprise:\nsaving the custom form; and\ngenerating another custom form for a different user using the saved custom form.', '9.', 'The system of claim 6, wherein the details of the service request include a type of service or a type of data to load or a type of service request,\nwherein the type of data to load includes at least one selected from the group consisting of: 2D seismic data; 3D seismic data; and well-related data,\nwherein the type of service includes at least one selected from the group consisting of: application workflow support; application user support; workflow support; training services; tailored workflow generation; application management; application packaging; release management; data management; data quality control; data management governance; data provisioning; data ecosystem ingestion services; petrotechnical infrastructure support; database management; and infrastructure optimization.', '10.', 'The system of claim 6, further comprising identifying a custom workflow, of a plurality of saved custom workflows, associated with the service ticket, wherein assigning the one or more tasks is based on the identifying the custom workflow.', '11.', 'A non-transitory computer-readable medium storing instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations, the operations comprising:\nreceiving a data loading service request for loading oilfield-related data to an application;\ngenerating a service ticket in response to the request, the service ticket identifying details of the data loading service request;\nassigning one or more tasks associated with the service ticket to one or more resources comprising one or more automated systems and one or more operators, wherein assigning the one or more tasks comprises selecting the one or more resources based on information included in the service ticket, wherein the information comprises a type of data associated with the data loading service request, a volume of data to be loaded, and application type to receive the data, and wherein the one or more resources are selected based on: one or more availability schedules of the one or more operators; one or more training profiles of the one or more operators with respect to the application type; and one or more capabilities of the one or more automated systems to complete the data loading service request with respect to the type of data and the volume of the data;\nreceiving, from the one or more resources, additional information regarding a status of completion of the data loading service request after the one or more tasks are assigned to the one or more resources, wherein the additional information comprises a new request, a request assigned, a request resolved, a close request, or any combination thereof; and\nproviding one or more updates of the status of the requested service to a user through a user interface, wherein the data is used by the application to perform an oil/gas recovery or exploration task.\n\n\n\n\n\n\n12.', 'The computer-readable medium of claim 11, wherein the data loading service request is received from the user via a custom form presented in the user interface associated with a data loading services application.', '13.', 'The computer-readable medium of claim 12, wherein the operations further comprise:\nsaving the custom form; and\ngenerating another custom form for a different user using the saved custom form.', '14.', 'The computer-readable medium of claim 11, further comprising identifying a custom workflow, of a plurality of saved custom workflows, associated with the service ticket, wherein the assigning the one or more tasks is based on the identifying the custom workflow.', '15.', 'The method of claim 2, wherein the data loading services application closes the service ticket upon completion of the one or more tasks.', '16.', 'The computing system of claim 7, wherein the data loading services application closes the service ticket upon completion of the one or more tasks.', '17.', 'The computer-readable medium of claim 12, wherein the data loading services application closes the service ticket upon completion of the one or more tasks.']

['FIG. 1 illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.; FIG.', '2 illustrates an example petrotechnical processing environment according to an embodiment.; FIG.', '3 illustrates a flowchart of a process for processing a request to access a data loading service, according to an embodiment.; FIG.', '4 illustrates a flowchart of a process for processing a data loading services request handling, according to an embodiment.;', 'FIG.', '5A illustrates an example of request form that may be presented to a user within a UI for submitting a data loading services request.', '; FIG.', '5B illustrates an example custom form generator for generating a form that may be presented to a user for receiving a data loading service request.; FIG.', '6 illustrates an example GUI tracking dashboard identifying the progress of workflow for completing a data loading service request.; FIG.', '7 illustrates a schematic view of a computing system, according to an embodiment.; FIG.', '1 illustrates an example of a system 100 that includes various management components 110 to manage various aspects of a geologic environment 150 (e.g., an environment that includes a sedimentary basin, a reservoir 151, one or more faults 153-1, one or more geobodies 153-2, etc.).', 'For example, the management components 110 may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 150.', 'In turn, further information about the geologic environment 150 may become available as feedback 160 (e.g., optionally as input to one or more of the management components 110).; FIG.', '1 also shows an example of a framework 170 that includes a model simulation layer 180 along with a framework services layer 190, a framework core layer 195 and a modules layer 175.', 'The framework 170 may include the commercially available OCEAN® framework where the model simulation layer 180 is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.; FIG. 1 also shows the geologic environment 150 as optionally including equipment 157 and 158 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 159.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 157 and/or 158 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG.', '2 illustrates an example petrotechnical processing environment in accordance with aspects of the present disclosure.', 'As shown in FIG.', '2, environment 200 includes a client device 210, a data loading application server 220, data sources 230, a traffic management and authentication server 240, a data processing application server 250, and a network 260.; FIG.', '3 illustrates a flowchart of a process 300 for processing a request to access a data loading service, according to an embodiment.', 'As shown in FIG.', '3', ', the process 300 may include receiving a request to access a data loading service (as at 310).', 'For example, the traffic management and authentication server 240 may receive a request to access a data loading service from the client device 210.', 'In some embodiments, the client device 210 may provide the request via an application or web portal used to submit data loading requests to the data loading application server 220.; FIG.', '4 illustrates a flowchart of a process 400 for processing a data loading services request handling, according to an embodiment.', 'As shown in FIG. 4, the process 400 may begin at node A which may occur subsequent to the traffic management and authentication server 240 granting access to the data loading application server 220 by the client device 210 and presenting the data loading application interface (e.g., the UI as described above with respect to FIG.', '3).', 'The process 400 may include receiving a data loading service request (as at 402).', 'In some embodiments, the request may be submitted by a client/user through a user interface (UI) and using the client device 210 (e.g., using a data loading services application and accessing the data loading application server 220).', 'For example, the user may log into the data loading services application and may be presented with a UI of the application.;', 'FIG.', '5A illustrates an example of request form that may be presented to a user within a UI for submitting a data loading services request.', 'As shown in FIG.', '5A, the request form 500 may include a field area 510 in which a user may provide inputs defining parameters and details of the data loading service request.', 'In the example shown in FIG.', '5A, the request form 500 may include a drop-down menu for selecting the type of data to load (e.g., 2D seismic data, 3D seismic data, well-related data, etc.), as at 512.', 'In some embodiments, the request form 500 may further include a set of radio buttons to select an application with which to load the data, as at 514.', 'In some embodiments, the request form 500 may further include a radio button for selecting whether the data is to be loaded to a new project or exiting project, as at 516, and a field to enter a name of the project, as at 518.', 'Additionally, or alternatively, the request form 500 may include a field for selecting a path or link to the input data to be loaded, as at 520.', 'Additionally, or alternatively, the data loading application server 220 may provide a filtering or search tool to search for data to be loaded based on attributes of the data, and information identifying the selected data may inputted into the request form.', '; FIG.', '5B illustrates an example custom form generator for generating a form that may be presented to a user for receiving a data loading service request.', 'For example, as described herein, different forms may be used to receive data loading service request from different users whose data loading needs may differ (e.g., based on the nature of their industry, applications used with loaded data, etc.).', 'As shown in FIG.', '5B, a custom form generator 550 may include an objects area in which a user may select a variety of objects to include the custom form, as at 552.', 'In some embodiments, the objects may include a text box, a text area, a checkbox, a radio button, a selection option, etc.', 'In some embodiments, an object may be dragged and dropped to the custom form.', 'As one example, the checkbox object may be dragged and dropped, as at 554.', 'The label of the checkbox title may be inputted, as at 556 (e.g., “Select Country”, and the labels of each checkbox may be inputted, as at 558 (e.g., “India,” and “USA”).', 'As further shown in the example of FIG.', '5B, a text area may be dragged and dropped to the form, as at 560.', 'The label of the text area may be inputted, as at 562 (e.g., “Name”).', 'In this example, the custom form may include a field for the user to entire a name associated with the request.', 'As described herein, the custom form may include any variety of fields, textboxes, radio buttons, checkboxes, etc. for the purposes of generating a custom request form for a particular client or group of clients so that different information may be inputted into the request forms for different clients/users.', 'Further, the custom forms may be saved and used as templates (e.g., used as-is, or as a basis for generating a different custom form).', '; FIG.', '6 illustrates an example GUI tracking dashboard identifying the progress of workflow for completing a data loading service request.', 'As shown in FIG.', '6, the GUI tracking dashboard 600 may present the progression status of a ticket corresponding to a workflow for the data loading service request (e.g., a request to load well data from a data source 230 to an application).', 'The GUI tracking dashboard 600 may include a tracking area 610 in which each workflow stage or milestone of the ticket is presented, along with status of each stage.', 'Each stage may be timestamped and described with a narrative.', 'In this way, the user may easily view the status of their data loading service request ticket without the need for extensive physical site visits, service calls, etc.', 'Further, the user may comment on various stages of the ticket to communicate with the operator and/or other team members involved with the ticket.', 'As described herein, the workflow for completing the request may be customized and thus, in practice, the workflow may appear different than the example shown in FIG.', '6.']

US11933156

Controller augmenting existing control system

Apr 28, 2020

Joergen K Johnsen, Hugo Rosano, Mahmoud Hadi, Jason Enderby, Mbaga Louis Ahorukomeye, Yuzhen Xue, Rui Pan, Juan Jose Rojas

SCHLUMBERGER TECHNOLOGY CORPORATION

Search Report and Written Opinion of International Patent Application No. PCT/US2021/029258 dated Aug. 19, 2021; 10 pages.; Electro Project, Soft Torque, accessed Apr. 27, 2020, 2 pages; <https://www.softtorque.com/soft-torque/what-is-ep-soft-torque>.

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['An augmenting controller for augmenting control of an actuator by a component controller.', 'The actuator is operable to change an operational parameter of a component of a drilling rig.', 'The component controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component.', 'The augmenting controller is operable to augment the control signals.']

['Description\n\n\n\n\n\n\nBACKGROUND OF THE DISCLOSURE\n \nExisting drilling rigs include various components controlled by corresponding actuators.', 'Some of the actuators are controlled by programmable logic controllers (PLCs).', 'However, the PLCs are often not able to cause the actuators and (thus) their controlled components to perform advanced operations, particularly operations developed years after the PLCs were initially deployed.', 'For example, existing rig control systems are often restricted to being handled by its core technologies, thus prohibiting integration of new technologies.', 'The existing PLCs also may not have sufficient processing power and/or communication speed/bandwidth to perform the advanced operations.', 'SUMMARY OF THE DISCLOSURE', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure introduces an apparatus that includes an augmenting controller for augmenting control of an actuator by a component controller.', 'The actuator is operable to change an operational parameter of a component of a drilling rig.', 'The component controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component.', 'The augmenting controller is operable to augment the control signals.', 'The present disclosure also introduces a system that includes an actuator, a first controller, and a second controller.', 'The actuator is operable to change an operational parameter of a drilling rig component.', 'The first controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component.', 'The second controller is connected between the first controller and the actuator and is operable to alter the control signals.', 'The present disclosure also introduces a method that includes electronically connecting an augmenting controller to an actuator.', 'The actuator is operable to change an operational parameter of a component of a drilling rig.', 'A component controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component.', 'The method also includes causing operation of the augmenting controller.', 'Operation of the augmenting controller includes augmenting the control signals to thereby augment control of the actuator by the component controller.', 'These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the material herein and/or practicing the principles described herein.', 'At least some aspects of the present disclosure may be achieved via means recited in the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is understood from the following detailed description when read with the accompanying figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n is a schematic view of at least a portion of an example implementation of a system according to one or more aspects of the present disclosure.\n \nFIG.', '2\n is a schematic view of at least a portion of another example implementation of the system shown in \nFIG.', '1\n according to one or more aspects of the present disclosure.', 'FIG.', '3\n is a schematic view of at least a portion of another example implementation of the systems shown in \nFIGS.', '1\n and \n2\n according to one or more aspects of the present disclosure.\n \nFIG.', '4\n is a schematic view of at least a portion of another example implementation of the systems shown in \nFIGS.', '1\n-\n3\n according to one or more aspects of the present disclosure.', 'FIG.', '5\n is a schematic view of at least a portion of another example implementation of the systems shown in \nFIGS.', '1\n-\n4\n according to one or more aspects of the present disclosure.', 'FIG.', '6\n is a schematic view of at least a portion of an example implementation of a processing system according to one or more aspects of the present disclosure.', 'DETAILED DESCRIPTION', 'It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments.', 'Specific examples of components and arrangements are described below to simplify the present disclosure.', 'These are, of course, merely examples and are not intended to be limiting.', 'In addition, the present disclosure may repeat reference numerals and/or letters in the various examples.', 'This repetition is for simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.', 'Moreover, the formation of a first feature over or on a second feature in the description that follows may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.\n \nFIG.', '1\n is a schematic view of at least a portion of an example implementation of a preexisting system \n100\n according to one or more aspects introduced by the present disclosure.', 'The system \n100\n comprises a drilling rig component \n110\n, an actuator \n120\n in communication with and/or otherwise operable to control operation of the component \n110\n, and a controller \n130\n in communication with the actuator \n120\n and operable to communication control signals to the actuator \n120\n.', 'The component \n110\n depicted in \nFIG.', '1\n is representative of various drilling rig components that may be operated in conjunction with an augmenting controller \n140\n according to one or more aspects of the present disclosure.', 'For example, the component \n110\n may be a top drive \n112\n, a drawworks \n114\n, or one or more mud pumps \n116\n.', 'However, the component \n110\n may also or instead be or comprise one or more other drilling rig components, such as an iron roughneck and/or other tubular handling equipment, and/or a choke, a return valve, and/or other valves, among other examples.', 'The actuator \n120\n is depicted as a variable frequency drive (VFD) for driving an alternating-current (AC) motor of the component \n110\n.', 'Thus, in the context of the present disclosure, the actuator \n120\n is not limited to conventional “actuators” that convert a form of energy to a mechanical motion.', 'In addition, the actuator \n120\n may be or comprise other types of drives, servos, solenoids, pistons/cylinders (e.g., hydraulic or pneumatic), and/or other types of actuators that can be operated via control signals communicated from the controller \n130\n in order to control operation of the component \n110\n.', 'The controller \n130\n is a PLC and/or other controller specifically designed and/or programmed to communicate control signals to the actuator \n120\n in order to control the actuator \n120\n and, thereby, the component \n110\n.', 'For example, the controller \n130\n is likely not a PC-based controller.', 'The controller \n130\n is not able to cause the actuator \n120\n and the component \n110\n to perform one or more drilling domain applications for various reasons.', 'For example, the controller \n130\n may simply not be programmed for such drilling domain applications, or the controller \n130\n may lack the physical processing power, memory, and/or communication means sufficient to perform such drilling domain applications.', 'The controller \n130\n may also (or instead) not be compatible with higher level programming languages often utilized in solving advanced mathematics and/or optimization problems integral to the drilling domain applications.', 'The controller \n130\n may also (or instead) not be configured or configurable for storing and retrieving data from a database system utilized by the drilling domain applications.', 'The controller \n130\n may also (or instead) have a vendor-specific IDE (integrated development environment) and/or programming language that may prevent performing the drilling domain applications, and which may also limit portability and/or re-use between rig control systems from different vendors.', 'The controller \n130\n may also (or instead) comprise an operating system that lacks support for advanced computation functions utilized by the drilling domain applications.\n \nFIG.', '1\n also depicts the system \n100\n after the interconnection of the augmenting controller \n140\n.', 'For the sake of clarity, the preexisting system \n100\n with the interconnected augmenting controller \n140\n may be referred to herein as the augmented system \n101\n.', 'The augmenting controller \n140\n augments and/or supports the preexisting control system \n100\n in the form of a PC-based controller that is installed on a preexisting drilling rig comprising the system \n100\n.', 'The augmenting controller \n140\n processes algorithms that are related to drilling domain applications and integrates the drilling domain applications with the preexisting control system \n100\n.\n \nFIG.', '2\n is a schematic view of at least a portion of another example implementation of the augmented system \n101\n shown in \nFIG.', '1\n, designated by reference number \n201\n in \nFIG.', '2\n.', 'The augmented system \n201\n is formed by interconnecting the augmenting controller \n140\n into a preexisting system comprising multiple instances of the actuator \n120\n and multiple instances of the controller \n130\n to provide augmented control of multiple instances of the component \n110\n of the preexisting system.', 'For example, the components \n110\n depicted in \nFIG.', '2\n may include a top drive, a drawworks, one or more mud pumps, a choke valve, and other components of a preexisting drilling rig.', 'Each component \n110\n may be driven by a dedicated VFD and/or other actuator \n120\n in response to control signals communicated from the corresponding controller \n130\n.', 'However, each component \n110\n may also be driven by the augmenting controller \n140\n, including in manners not possible in the preexisting system before the interconnection of the augmenting controller \n140\n.\n \nFIG.', '2\n also demonstrates that the augmenting controller \n140\n may comprise or be connected with a dedicated human-machine interface (HMI) \n145\n.', 'The HMI \n145\n is separate from the one or more HMIs \n150\n of the preexisting drilling rig system.', 'However, introducing the augmenting controller \n140\n into the preexisting drilling rig system may include connecting the augmenting controller \n140\n with the one or more HMIs \n150\n.', 'Thus, the augmenting controller \n140\n may be in communication with the HMI \n145\n, the HMI(s) \n150\n, or both.', 'The introduced HMI \n145\n may be utilized by rig personnel to enter commands that may be communicated to the augmenting controller \n140\n and/or to monitor data and/or other information communicated from the augmenting controller \n140\n.', 'The existing HMI(s) \n150\n may be utilized by rig personnel to enter commands that may be communicated to the preexisting controllers \n130\n and/or to monitor data and/or information communication from the controllers \n130\n.\n \nFIG.', '3\n is a schematic view of at least a portion of another example implementation of the augmented system \n201\n shown in \nFIG.', '2\n, designated by reference number \n301\n in \nFIG.', '3\n.', 'The augmented system \n301\n is formed by interconnecting the augmenting controller \n140\n into a preexisting system comprising multiple instances of the actuator \n120\n but just a single instance of the controller \n130\n to provide augmented control of multiple instances of the component \n110\n of the preexisting system.', 'That is, in the preexisting system, the controller \n130\n was used to control multiple actuators \n120\n and, thereby, multiple components \n110\n.', 'With the introduction of the augmenting controller \n140\n, the multiple actuators \n120\n may instead or also be controlled by the augmenting controller \n140\n.', 'However, in such implementations, the multiple actuators \n120\n may be controlled via different protocols/languages, thus there may be additional connections \n131\n between the preexisting controller \n130\n and the augmenting controller \n140\n, so that it will appear to the preexisting controller \n130\n that it remains connected to the different actuators \n120\n.\n \nFIG.', '4\n is a schematic view of at least a portion of another example implementation of the augmented system \n201\n shown in \nFIG.', '2\n, designated by reference number \n401\n in \nFIG.', '4\n.', 'The augmented system \n401\n is formed by interconnecting the augmenting controller \n140\n into a preexisting system comprising two actuators \n120\n and two controllers \n130\n to provide augmented control of two components \n110\n of the preexisting system.', 'However, while the augmenting controller \n140\n in the system \n201\n shown in \nFIG.', '2\n is connected in series between the controllers \n130\n and the actuators, the augmenting controller \n140\n in the system \n401\n shown in \nFIG.', '4\n is connected to the actuators \n120\n in parallel with the controllers \n130\n.', 'Thus, each controller \n130\n may remain in direct connection and communication with the corresponding actuators \n120\n.', 'In such implementations, the augmenting controller \n140\n may or may not be connected directly to the controllers \n130\n, as indicated in \nFIG.', '4\n by dashed arrows \n132\n.', 'FIG.', '5\n is a schematic view of at least a portion of another example implementation of the augmented system \n401\n shown in \nFIG.', '4\n, designated by reference number \n501\n in \nFIG.', '5\n.', 'The augmented system \n501\n shown in \nFIG.', '5\n is the same as the augmented system \n401\n shown in \nFIG.', '4\n except that the augmented system \n501\n also comprises a gateway or coordinating controller \n160\n.', 'This additional controller \n160\n may be connected to and communicate with each of the preexisting controllers \n130\n.', 'The controller \n160\n may be part of the preexisting system from which the augmented system \n501\n is formed by interconnecting the augmenting controller \n140\n.', 'The controller \n160\n may also connect directly to the augmenting controller \n140\n, as indicated by the dashed line in \nFIG. \n5\n.', 'For example, the direct connection between the controller \n160\n and the augmenting controller \n140\n may be in lieu of the direct connection between the HMI \n150\n and the augmenting controller \n140\n, such that the HMI \n150\n is directly connected to and communicates with the controller \n160\n but no other components.', "In each of the augmented systems described above, as well as others within the scope of the present disclosure, the augmenting controller \n140\n may permit the preexisting drilling rig systems to be utilized with drilling domain applications that aren't available absent the augmenting controller \n140\n.", 'For example, the drilling domain applications may call for processing power and applications beyond the capabilities of a typical PLC (e.g., the controller \n130\n), such as calling pre-build libraries (e.g., dll files) that are compiled using advanced analytical and/or control software, such as MATLAB and/or SIMULINK.', 'Integrating the augmenting controller \n140\n into the preexisting system \n100\n permits the augmenting controller \n140\n to have direct access to the actuator(s) \n120\n in order to deploy improved drilling domain applications that utilize fast deterministic control loops that, for example, run at a minimum update rate of two milliseconds.', 'The augmenting controller \n140\n may be utilized to enhance drilling performance of a drilling rig comprising the augmented system \n101\n via execution of the drilling domain applications deployed on the augmenting controller \n140\n.', 'The augmenting controller \n140\n and the PC-based drilling domain applications may permit execution of real-time control applications.', 'The augmenting controller \n140\n and the PC-based drilling domain applications may also introduce the otherwise missing ability to exchange data between PC-based applications and real-time applications within less than ten milliseconds.', 'The augmenting controller \n140\n and the PC-based drilling domain applications may also introduce the ability to support of a wide range of industrial communication protocols, such as PROFIBUS, PROFINET, CAN bus, ETHERCAT, Ethernet/IP, MODBUS, and/or others.', 'The PC-based applications may be developed using different programing environments, such as C#, C++, JAVA, JAVASCRIPT, MATLAB, PYTHON, and/or others.', 'The real-time applications may be developed using soft PLC platforms, such as CODESYS, TWINCAT, and/or others.', 'The augmenting controller \n140\n may pass through commands from the controller \n130\n to the actuator \n120\n when, for example, the augmenting controller \n140\n is not running a drilling domain application.', 'If a particular rig operation calls for a certain drilling domain application, then the augmenting controller \n140\n can modify communication packets received from the controller \n130\n to implement the drilling domain application algorithm.', 'One or more of the drilling domain applications deployed by the augmenting controller \n140\n may be for stick-slip mitigation and/or controlled drill string oscillation (e.g., for sliding drilling).', 'In such implementations, the actuator \n120\n controlled by the augmenting controller \n140\n may be the VFD that is driving the top drive.', 'Another one or more of the drilling domain applications deployed by the augmenting controller \n140\n may be for auto-tune or adaptive or multi-variable automatic drilling.', 'In such implementations, the actuators \n120\n controlled by the augmenting controller \n140\n may be the VFDs driving the drawworks and the top drive.', 'Another one or more of the drilling domain applications deployed by the augmenting controller \n140\n may be for mud pump synchronization and pressure control.', 'In such implementations, the actuator(s) \n120\n controlled by the augmenting controller \n140\n may be the VFD(s) driving the mud pump(s).', 'Another one or more of the drilling domain applications deployed by the augmenting controller \n140\n may be for managed-pressure drilling.', 'In such implementations, the actuators \n120\n controlled by the augmenting controller \n140\n may the VFDs and/or other actuators driving mud pumps, return valves, choke valves, and the like.', 'The augmenting controller \n140\n may mimic the interfaces between the controller \n130\n and the actuator \n120\n so that, for example, the software and/or hardware configuration of the controller \n130\n need not be modified when interconnecting the augmenting controller \n140\n.', 'Thus, the augmenting controller \n140\n may be agnostic to the controller \n130\n, the actuator \n120\n, or both.', 'Moreover, the augmenting controller \n140\n may be configured to handle each of the different communication interfaces of the controllers and actuators of a typical rig control system, such that the augmenting controller \n140\n may be integrated with the vast majority of preexisting drilling rig control systems.', 'The augmenting controller \n140\n may also provide direct interfaces to other monitoring systems, such as historical databases, data exporters, and other examples.', 'The augmenting controller \n140\n may also provide direct interfaces to other graphical user interfaces (GUIs), such as a control HMI, a calibration tool, a monitoring tool, a commissioning tool, and other examples.', 'This may permit the augmented system to send and receive information directly without having to expand communication channels in the existing control system, including where expanding communication in a preexisting control system is restricted by vendors and operators for security reasons and requires a significant effort.', 'The augmenting controller \n140\n may be considered to have three operational modes.', 'In a first “pass-through” mode, the augmenting controller \n140\n may merely pass through commands from the controller \n130\n to the actuator \n120\n.', 'In a second “advanced-control” mode, the augmenting controller \n140\n may generate and send commands to the actuator \n120\n to perform a drilling domain application not able to be performed by the controller \n130\n.', 'In a third “augmented-control” mode, the augmenting controller \n140\n may augment (e.g., block, change, and/or add to) commands from the controller \n130\n before sending them to the actuator \n120\n.', 'The different operational modes may depend on how the augmenting controller \n140\n is interconnected into the preexisting system.', 'For example, the augmenting controller \n140\n may be interconnected into the preexisting system in a serial configuration, in which the augmenting controller \n140\n is connected between the existing controller \n130\n and the existing actuator \n120\n, such as shown in \nFIGS.', '1\n and \n2\n.', 'In this configuration, the augmenting controller \n140\n may operate in the pass-through mode or the augmented-control mode.', 'For example, in the augmented-control mode of operation with the serial configuration, commands from the controller \n130\n may be augmented by the augmenting controller \n140\n to perform a drilling application and/or other applications that are not very critical in time (e.g., a pipe oscillator application).', 'In a parallel configuration, the controller \n130\n is directly connected to the actuator \n120\n and the augmenting controller \n140\n is connected to the actuator \n120\n using a second communication port on the actuator \n120\n, such as shown in \nFIGS. \n4\n and \n5\n, absent the dashed lines \n132\n.', 'In this configuration, the augmenting controller \n140\n may operate in the advanced-control mode to generate and send control commands to the actuator \n120\n to perform a drilling application not able to be performed in the absence of the augmenting controller \n140\n.', 'In a hybrid configuration, the augmenting controller \n140\n is connected between the controller \n130\n and the actuator \n120\n and is also connected parallelly to the actuator \n120\n using a second communication port.', 'In this configuration, the augmenting controller \n140\n may operate in each of the pass-through, advanced-control, and the augmented-control modes.', 'The augmenting controller \n140\n may implement an internal web interface (e.g., WebUI) and a REST (REpresentational State Transfer) API (application program interface) for the drilling domain applications hosted thereon.', "The controller \n130\n may develop the application screens and interface with the augmenting controller \n140\n using the REST API, or the controller \n130\n may simply host the WebUI within one of the controller \n130\n screens, or a separate HMI may be installed on the rig (e.g., at the driller's chair) for displaying the drilling domain application WebUI.", 'The interface may be done using the HMI software that is running on the HMI \n150\n.', 'However, the interface to the HMI may be provided by passing variables from the HMI \n150\n to the controller \n130\n and then to the augmenting controller \n140\n.\n \nFIG.', '6\n is a schematic view of at least a portion of an example implementation of a processing device \n400\n (or system) according to one or more aspects of the present disclosure.', 'The processing device \n400\n may be or form at least a portion of one or more instances of one or more of the actuator \n120\n, the controller \n130\n, the augmenting controller \n140\n, the HMI \n145\n, the HMI \n150\n, and/or the controller \n160\n described above.', 'The processing device \n400\n may be or comprise, for example, one or more processors, controllers, special-purpose computing devices, PCs (e.g., desktop, laptop, and/or tablet computers), personal digital assistants, smartphones, IPCs, PLCs, servers, internet appliances, and/or other types of computing devices.', 'The processing device \n400\n may comprise a processor \n412\n, such as a general-purpose programmable processor.', 'The processor \n412\n may comprise a local memory \n414\n and may execute machine-readable and executable program code instructions \n432\n (i.e., computer program code) present in the local memory \n414\n and/or another memory device.', 'The processor \n412\n may be, comprise, or be implemented by one or more processors of various types suitable to the local application environment, and may include one or more of general-purpose computers, special-purpose computers, microprocessors, digital signal processors (DSPs), field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), and processors based on a multi-core processor architecture, as non-limiting examples.', 'Examples of the processor \n412\n include one or more INTEL microprocessors, microcontrollers from the ARM and/or PICO families of microcontrollers, and/or embedded soft/hard processors in one or more FPGAs.', 'The processor \n412\n may execute, among other things, the program code instructions \n432\n and/or other instructions and/or programs to implement the example methods and/or operations described herein.', 'The processor \n412\n may be in communication with a main memory \n416\n, such as may include a volatile memory \n418\n and a non-volatile memory \n420\n, perhaps via a bus \n422\n and/or other communication means.', 'The volatile memory \n418\n may be, comprise, or be implemented by random access memory (RAM), static RAM (SRAM), dynamic RAM (DRAM), synchronous DRAM (SDRAM), RAMBUS DRAM (RDRAM), and/or other types of RAM devices.', 'The non-volatile memory \n420\n may be, comprise, or be implemented by read-only memory, flash memory, and/or other types of memory devices.', 'One or more memory controllers (not shown) may control access to the volatile memory \n418\n and/or non-volatile memory \n420\n.', 'The processing device \n400\n may also comprise an interface circuit \n424\n, which is in communication with the processor \n412\n, such as via the bus \n422\n.', 'The interface circuit \n424\n may be, comprise, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third-generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'The interface circuit \n424\n may comprise a graphics driver card.', 'The interface circuit \n424\n may comprise a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).', 'The interface circuit \n424\n can facilitate communications between the processing device \n400\n and one or more devices by utilizing one or more communication protocols, such as an Ethernet-based network protocol (such as ProfiNET, OPC, OPC/UA, Modbus TCP/IP, EtherCAT, UDP multicast, Siemens S7 communication, or the like), a proprietary communication protocol, and/or another communication protocol.', 'One or more input devices \n426\n may also be connected to the interface circuit \n424\n.', 'The input devices \n426\n may permit rig personnel to enter the program code instructions \n432\n, which may be or comprise control data, operational parameters, operational set-points, a well construction plan, and/or a database of operational sequences.', 'The program code instructions \n432\n may further comprise the drilling domain applications described above, as well as other programs operable to perform example methods and/or operations described herein.', 'The input devices \n426\n may be, comprise, or be implemented by a keyboard, a mouse, a joystick, a touchscreen, a track-pad, a trackball, an isopoint, and/or a voice recognition system, among other examples.', 'One or more output devices \n428\n may also be connected to the interface circuit \n424\n.', 'The output devices \n428\n may permit for visualization or other sensory perception of various data, such as sensor data, status data, and/or other example data.', 'The output devices \n428\n may be, comprise, or be implemented by video output devices (e.g., an LCD, an LED display, a CRT display, a touchscreen, etc.), printers, and/or speakers, among other examples.', 'The one or more input devices \n426\n and the one or more output devices \n428\n connected to the interface circuit \n424\n may, at least in part, facilitate the HMIs described herein.', 'The processing device \n400\n may comprise a mass storage device \n430\n for storing data and program code instructions \n432\n.', 'The mass storage device \n430\n may be connected to the processor \n412\n, such as via the bus \n422\n.', 'The mass storage device \n430\n may be or comprise a tangible, non-transitory storage medium, such as a floppy disk drive, a hard disk drive, a compact disk (CD) drive, and/or digital versatile disk (DVD) drive, among other examples.', 'The processing device \n400\n may be communicatively connected with an external storage medium \n434\n via the interface circuit \n424\n.', 'The external storage medium \n434\n may be or comprise a removable storage medium (e.g., a CD or DVD), such as may be operable to store data and program code instructions \n432\n.', 'As described above, the program code instructions \n432\n may be stored in the mass storage device \n430\n, the main memory \n416\n, the local memory \n414\n, and/or the removable storage medium \n434\n.', 'Thus, the processing device \n400\n may be implemented in accordance with hardware (perhaps implemented in one or more chips including an integrated circuit, such as an ASIC), or may be implemented as software or firmware for execution by the processor \n412\n.', 'In the case of firmware or software, the implementation may be provided as a computer program product including a non-transitory, computer-readable medium or storage structure embodying computer program code instructions \n432\n (i.e., software or firmware) thereon for execution by the processor \n412\n.', 'The program code instructions \n432\n may include program instructions or computer program code that, when executed by the processor \n412\n, may perform and/or cause performance of example applications, methods, processes, and/or operations described herein.', 'In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces an apparatus comprising an augmenting controller for augmenting control of an actuator by a component controller, wherein: the actuator is operable to change an operational parameter of a component of a drilling rig; the component controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component; and the augmenting controller is operable to augment the control signals.', 'The control signals may be first control signals and the augmenting controller may be operable to generate and communicate second control signals to the actuator.', 'The second control signals may cause the actuator to perform an operation not able to be caused by the component controller.', 'The component controller may not communicate with the actuator other than through the augmenting controller.', 'The component controller may communicate directly with the actuator.', 'The actuator may be a VFD.', 'The component may be a top drive driven by operation of the VFD, a drawworks driven by operation of the VFD, or a mud pump system driven by operation of the VFD.', 'The component may be a choke.', 'The component controller may be a PLC.', 'In such implementations, among others within the scope of the present disclosure, the augmenting controller may not be a PLC.', 'For example, the augmenting controller may be a PC-based controller.', 'The augmenting controller may process algorithms that are related to drilling domain applications and may integrate the drilling domain applications with the component controller.', 'The component controller may not be able to be programmed to process the algorithms.', 'The component controller may not have sufficient memory and/or processing power to process the algorithms.', 'The augmenting controller may be agnostic to the component controller, the actuator, or both.', 'The drilling domain applications may include an algorithm to mitigate stick-slip occurrence during drilling.', 'In such implementations, among others within the scope of the present disclosure, the actuator may be a VFD and the component is a top drive driven by operation of the VFD.', 'The drilling domain applications may include an algorithm to automatically control drilling.', 'In such implementations, among others within the scope of the present disclosure, the component controller may be a first component controller, the control signals may be first control signals, the actuator may be a first VFD, the component may be a top drive driven by operation of the first VFD, a second VFD may be operable to change an operational parameter of a drawworks of the drilling rig, a second component controller may be configured for communicating second control signals to the second VFD to control the second VFD and thereby control operation of the drawworks, and the augmenting controller may also be operable to augment the second control signals.', 'The present disclosure also introduces a system comprising: an actuator operable to change an operational parameter of a drilling rig component; a first controller configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component; and a second controller connected between the first controller and the actuator and operable to alter the control signals.', 'The first controller may not communicate with the actuator other than through the second controller.', 'The first controller may communicate directly with the actuator.', 'The actuator may be a VFD.', 'In such implementations, among others within the scope of the present disclosure, the component may be a top drive driven by operation of the VFD, a drawworks driven by operation of the VFD, or a mud pump system driven by operation of the VFD.', 'The component may be a choke.', 'The first controller may be a PLC.', 'In such implementations, among others within the scope of the present disclosure, the second controller may not be a PLC.', 'For example, the second controller may be a PC-based controller.', 'The second controller may process algorithms that are related to drilling domain applications and may integrate the drilling domain applications with the first controller, and the first controller may not be able to be programmed to process the algorithms.', 'The first controller may not have sufficient memory and/or processing power to process the algorithms.', 'The second controller may be agnostic to the first controller, the actuator, or both.', 'The drilling domain applications may include an algorithm to mitigate stick-slip occurrence during drilling.', 'In such implementations, among others within the scope of the present disclosure, the actuator may be a VFD and the component may be a top drive driven by operation of the VFD.', 'The drilling domain applications may include an algorithm to automatically control drilling.', 'In such implementations, among others within the scope of the present disclosure, the control signals may be first control signals, the actuator may be a first VFD, the component may be a top drive driven by operation of the first VFD, and the system may further comprise: a second VFD operable to change an operational parameter of a drawworks; and a third controller configured for communicating second control signals to the second VFD to control the second VFD and thereby control operation of the drawworks, wherein the second controller is also connected between the third controller and the second VFD and is operable to alter the second control signals.', 'The first controller may comprise a first processor and a first memory comprising first instructions executed by the first processor.', 'The second controller may comprise a second processor and a second memory comprising second instructions executed by the second processor.', 'The first and second processors may each be separate, unitary processors.', 'The first and second memories may each be separate, unitary memories.', 'The present disclosure also introduces a method comprising: (A) electronically connecting an augmenting controller to an actuator, wherein: (1) the actuator is operable to change an operational parameter of a component of a drilling rig; and (2) a component controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component; and (B) causing operation of the augmenting controller, wherein operation of the augmenting controller comprises augmenting the control signals to thereby augment control of the actuator by the component controller.', 'The control signals may be first control signals and operation of the augmenting controller may further comprise generating and communicating second control signals to the actuator.', 'The second control signals may cause the actuator to perform an operation not able to be caused by the component controller.', 'Operation of the augmenting controller may comprise processing algorithms that are related to drilling domain applications, thereby integrating the drilling domain applications with the component controller.', 'In such implementations, among others within the scope of the present disclosure, the component controller may not be able to be programmed to process the algorithms, and/or the component controller may not have sufficient memory and/or processing power to process the algorithms.', 'Causing operation of the augmenting controller may comprise operating an HMI comprised by or interfaced with the augmenting controller.', 'Operation of the augmenting controller may comprise: receiving the control signals from the component controller and passing the control signals to the actuator without augmenting the control signals; and receiving the control signals from the component controller, augmenting the control signals, and communicating the augmented control signals to the actuator.', 'In such implementations, among others within the scope of the present disclosure, operation of the augmenting controller may further comprise: generating additional control signals independent of the control signals received from the component controller; and communicating the generated additional control signals to the actuator.', 'The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure.', 'A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same functions and/or achieving the same benefits of the embodiments introduced herein.', 'A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.', 'The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. § 1.72(b) to permit the reader to quickly ascertain the nature of the technical disclosure.', 'It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.']

['1.', 'An apparatus comprising:\nan augmenting controller for augmenting control of an actuator by a component controller, wherein: the actuator is operable to change an operational parameter of a component of a drilling rig; the component controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component; and the augmenting controller is operable to augment the control signals.', '2.', 'The apparatus of claim 1 wherein:\nthe control signals are first control signals; and\nthe augmenting controller is operable to generate and communicate second control signals to the actuator.', '3.', 'The apparatus of claim 2 wherein the second control signals cause the actuator to perform an operation not able to be caused by the component controller.', '4.', 'The apparatus of claim 1 wherein the component controller does not communicate with the actuator other than through the augmenting controller.', '5.', 'The apparatus of claim 1 wherein the component controller communicates directly with the actuator.', '6.', 'The apparatus of claim 1 wherein the actuator is a variable frequency drive (VFD).', '7.', 'The apparatus of claim 6 wherein the component is a top drive driven by operation of the VFD.\n\n\n\n\n\n\n8.', 'The apparatus of claim 6 wherein the component is a drawworks driven by operation of the VFD.\n\n\n\n\n\n\n9.', 'The apparatus of claim 6 wherein the component is a mud pump system driven by operation of the VFD.\n\n\n\n\n\n\n10.', 'The apparatus of claim 1 wherein the augmenting controller is a personal computer (PC) based controller.', '11.', 'The apparatus of claim 10 wherein the component controller is a programmable logic controller (PLC).', '12.', 'The apparatus of claim 1 wherein the augmenting controller processes algorithms that are related to drilling domain applications and integrates the drilling domain applications with the component controller.\n\n\n\n\n\n\n13.', 'The apparatus of claim 12 wherein the component controller cannot be programmed to process the algorithms.', '14.', 'The apparatus of claim 12 wherein the component controller does not have sufficient memory and/or processing power to process the algorithms.', '15.', 'A system comprising:\nan actuator operable to change an operational parameter of a drilling rig component;\na first controller configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component; and\na second controller connected between the first controller and the actuator and operable to alter the control signals.', '16.', 'The system of claim 15 wherein:\nthe actuator is a variable frequency drive (VFD);\nthe component is a top drive driven by operation of the VFD, a drawworks driven by operation of the VFD, or a mud pump system driven by operation of the VFD;\nthe first controller is a programmable logic controller (PLC);\nthe second controller is not a PLC;\nthe second controller processes algorithms that are related to drilling domain applications and integrates the drilling domain applications with the first controller; and\nthe first controller: cannot be programmed to process the algorithms; and/or does not have sufficient memory and/or processing power to process the algorithms.', '17.', 'The system of claim 16 wherein:\nthe drilling domain applications include: a first algorithm to mitigate stick-slip occurrence during drilling; and a second algorithm to automatically control drilling;\nthe control signals are first control signals;\nthe actuator is a first VFD;\nthe component is a top drive driven by operation of the first VFD;\nthe system further comprises: a second VFD operable to change an operational parameter of a drawworks; and a third controller configured for communicating second control signals to the second VFD to control the second VFD and thereby control operation of the drawworks; and\nthe second controller is also connected between the third controller and the second VFD and is operable to alter the second control signals.', '18.', 'A method comprising:\nelectronically connecting an augmenting controller to an actuator, wherein: the actuator is operable to change an operational parameter of a component of a drilling rig; and a component controller is configured for communicating control signals to the actuator to control the actuator and thereby control operation of the component; and\ncausing operation of the augmenting controller, wherein operation of the augmenting controller comprises augmenting the control signals to thereby augment control of the actuator by the component controller.', '19.', 'The method of claim 18 wherein operation of the augmenting controller comprises:\nreceiving the control signals from the component controller and passing the control signals to the actuator without augmenting the control signals;\nreceiving the control signals from the component controller, augmenting the control signals, and communicating the augmented control signals to the actuator;\ngenerating additional control signals independent of the control signals received from the component controller; and\ncommunicating the generated additional control signals to the actuator.']

['FIG.', '1 is a schematic view of at least a portion of an example implementation of a system according to one or more aspects of the present disclosure.', '; FIG.', '2 is a schematic view of at least a portion of another example implementation of the system shown in FIG.', '1 according to one or more aspects of the present disclosure.', '; FIG.', '3 is a schematic view of at least a portion of another example implementation of the systems shown in FIGS.', '1 and 2 according to one or more aspects of the present disclosure.', '; FIG.', '4 is a schematic view of at least a portion of another example implementation of the systems shown in FIGS.', '1-3 according to one or more aspects of the present disclosure.', '; FIG.', '5 is a schematic view of at least a portion of another example implementation of the systems shown in FIGS.', '1-4 according to one or more aspects of the present disclosure.', '; FIG.', '6 is a schematic view of at least a portion of an example implementation of a processing system according to one or more aspects of the present disclosure.', '; FIG. 1 is a schematic view of at least a portion of an example implementation of a preexisting system 100 according to one or more aspects introduced by the present disclosure.', 'The system 100 comprises a drilling rig component 110, an actuator 120 in communication with and/or otherwise operable to control operation of the component 110, and a controller 130 in communication with the actuator 120 and operable to communication control signals to the actuator 120.; FIG. 1 also depicts the system 100 after the interconnection of the augmenting controller 140.', 'For the sake of clarity, the preexisting system 100 with the interconnected augmenting controller 140 may be referred to herein as the augmented system 101.; FIG. 2 is a schematic view of at least a portion of another example implementation of the augmented system 101 shown in FIG.', '1, designated by reference number 201 in FIG.', '2.', 'The augmented system 201 is formed by interconnecting the augmenting controller 140 into a preexisting system comprising multiple instances of the actuator', '120 and multiple instances of the controller 130 to provide augmented control of multiple instances of the component 110 of the preexisting system.', 'For example, the components 110 depicted in FIG. 2 may include a top drive, a drawworks, one or more mud pumps, a choke valve, and other components of a preexisting drilling rig.', 'Each component 110 may be driven by a dedicated VFD and/or other actuator 120 in response to control signals communicated from the corresponding controller 130.', 'However, each component 110 may also be driven by the augmenting controller 140, including in manners not possible in the preexisting system before the interconnection of the augmenting controller 140.; FIG. 2 also demonstrates that the augmenting controller 140 may comprise or be connected with a dedicated human-machine interface (HMI) 145.', 'The HMI 145 is separate from the one or more HMIs 150 of the preexisting drilling rig system.', 'However, introducing the augmenting controller 140 into the preexisting drilling rig system may include connecting the augmenting controller 140 with the one or more HMIs 150.', 'Thus, the augmenting controller 140 may be in communication with the HMI 145, the HMI(s) 150, or both.', 'The introduced HMI 145 may be utilized by rig personnel to enter commands that may be communicated to the augmenting controller 140 and/or to monitor data and/or other information communicated from the augmenting controller 140.', 'The existing HMI(s) 150 may be utilized by rig personnel to enter commands that may be communicated to the preexisting controllers 130 and/or to monitor data and/or information communication from the controllers 130.; FIG.', '3 is a schematic view of at least a portion of another example implementation of the augmented system 201 shown in FIG.', '2, designated by reference number 301 in FIG.', '3.', 'The augmented system 301 is formed by interconnecting the augmenting controller 140 into a preexisting system comprising multiple instances of the actuator 120 but just a single instance of the controller 130 to provide augmented control of multiple instances of the component 110 of the preexisting system.', 'That is, in the preexisting system, the controller 130 was used to control multiple actuators 120 and, thereby, multiple components 110.', 'With the introduction of the augmenting controller 140, the multiple actuators 120 may instead or also be controlled by the augmenting controller 140.', 'However, in such implementations, the multiple actuators 120 may be controlled via different protocols/languages, thus there may be additional connections 131 between the preexisting controller 130 and the augmenting controller 140, so that it will appear to the preexisting controller 130 that it remains connected to the different actuators 120.; FIG.', '4 is a schematic view of at least a portion of another example implementation of the augmented system 201 shown in FIG.', '2, designated by reference number 401 in FIG.', '4.', 'The augmented system 401 is formed by interconnecting the augmenting controller 140 into a preexisting system comprising two actuators 120 and two controllers 130 to provide augmented control of two components 110 of the preexisting system.', 'However, while the augmenting controller 140 in the system 201 shown in FIG.', '2 is connected in series between the controllers 130 and the actuators, the augmenting controller 140 in the system 401 shown in FIG.', '4 is connected to the actuators 120 in parallel with the controllers 130.', 'Thus, each controller 130 may remain in direct connection and communication with the corresponding actuators 120.', 'In such implementations, the augmenting controller 140 may or may not be connected directly to the controllers 130, as indicated in FIG.', '4 by dashed arrows 132.;', 'FIG. 5 is a schematic view of at least a portion of another example implementation of the augmented system 401 shown in FIG. 4, designated by reference number 501 in FIG.', '5.', 'The augmented system 501 shown in FIG. 5 is the same as the augmented system 401 shown in FIG.', '4 except that the augmented system 501 also comprises a gateway or coordinating controller 160.', 'This additional controller 160 may be connected to and communicate with each of the preexisting controllers 130.', 'The controller 160 may be part of the preexisting system from which the augmented system 501 is formed by interconnecting the augmenting controller 140.', 'The controller 160 may also connect directly to the augmenting controller 140, as indicated by the dashed line in FIG.', '5.', 'For example, the direct connection between the controller 160 and the augmenting controller 140 may be in lieu of the direct connection between the HMI 150 and the augmenting controller 140, such that the HMI 150 is directly connected to and communicates with the controller 160 but no other components.; FIG.', '6 is a schematic view of at least a portion of an example implementation of a processing device 400 (or system) according to one or more aspects of the present disclosure.', 'The processing device 400 may be or form at least a portion of one or more instances of one or more of the actuator 120, the controller 130, the augmenting controller 140, the HMI 145, the HMI 150, and/or the controller 160 described above.', 'The processing device 400 may be or comprise, for example, one or more processors, controllers, special-purpose computing devices, PCs (e.g., desktop, laptop, and/or tablet computers), personal digital assistants, smartphones, IPCs, PLCs, servers, internet appliances, and/or other types of computing devices.']

US11976519

Ridge shaped element

Mar 1, 2021

Feng Yu, Cheng Peng, Ronald Eyre, Douglas Marsh

Schlumberger Technology Corporation

International Search Report and Written Opinion issued in International Patent application PCT/2021/020274 on Jun. 21, 2021, 8 pages.

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2425950; March 2012; EP; 2018231343; December 2018; WO; 2019128956; July 2019; WO

No images available

['A cutting element includes a substrate and an ultrahard layer on an upper surface of the substrate, a top surface of the ultrahard layer having a ridge extending along a major dimension of the top surface from an edge of the top surface, where the ridge has a peak with at least two different roof radii of curvature, and at least two sidewalls sloping in opposite directions from the peak of the ridge at a roof angle, where a first roof angle of the ridge proximate the edge is smaller than a second roof angle in a central portion of the ridge around a longitudinal axis of the cutting element.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE TO RELATED APPLICATIONS', 'This application is the U.S. national phase of International Patent Application No. PCT/US2021/020274, filed Mar. 1, 2021, which claims the benefit of Provisional Application No. 62/983,883 filed on Mar. 2, 2020, which is hereby incorporated by reference in its entirety.', 'BACKGROUND\n \nDrag bits, often referred to as “fixed cutter drill bits,” include bits that have cutting elements attached to the bit body, which may be a steel bit body or a matrix bit body formed from a matrix material such as tungsten carbide surrounded by a binder material.', 'Drag bits may generally be defined as bits that have no moving parts.', 'Drag bits having cutting elements made of an ultrahard cutting surface layer or “table” (generally made of polycrystalline diamond material or polycrystalline boron nitride material) deposited onto or otherwise bonded to a substrate are known in the art as polycrystalline diamond compact (“PDC”) bits.', 'An example of a drag bit having a plurality of cutting elements with ultrahard working surfaces is shown in \nFIG.', '1\n.', 'The drill bit \n10\n includes a bit body \n11\n having a threaded upper pin end \n12\n and a cutting end \n13\n.', 'The cutting end \n13\n generally includes a plurality of ribs or blades \n14\n arranged about the rotational axis (also referred to as the longitudinal or central axis) of the drill bit and extending radially outward from the bit body \n11\n.', 'Cutting elements, or cutters, \n15\n are embedded in the blades \n14\n at predetermined angular orientations and radial locations relative to a working surface and with a desired back rake angle and side rake angle against a formation to be drilled.', 'The cutters \n15\n are generally cylindrical in shape having an ultrahard material layer attached to a substrate, such as a cemented carbide substrate.', 'The top surface of the ultrahard material layer may be referred to as a working surface, and the edge formed around the top surface may be referred to as the cutting edge, as the working surface and cutting edge of the cutting elements are typically the surfaces that contact and cut a formation.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Some embodiments of the present disclosure relate to cutting elements that include a substrate and an ultrahard layer on an upper surface of the substrate, a top surface of the ultrahard layer having a ridge extending along a major dimension of the top surface from an edge of the top surface, where the ridge may have a peak with at least two different roof radii of curvature, and at least two sidewalls sloping in opposite directions from the peak of the ridge at a roof angle, where a first roof angle of the ridge proximate the edge may be smaller than a second roof angle in a central portion of the ridge around a longitudinal axis of the cutting element.', 'Some embodiments of the present disclosure relate to cutting elements that include a top surface having a ridge extending from an edge of the top surface along a major dimension of the top surface, and a peak of the ridge having a width measured between opposite points of transition from the peak to a sidewall, wherein the width of the peak in a central portion of the ridge around a longitudinal axis of the cutting element may be greater than the width of the peak in the edge portion of the ridge, the edge portion extending a length of the ridge from the edge to the central portion, and wherein the peak may have a roof radius of curvature along an edge portion of the ridge less than 0.1 inches.', 'Some embodiments disclosed herein relate to cutting elements that include a substrate and an ultrahard layer on an upper surface of the substrate, a top surface of the ultrahard layer having a geometric surface axially extended from a plurality of recessed edge portions formed around an edge of the top surface, and at least one ridge extending radially outward from the geometric surface to the edge of the top surface, the at least one ridge having a peak with a roof radius of curvature.', 'Some embodiments disclosed herein relate to methods of forming a cutting element that includes providing a cutting element having a ridge formed at a top surface of the cutting element, the ridge extending along a major dimension of the top surface from an edge of the top surface, wherein the ridge has a peak with a first roof radius of curvature and sidewalls sloping away from the peak at a first roof angle, and removing an amount of ultrahard material from the top surface around an edge portion of the ridge to form a second peak having a second roof radius of curvature smaller than the first roof radius of curvature and recessed sidewalls sloping away from the second peak at a second roof angle smaller than the first roof angle, wherein the edge portion having the second roof radius of curvature and the second roof angle extends a partial length of the ridge from the edge toward a longitudinal axis of the cutting element.', 'Other aspects and advantages will be apparent from the following description and the appended claims.', 'BRIEF DESCRIPTION OF DRAWINGS\n \nFIG.', '1\n is a conventional drill bit.', 'FIGS.', '2\n and \n3\n show side views of a cutting element according to embodiments of the present disclosure.', 'FIG.', '4\n shows an ultrahard layer according to embodiments of the present disclosure.\n \nFIG.', '5\n shows a side view of the ultrahard layer shown in \nFIG.', '4\n.\n \nFIG.', '6\n shows a top view of the ultrahard layer shown in \nFIGS.', '4\n and \n5\n.\n \nFIG.', '7\n shows another side view of the ultrahard layer shown in \nFIGS.', '4\n-\n6\n.\n \nFIG.', '8\n shows a cutting element according to embodiments of the present disclosure.\n \nFIG.', '9\n shows an ultrahard layer according to embodiments of the present disclosure.\n \nFIG.', '10\n shows a top view of the ultrahard layer shown in \nFIG.', '9\n.', 'FIG.', '11\n shows a side view of the ultrahard layer shown in \nFIGS.', '9\n and \n10\n.\n \nFIG.', '12\n shows another side view of the ultrahard layer shown in \nFIGS.', '9\n-\n11\n.\n \nFIG.', '13\n shows an ultrahard layer according to embodiments of the present disclosure.\n \nFIG.', '14\n shows a side view of the ultrahard layer shown in \nFIG. \n13\n.\n \nFIG.', '15\n shows a top view of the ultrahard layer shown in \nFIGS. \n13\n and \n14\n.\n \nFIG.', '16\n shows a cross-sectional view of the ultrahard layer of \nFIGS.', '13\n-\n15\n along a plane intersecting the longitudinal axis of the ultrahard layer and extending through the length of the ridge on the ultrahard layer.\n \nFIG.', '17\n shows another cross-sectional view of the ultrahard layer of \nFIGS.', '13\n-\n16\n along a plane intersecting the longitudinal axis of the ultrahard layer and perpendicular to the length of the ridge on the ultrahard layer.\n \nFIG.', '18\n shows another cross-sectional view of the ultrahard layer of \nFIGS.', '13\n-\n17\n along a plane parallel to the longitudinal axis of the ultrahard layer and perpendicular to the length of the ridge on the ultrahard layer.\n \nFIG.', '19\n shows a top view of a cutting element according to embodiments of the present disclosure.\n \nFIG.', '20\n shows a top view of a cutting element according to embodiments of the present disclosure.\n \nFIG.', '21\n shows a top view of a cutting element according to embodiments of the present disclosure.\n \nFIG.', '22\n shows a top view of a cutting element according to embodiments of the present disclosure.\n \nFIG.', '23\n shows a top view of a cutting element according to embodiments of the present disclosure.\n \nFIG.', '24\n shows a top view of a cutting element according to embodiments of the present disclosure.', 'FIGS.', '25\n-\n28\n show different views of a cutting element according to embodiments of the present disclosure.\n \nFIG.', '29\n shows a graph comparing forces and specific energy during testing of different cutting element types with a cutting element according to embodiments of the present disclosure.', 'FIGS.', '30\n-\n34\n show different views of a cutting element according to embodiments of the present disclosure.\n \nFIG.', '35\n shows a comparison between the contacting area of a planar cutting element with ridge cutting elements at a depth of cut.\n \nFIG.', '36\n shows a graph of the change in contacting area at different depths of cut for the cutting elements shown in \nFIG.', '35\n.', 'FIG.', '37\n shows a schematic of forces acting on a ridge cutting element.\n \nFIG.', '38\n shows a cross-sectional view of a ridge cutting element as it cuts a formation.', 'DETAILED DESCRIPTION\n \nEmbodiments of the present disclosure generally relate to shaped elements (e.g., shaped cutting elements), which may be mounted to drill bits for drilling earthen formations or other cutting tools.', 'The shaped element geometry may include a non-planar top surface, also referred to as a working surface or cutting face, formed on an ultrahard layer of the shaped element.', 'Further, the ultrahard layer of the shaped element may be on a substrate at a non-planar interface surface designed to improve the cutting performance of the non-planar top surface.', 'Shaped elements of the present disclosure may be mounted to various types of downhole tools, including but not limited to, drill bits, such as drag bits, reamers, and other downhole milling tools.', 'The non-planar top surface may have a ridge geometry optimized to improve drilling efficiency and stability.', 'Three parameters of the ridge geometry—roof angle, roof radius of curvature, and roof ridge angle—have been identified as factors in determining the cutting element engagement with a rock formation and torque resistance in the cutting tool.', 'According to embodiments of the present disclosure, roof angle, roof radius of curvature, and roof ridge angle may be designed in combination to provide improved cutting efficiency.', 'FIGS.', '2\n and \n3\n show side views of a cutting element \n100\n according to embodiments of the present disclosure identifying the roof angle \n102\n, roof radius of curvature \n104\n, and roof ridge angle \n106\n of the cutting element ridge geometry.', 'The cutting element \n100\n includes an ultrahard layer \n160\n disposed on a substrate \n162\n at an interface \n164\n, where the non-planar top surface \n110\n geometry is formed on the ultrahard layer \n160\n.', 'The non-planar top surface \n110\n geometry includes a ridge \n120\n extending along a major dimension \n180\n of the top surface between opposite sides of an edge \n114\n surrounding (and defining the bounds of) the top surface \n110\n.', 'The presence of the ridge \n120\n results in an undulating edge \n114\n having raised and recessed portions relative to each other.', 'In the embodiment shown, the ridge \n120\n may extend across the entire diameter of the ultrahard layer \n160\n between two opposite raised portions of the edge \n114\n.', 'A chamfer \n140\n may be formed around the edge \n114\n, or periphery, of the top surface \n110\n, where the chamfer \n140\n extends radially inward from the edge \n114\n of the top surface \n110\n.', 'In some embodiments, the chamfer \n140\n may extend around the entire periphery of the top surface \n110\n.', 'In some embodiments, the chamfer \n140\n may extend partially around the periphery of the top surface \n110\n (i.e., less than the entire periphery of the top surface \n110\n).', 'In one or more embodiments, the chamfer \n140\n may vary in angle and/or width around the edge \n114\n.', 'In some embodiments, a cutting element \n100\n may have a radiused edge \n114\n.', 'As shown, the ridge \n120\n has a peak \n122\n with a convex cross-sectional shape when viewed along a plane perpendicular to the length of the ridge \n120\n along the major dimension \n180\n, where the peak \n122\n has a roof radius of curvature \n104\n.', 'The peak \n122\n of the ridge \n120\n may have a width \n124\n measured between opposite points \n126\n, \n128\n of transition from the peak \n122\n to a sidewall \n130\n.', 'A roof radius of curvature \n104\n may be selected from a range of 0.02 inches to 0.2 inches, depending on, for example, the size of the cutting element \n100\n and the other ridge geometry factors of interest in this disclosure, including the roof angle \n102\n and roof ridge angle \n106\n.', 'Further, according to embodiments of the present disclosure, a roof radius of curvature \n104\n may be varied along the length of the ridge \n120\n.', 'For example, as discussed more below, a first portion of the ridge \n120\n may have a peak \n122\n with a first roof radius of curvature \n104\n, and a second portion of the ridge \n120\n may have a peak \n122\n with a second roof radius of curvature \n104\n that is greater than the first roof radius of curvature \n104\n.', 'While the embodiment shown in \nFIGS. \n2\n and \n3\n has a ridge \n120\n with a convex peak \n122\n, it is also within the scope of the present disclosure that the peak \n122\n may have a plateau or substantially planar face along a portion of the ridge \n120\n.', 'In such embodiment, the peak \n122\n may have a substantially infinite roof radius of curvature \n104\n.', 'Further, planar peak \n122\n portions of a ridge \n120\n may have radiused transitions to the sidewalls \n130\n on either side of the ridge \n120\n.', 'The roof angle \n102\n is the angle defined between the sidewalls \n130\n along a longitudinal plane parallel with the longitudinal axis \n101\n of the cutting element \n100\n and perpendicular to a plane tangent to each sidewall \n130\n.', 'According to embodiments of the present disclosure, a roof angle \n102\n may be selected from a range of about 110 degrees to about 165 degrees, depending on, for example, the size of the cutting element \n100\n and the other ridge geometry factors of interest in this disclosure, including the roof radius of curvature \n104\n and roof ridge angle \n106\n.', 'Further, according to embodiments of the present disclosure, a roof angle \n102\n may be varied along the length of the ridge \n120\n.', 'For example, as discussed more below, a first portion of the ridge \n120\n may have a peak \n122\n with a first roof angle \n102\n, and a second portion of the ridge \n120\n may have a peak \n122\n with a second roof angle \n102\n that is greater than the first roof radius of curvature \n104\n.', 'In embodiments having a chamfer \n140\n formed around the edge \n114\n of the top surface \n110\n, the peak \n122\n of the ridge \n120\n may intersect with an interior boundary \n141\n of the chamfer \n140\n, where the peak \n122\n of the ridge \n120\n may extend from proximate the edge \n114\n of the cutting element \n100\n in a direction toward the longitudinal axis \n101\n.', 'In some embodiments, the peak \n122\n of the ridge \n120\n may extend from the edge \n114\n of the cutting element \n100\n without a chamfer between the edge \n114\n and the peak \n122\n.', 'The ridge \n120\n may be axially separated a height \n125\n from a recessed edge portion \n132\n formed around the edge \n114\n of the top surface \n110\n, where the recessed edge portion \n132\n may be the axially farthest region of the edge \n114\n from the peak \n122\n of the ridge \n120\n.', 'In some embodiments, the height \n125\n of the ridge \n120\n may be uniform along its length, where the entire peak \n122\n extends along a plane \n123\n perpendicular to the longitudinal axis \n101\n.', 'In some embodiments, such as shown in \nFIG. \n3\n, the height \n125\n of the ridge \n120\n may vary.', 'For example, as shown in \nFIG.', '3\n, the height \n125\n of the ridge may increase in a direction from the edge \n114\n toward the longitudinal axis \n101\n, such that the peak \n122\n of the ridge \n120\n has a sloped portion proximate the edge \n114\n of the top surface \n110\n.', 'A roof ridge angle \n106\n is the angle defined between a line \n121\n tangent to the peak \n122\n of the ridge \n120\n proximate the edge \n114\n and a plane \n123\n perpendicular to the longitudinal axis \n101\n.', 'According to embodiments of the present disclosure, a ridge \n120\n may have a roof ridge angle \n106\n selected from a range of zero to about 10 degrees on one or both edge portions of the ridge \n120\n, such that the axial height of the ridge \n120\n at the edge portion of the ridge \n120\n is less the axial height of the ridge \n120\n at the central portion of the ridge \n120\n.', 'According to embodiments of the present disclosure, an edge portion of a ridge may have a roof ridge angle greater than zero in combination with a reduced roof radius of curvature and a reduced roof angle when compared with a central portion of the ridge.', 'Such combination of ridge geometry factors may increase cutting efficiency.', 'For example, as shown in the embodiment of \nFIGS.', '4\n-\n7\n, an ultrahard layer \n200\n may have an edge portion \n221\n of a ridge \n220\n with a roof ridge angle \n206\n greater than zero in combination with a reduced roof radius of curvature \n204\na \nand a reduced roof angle \n202\na \nwhen compared with a central portion \n223\n and/or other portions of the ridge \n220\n along its length \n280\n.', 'In some embodiments, an edge portion \n221\n of a ridge \n220\n may refer to a length \n281\n of the ridge \n220\n measured from the edge \n214\n of the top surface \n210\n that corresponds with a predicted depth of cut of the cutting element during operation.', 'For example, if a predicted depth of cut of a cutting element during operation ranges up to 0.2 inches, a cutting edge portion \n221\n of a ridge \n220\n formed on the top surface \n210\n of the cutting element may refer to the portion of the ridge within 0.2 inches from the edge \n214\n of the top surface \n214\n.', 'In some embodiments, an edge portion \n221\n of a ridge \n220\n may refer to a percentage of the entire length \n280\n of the ridge proximate the edge \n214\n of the top surface \n210\n.', 'For example, an edge portion \n221\n may extend a length \n281\n from the edge \n214\n of the top surface \n210\n that is between 5 and 30 percent of the entire length \n280\n of the ridge \n220\n.\n \nFIGS.', '4\n-\n7\n show the ultrahard layer \n200\n portion of a cutting element, which may be attached to (or formed to) a substrate at a planar or non-planar interface to form the cutting element.', 'For example, in the embodiment shown in \nFIGS.', '4\n-\n7\n, the ultrahard layer \n200\n may have a bottom surface \n207\n that may be attached to an upper surface of a substrate having a geometry corresponding to the bottom surface \n207\n geometry, forming an interface between the ultrahard layer \n200\n and substrate.', 'The geometry of the top surface \n210\n of the cutting element \n200\n may be described with respect to an x-y-z coordinate system, as shown in \nFIG.', '4\n.', 'The ultrahard layer \n200\n has a longitudinal axis \n201\n coinciding with the z-axis extending there through.', 'The non-planar top surface \n210\n formed on the ultrahard layer \n200\n has a geometry formed by varying heights \n250\n along the x-axis and y-axis, wherein the height \n250\n is measured along the z-axis from a common base plane \n205\n through a bottom surface \n207\n of the ultrahard layer \n200\n.', 'As shown in \nFIG. \n5\n, which is a side view in an x-z coordinate plane of the ultrahard layer \n200\n, the peak \n222\n of the ridge \n220\n has the greatest heights \n252\n formed in the top surface \n210\n.', 'As shown in \nFIGS. \n6\n and \n7\n, which show a top view in an x-y coordinate plane and a side view in an y-z coordinate plane, respectively, the ridge \n220\n extends a length \n280\n across the diameter of the ultrahard layer \n200\n along the y-axis between opposite sides of the edge \n214\n of the top surface \n210\n.', 'From the sake of convenience, the y-axis is consistently defined based on the extension direction of the ridge \n220\n; however, one skilled in the art would appreciate that if defined differently, the remaining description based on the x-, y-, z-coordinate system would similarly vary.', 'At least two sidewalls \n230\n, \n232\n slope in opposite directions from the peak \n222\n of the ridge \n220\n at a roof angle \n202\na\n, \n202\nb \n(collectively referred to as \n202\n).', 'First sidewalls \n232\n extend a length along the y-axis from proximate an edge \n214\n of the ultrahard layer \n200\n and slope outwardly from the peak \n222\n in opposite directions along the x-axis.', 'Second sidewalls \n230\n may be adjacent to the first sidewalls \n232\n, extending a length along the y-axis from the first sidewalls \n232\n and sloping outwardly from the peak \n222\n and from a transition \n234\n to the first sidewalls \n232\n in opposite directions along the x-axis.', 'As shown in \nFIG.', '5\n, the slope of the sidewalls \n230\n, \n232\n may be measured along a line \n231\n, \n233\n tangent to the sidewalls \n230\n, \n232\n.', 'In the embodiment shown, the sidewalls \n230\n, \n232\n are substantially planar faces sloping from the peak \n222\n of the ridge \n220\n in a direction toward the edge \n214\n of the top surface \n210\n.', 'The transition between the sidewalls \n230\n, \n232\n and the peak \n222\n may be radiused or angled.', 'The roof angle \n202\n may vary along the length of the ridge \n220\n.', 'For example, different portions along the ridge \n220\n may have different roof angles \n202\na\n, \n202\nb\n.', 'The roof angle \n202\n may gradually transition (e.g., through radiused transitions) between different roof angles \n202\n by differently sloping sidewalls, for example, undulating sidewalls, sloping from the peak \n222\n of the ridge \n220\n at different slopes \n231\n, \n233\n.', 'In the embodiment shown, an edge portion \n221\n of the ridge \n220\n proximate the edge \n214\n may have first sidewalls \n232\n extending from the peak \n222\n of the ridge \n220\n at a first roof angle \n202\na\n, and a central portion \n223\n of the ridge \n220\n around the longitudinal axis \n201\n may have second sidewalls \n230\n extending from the peak \n222\n of the ridge \n220\n at a second roof angle \n202\nb\n, where the first roof angle \n202\na \nis smaller than the second roof angle \n202\nb.', 'The first sidewalls \n232\n sloping from the ridge \n220\n at the first roof angle \n202\na \nmay be recessed from the second sidewalls \n230\n sloping from the ridge \n220\n at the second roof angle \n202\nb\n, where the first sidewalls \n232\n may have a lesser height \n250\n than the second sidewalls \n230\n along the y-dimension at a shared x-position.', 'The first sidewalls \n232\n may transition to the second sidewalls \n230\n through a gradual transition proximate the peak \n222\n, where the first sidewalls \n232\n have a relatively steeper slope \n233\n proximate the edge portion \n221\n of the ridge \n220\n that gets shallower in the direction from the edge portion \n221\n toward the central portion \n223\n until the first sidewalls \n232\n transitions to the second sidewalls \n232\n.', 'The first sidewalls \n232\n may also transition to the second sidewalls \n230\n via one or more transition surfaces, such as landing \n234\n and radiused transitions \n236\n, \n238\n between planar portions of the sidewalls \n230\n, \n232\n.', 'The peak \n222\n may further have a varying roof radius of curvature \n204\na\n, \n204\nb \n(collectively referred to as \n204\n) corresponding to changes in the roof angle \n202\n.', 'For example, in the embodiments shown, the edge portion \n221\n of the ridge \n220\n may have a first roof radius of curvature \n204\na\n, where first sidewalls \n232\n extend at the first roof angle \n202\na \nfrom the peak \n222\n, and the central portion \n223\n of the ridge \n220\n may have a second roof radius of curvature \n204\nb\n, where the second sidewalls \n230\n extend at the second roof angle \n202\nb \nfrom the peak.', 'Both the first roof radius of curvature \n204\na \nand the first roof angle \n202\na \nmay be smaller than the second roof radius of curvature \n204\nb \nand the second roof angle \n202\nb\n.', 'For example, the edge portion \n221\n of the ridge \n220\n may have a peak \n222\n with a first roof radius of curvature \n204\na \nof less than 0.1 inches, e.g., ranging between 0.02 inches and 0.09 inches, and a first roof angle \n202\na \nranging between 110 degrees and 130 degrees, while the central portion \n223\n of the ridge \n220\n may have a peak \n222\n with a second roof radius of curvature \n204\nb \nranging between 0.1 and 0.2 inches and a second roof angle \n202\nb \nranging between 135 degrees and 165 degrees.', 'According to embodiments of the present disclosure, an edge portion \n221\n of a ridge \n220\n may have a peak \n222\n with a first roof radius of curvature \n204\na \nthat is, for example, less than 80 percent (e.g., ranging from 40 to 60 percent) of a second roof radius of curvature \n204\nb \nin a central portion \n223\n of the ridge \n220\n and a first roof angle \n202\na \nthat is, for example, less than 80 percent (e.g., ranging from 40 to 60 percent) of a second roof angle \n202\nb \nin the central portion \n223\n of the ridge \n220\n.', 'A ridge \n220\n may have a peak \n222\n with at least two different roof radii of curvature \n204\n.', 'For example, the peak \n222\n of a ridge \n220\n may have relatively smaller roof radii of curvature \n204\na \nproximate the edges \n214\n of the top surface \n210\n than the roof radius of curvature \n204\nb \nin a central portion \n223\n of the ridge \n220\n.', 'In some embodiments, a ridge \n220\n may have a peak \n222\n with more than three different roof radii of curvature \n204\n.', 'In the embodiment shown, the peak \n222\n has a relatively smaller first roof radius of curvature \n204\na \nat one side of the ridge \n220\n and a relatively larger second roof radius of curvature \n204\nb \nat the opposite side of the ridge \n220\n.', 'Further, the peak \n222\n of the ridge \n220\n may have a continuously increasing height \n250\n along an edge portion \n221\n of the ridge \n220\n in a direction from the edge \n214\n toward the longitudinal axis \n201\n.', 'For example, a ridge \n220\n may have a peak \n222\n having a curvature along the y-axis.', 'A roof ridge angle \n206\n may be defined between a line \n228\n tangent to the peak \n222\n of the ridge \n220\n proximate the edge \n214\n and a plane \n229\n perpendicular to the longitudinal axis \n201\n.', 'The roof ridge angle \n206\n may range from greater than zero to 10 degrees, for example, between 2 and 8 degrees.', 'According to embodiments of the present disclosure, a length of a ridge \n220\n, e.g., an edge portion \n221\n of the ridge \n220\n, having a first roof radius of curvature \n204\na \nand first roof angle \n202\na \nsmaller relative to other portions of the ridge \n220\n may have a roof ridge angle \n206\n greater than zero degrees.', 'In embodiments having a chamfer \n240\n extending around the edge \n214\n of the ultrahard layer \n200\n, an edge portion \n221\n of the ridge \n220\n may include a chamfer \n240\n.', 'In such embodiments, the ridge geometry parameters of the edge portion \n221\n including the roof angle \n202\n, roof ridge angle \n206\n, and roof radius of curvature \n204\n, may describe the geometry of the ridge peak \n222\n and sidewalls \n232\n within the edge portion \n221\n, exclusive of the chamfer \n240\n.', 'In other words, description of ridge geometry parameters of an edge portion \n221\n having a chamfer \n240\n may include the roof angle \n202\n, roof ridge angle \n206\n, and roof radius of curvature \n204\n of the peak \n222\n and sidewalls \n232\n extending from an interior boundary \n241\n of the chamfer \n240\n in the edge portion \n221\n.', 'According to embodiments of the present disclosure, the ridge \n220\n may include one or more concave recesses \n270\n formed along the peak \n222\n of the ridge \n220\n.', 'A concave recess \n270\n may form a concave discontinuous region along the profile of the ridge \n220\n along its length, e.g., as shown in \nFIG. \n7\n.', 'In the embodiment shown, the ridge \n220\n may have one concave recess \n270\n.', 'In other embodiments, a ridge \n220\n may have more than one concave recess \n270\n.', 'In some embodiments, a ridge \n220\n may have no concave recesses \n270\n.', 'Further, the concave recess \n270\n may have a tear-drop shape when viewed from a top perspective (as shown in \nFIG. \n6\n), where the wider part of the tear-drop is proximate the edge portion \n221\n and the narrower/sharper part of the tear-drop is proximate the central portion \n223\n of the ridge \n220\n.', 'According to embodiments of the present disclosure, a ridge \n220\n may have a peak \n222\n with a varying width \n225\na\n, \n225\nb \n(collectively referred to as \n225\n) measured between opposite points of transition from the peak \n222\n to the sidewall \n230\n, \n232\n.', 'For example, the peak \n222\n in the edge portion \n221\n of the ridge \n220\n may have a first width \n225\na\n, and the peak \n222\n in a remaining portion of the ridge \n220\n, e.g., the central portion \n223\n of the ridge \n220\n, may have a second width \n225\nb \nthat is greater than the first width \n225\na.', 'In the embodiment shown in \nFIGS.', '4\n-\n7\n, one edge portion \n221\n of a ridge \n220\n is modified to have, e.g., a relatively smaller roof angle \n202\na \nthan a central portion \n223\n, a relatively smaller roof radius of curvature \n204\na \nthan the central portion \n223\n, a relatively smaller width \n225\na \nthan the central portion \n223\n, and a roof ridge angle \n206\n, and one concave recess \n270\n is formed in the ridge \n220\n radially from the edge portion \n221\n.', 'In some embodiments, both ends of a ridge \n220\n may be modified to have at least one of a relatively smaller roof angle \n202\na \nthan a central portion \n223\n, a relatively smaller roof radius of curvature \n204\na \nthan the central portion \n223\n, a relatively smaller width \n225\na \nthan the central portion \n223\n, and a roof ridge angle \n206\n.', 'Further, in some embodiments, more than one concave recess \n270\n may be formed along the ridge \n220\n.', 'For example, \nFIG.', '8\n shows an embodiment of a cutting element \n290\n having a modified edge portion \n221\n on each end of the ridge \n220\n.', 'Each edge portion \n221\n may have at least one of a relatively smaller roof angle \n202\na \nthan a central portion \n223\n of the ridge \n220\n, a relatively smaller roof radius of curvature \n204\na \nthan the central portion \n223\n of the ridge \n220\n, a relatively smaller width \n225\na \nthan the central portion \n223\n of the ridge \n220\n, and a roof ridge angle \n206\n.', 'Further, two concave recesses \n270\n are formed along the ridge \n220\n, each concave recess \n270\n located radially between an edge portion \n221\n and the central portion \n223\n.', 'The ridge geometry may be symmetrical about a line \n285\n extending along a major dimension of the top surface \n210\n and through the longitudinal axis \n201\n of the cutting element \n290\n.', 'By providing symmetrical edge portions \n221\n of a ridge \n220\n, the cutting element \n290\n may be used in two cutting positions.', 'For example, the cutting element \n290\n may be positioned in a cutting tool in a first orientation where a first edge portion \n221\n is oriented to contact and cut a formation during operation.', 'The cutting element \n290\n may further be positioned in a cutting tool in a second orientation (e.g., if the first edge portion \n221\n wears or fails from use) where the second edge portion \n221\n is oriented to contact and cut a formation during operation.', 'In some embodiments, a ridge \n220\n may have two different edge portion \n221\n geometries, which may allow for a single cutting element \n200\n to have two cutting efficiency options.', 'For example, a cutting element \n200\n may have a first edge portion \n221\n extending a first length from an edge \n214\n of the cutting element \n200\n and a second edge portion \n221\n extending a second length from an opposite side of the edge \n214\n, where both the first and second edge portions \n221\n may have at least two of a relatively smaller roof angle \n202\na \nthan a central portion \n223\n of the ridge \n220\n, a relatively smaller roof radius of curvature \n204\na \nthan the central portion \n223\n of the ridge \n220\n, a relatively smaller width \n225\na \nthan the central portion \n223\n of the ridge \n220\n, and a roof ridge angle \n206\n.', 'At least one geometry parameter in the first edge portion \n221\n may be different than the second edge portion \n221\n.', 'For example, the first length of the first edge portion \n221\n may be different from the second length of the second edge portion \n221\n, which may be selected, for example, based on different expected depths of cut.', 'FIGS.', '9\n-\n12\n show another example of an ultrahard layer \n300\n according to embodiments of the present disclosure. \nFIG.', '9\n is a perspective view, \nFIG.', '10\n is a top view, and \nFIGS.', '11\n and \n12\n are side views of the ultrahard layer \n300\n.', 'The ultrahard layer \n300\n has a top surface \n310\n and a bottom surface \n307\n opposite the top surface, where a thickness \n350\n of the ultrahard layer \n300\n is measured axially between the top surface \n310\n and bottom surface \n307\n of the ultrahard layer \n300\n.', 'The top surface \n310\n of the ultrahard layer \n300\n has a ridge \n320\n geometry, which includes a ridge \n320\n extending a length \n380\n across the major dimension (e.g., diameter) of the top surface \n310\n.', 'The top surface \n310\n may also include a chamfer \n340\n formed around the edge \n314\n of the top surface \n310\n, where the chamfer \n340\n extends radially inward from the edge \n314\n to an interior boundary \n341\n of the chamfer \n340\n.', 'The ridge \n320\n includes a peak \n322\n extending linearly between opposite sides of the edge \n314\n and sidewalls \n330\n, \n332\n extending from the peak \n322\n toward the edge \n314\n.', 'In embodiments having a chamfer \n340\n formed around the entire edge \n314\n, the peak \n322\n may extend to and meet with opposite sides of the interior boundary \n341\n of the chamfer \n340\n.', 'The ridge \n320\n may further include an edge portion \n321\n extending a length \n381\n from the edge \n314\n of the top surface \n310\n that has at least one of a roof ridge angle \n306\n, reduced roof angle \n302\n, and a reduced roof radius of curvature \n304\n when compared with a remaining portion \n323\n of the ridge \n320\n.', 'In the embodiment shown in \nFIGS.', '9\n-\n12\n, the edge portion \n321\n of the ridge may extend a length \n381\n that is between 25 and 45 percent of the entire length \n380\n of the ridge \n320\n.', 'The edge portion \n321\n of the ridge \n320\n may have a first roof angle \n302\na \nmeasured between oppositely sloping first sidewalls \n332\n from the peak \n322\n, and the remaining portion \n323\n of the ridge \n320\n may have a second roof angle \n302\nb \nmeasured between oppositely sloping second sidewalls \n330\n.', 'The first sidewalls \n332\n may appear to be scooped or recessed from the adjacent second sidewalls \n330\n, such that the first sidewalls \n332\n extend from the peak \n322\n at a steeper slope relative the longitudinal axis \n301\n of the ultrahard layer than the second sidewalls \n330\n, and thus, the first roof angle \n302\na \nis smaller than the second roof angle \n302\nb\n.', 'In embodiments having a convex and/or concave cross sectional profile of a sidewall, such as shown in \nFIG. \n12\n, where first sidewalls \n332\n have a concave cross-sectional profile and second sidewalls \n330\n have a convex cross-sectional profile, the slope of the sidewalls \n330\n, \n332\n may be measured along a line \n331\na\n, \n331\nb \ntangent to the portion of the sidewalls \n330\n, \n332\n extending from a point \n326\n of transition from the peak \n322\n to the sidewalls \n330\n, \n332\n.', 'The edge portion \n321\n of the ridge \n320\n may also have a first roof radius of curvature \n304\na \nthat is smaller than a second roof radius of curvature \n304\nb \nof the remaining portion \n323\n of the ridge \n320\n.', 'For example, the first roof radius of curvature \n304\na \nmay be less than 80 percent, less than 60 percent, less than 50 percent, or less than 40 percent of the second roof radius of curvature \n304\nb.', 'As shown in \nFIG. \n11\n, the ridge \n320\n geometry may further include a first roof ridge angle \n306\na \nformed along the peak \n322\n in the edge portion \n321\n of the ridge \n320\n.', 'The first roof ridge angle \n306\na \nmay be formed between a plane \n329\n perpendicular to the longitudinal axis \n301\n and a line \n328\na \nextending along the peak \n322\n from a point where the peak \n322\n meets the interior boundary \n341\n of the chamfer \n340\n (or the edge \n314\n in embodiments without a chamfer \n340\n) to a point \n327\n where the peak \n322\n transitions to being parallel with the plane \n329\n.', 'The peak \n322\n in the edge portion \n321\n of the ridge \n320\n may have a concave cross-sectional profile when viewed along a profile intersecting the longitudinal axis \n301\n and extending through the length \n312\n of the ridge \n320\n.', 'According to embodiments of the present disclosure, the first roof ridge angle \n306\na \nmay be selected from a range of zero to about 10 degrees.', 'A second roof ridge angle \n306\nb \nmay be formed along the peak \n322\n at the edge \n314\n opposite the edge portion \n321\n.', 'The portion of the peak \n322\n proximate the edge \n314\n and defining a second roof ridge angle \n306\nb \nmay have substantially planar cross-sectional profile when viewed along the profile intersecting the longitudinal axis \n301\n and extending through the length \n312\n of the ridge \n320\n.', 'In such case, the second roof ridge angle \n306\nb \nmay be measured between a line \n328\nb \ntangent to the peak \n322\n of the ridge \n320\n proximate the edge \n314\n and the plane \n329\n perpendicular to the longitudinal axis \n301\n.', 'According to embodiments of the present disclosure, the second roof ridge angle \n306\nb \nmay be selected from a range of zero to about 10 degrees.', 'The second roof ridge angle \n306\nb \nmay be less than, greater than, or equal to the first roof ridge angle \n306\na. \n \nFIGS.', '13\n-\n18\n show another example of an ultrahard layer \n400\n according to embodiments of the present disclosure.', 'FIG.', '13\n is a perspective view of the ultrahard layer \n400\n.', 'FIG.', '14\n is a side view of the ultrahard layer \n400\n.', 'FIG.', '15\n is a schematic of a top view of the ultrahard layer \n400\n (looking at the top surface \n410\n of the ultrahard layer \n400\n).', 'FIGS.', '16\n-\n18\n are cross-sectional views of the ultrahard layer \n400\n taken along cross-sections A-A, B-B, and C-C, respectively, shown in \nFIG.', '15\n.', 'The ultrahard layer \n400\n has a non-planar top surface \n410\n with ridge \n420\n geometry and a non-planar bottom surface \n407\n opposite the top surface \n410\n.', 'The ridge \n420\n geometry includes a ridge \n420\n extending linearly along a major dimension \n480\n of the ultrahard layer \n400\n between opposite sides of an edge \n414\n of the ultrahard layer \n400\n.', 'The ultrahard layer \n400\n may have a cylindrical side surface \n403\n, where the major dimension \n480\n of the ultrahard layer \n400\n is a diameter \n480\n of the cylindrical side surface \n403\n.', 'In other embodiments, the side surface(s) \n403\n of an ultrahard layer may define non-circular cross-sectional shapes along a cross-section perpendicular to the longitudinal axis \n401\n, such as oblong, elliptical, or polygonal cross-sectional shapes.', 'The non-planar bottom surface \n407\n of the ultrahard layer \n400\n may be attached to (or formed to) an upper surface of a substrate having a geometry corresponding to the bottom surface \n407\n geometry, forming a non-planar interface between the ultrahard layer \n400\n and substrate.', 'In the embodiment shown, the geometry of the bottom surface \n407\n includes one or more protrusions \n408\n formed at circumferential positions around the perimeter of the bottom surface \n407\n, for example, at opposite sides of a diameter \n480\n of the ultrahard layer \n400\n.', 'In some embodiments, one or more protrusions \n408\n may be formed at a circumferential position around the ultrahard layer \n400\n that corresponds with an edge portion \n421\n of a ridge \n420\n formed on the top surface \n410\n.', 'For example, as shown in \nFIGS. \n13\n and \n14\n, protrusions \n408\n may be formed on the bottom surface \n407\n at circumferential positions opposite edge portions \n421\n of the ridge \n420\n.', 'The ultrahard layer \n400\n may be attached or formed to a substrate having an upper surface with a corresponding geometry to the bottom surface \n407\n of the ultrahard layer \n400\n, e.g., one or more recessed portions having a corresponding shape to one or more protrusions \n408\n formed on the bottom surface \n407\n of the ultrahard layer \n400\n.', 'A thickness \n450\n of the ultrahard layer \n400\n is measured axially between the top surface \n410\n and bottom surface \n407\n of the ultrahard layer \n400\n.', 'According to embodiments of the present disclosure, the ultrahard layer \n400\n may have a combination top surface \n410\n geometry and bottom surface \n407\n geometry to provide the ultrahard layer \n400\n with the greatest thickness \n456\n at the edge portions \n421\n of the ridge \n420\n relative to the remaining areas of the ultrahard layer \n400\n.', 'The ridge \n420\n geometry of the top surface \n410\n includes a peak \n422\n of the ridge \n420\n and sidewalls \n430\n extending outwardly from the peak \n422\n to an interior boundary \n441\n of a chamfer \n440\n formed around the edge \n414\n of the top surface \n410\n (or in embodiments without a chamfer \n440\n, extending to the edge \n414\n of the top surface \n410\n).', 'The peak \n422\n may have a width \n425\n measured between opposite points \n426\n of transition from the peak \n422\n to a sidewall \n430\n.', 'The transition from the peak \n422\n to a sidewall \n430\n may be angled or radiused.', 'The width \n425\n of the peak \n422\n may vary along the length \n480\n of the ridge \n420\n.', 'For example, the peak \n422\n in the edge portions \n421\n of the ridge \n420\n may have a first width \n425\na\n, and the portion of the peak \n422\n extending between the opposite edge portions \n421\n (e.g., including a central portion \n423\n around the longitudinal axis \n401\n of the ultrahard layer) may have a second width \n425\nb \ngreater than the first width \n425\na.', 'According to embodiments of the present disclosure, the first width \n425\na \nof a peak \n422\n in an edge portion \n421\n of a ridge \n420\n may be, for example, between 20 percent to 80 percent less than the second width \n425\nb \nof the peak \n422\n in the central portion \n423\n of the ridge \n420\n.', 'For example, in the embodiment shown, the peak \n422\n in the edge portions \n421\n of the ridge \n420\n may have a first width \n425\na \nranging between 20 percent to 50 percent less than the second width \n425\nb \nof the portion of the peak \n422\n extending between the edge portions \n421\n.', 'The width values may vary depending on the overall size of the ultrahard layer \n400\n and the other dimensions of the ridge geometry, such as the ridge height \n460\n, roof angle \n402\n, roof radius of curvature \n404\n, and roof ridge angle (e.g., \n206\n).', 'In some embodiments, a first width \n425\na \nof the peak \n422\n in the edge portions \n421\n may range, for example, between 0.02 inches to 0.05 inches, or between 0.03 inches to 0.06 inches, and the second width \n425\nb \nof the portion of the peak \n422\n extending between the edge portions \n421\n may range, for example, between 0.04 inches to 0.08 inches, or between 0.05 inches to 0.1 inch.', 'The roof radius of curvature \n404\n is a measurement of the curvature of the peak \n422\n and may vary along the length \n480\n of the ridge \n420\n.', 'For example, in the embodiment shown in \nFIGS.', '13\n-\n18\n, the peak \n422\n may have a first roof radius of curvature \n404\na \nin the edge portions \n421\n of the ridge \n420\n and a second roof radius of curvature \n404\nb \nin the central portion \n423\n of the ridge \n420\n, where the second roof radius of curvature \n404\nb \nis greater than the first roof radius of curvature \n404\na\n.', 'According to embodiments of the present disclosure, the roof radius of curvature \n404\n of a peak \n422\n in edge portion(s) \n421\n of a ridge \n420\n may be smaller than the roof radius of curvature \n404\n of the peak \n422\n in portions of the ridge \n420\n interior to and adjacent to the edge portion(s) \n421\n.', 'For example, the first roof radius of curvature \n404\na \nof the peak \n422\n in the edge portions \n421\n of a ridge \n420\n may range from about 20 percent to 60 percent less than the roof radius of curvature \n404\n of a portion of the ridge \n420\n adjacent to and interior to the edge portions \n421\n.', 'In some embodiments, the first roof radius of curvature \n404\na \nof the peak \n422\n in an edge portion \n421\n of a ridge \n420\n may vary along the length of the edge portion \n421\n and/or the roof radius of curvature \n404\n may vary along the remaining portion of the ridge \n420\n, where the greatest value of the first roof radius of curvature \n404\na \nmay be less than the roof radius or radii of curvature \n404\n along the remaining portion of the ridge \n420\n.', 'For example, the first roof radius of curvature \n404\na \nof the peak \n422\n in the edge portions \n421\n of a ridge \n420\n may be less than 0.1 inches, e.g., ranging from a lower limit of 0.02 inches, 0.04 inches, or 0.06 inches to an upper limit of 0.05 inches, 0.08 inches, or 0.09 inches, and a portion of the ridge \n420\n adjacent to and interior to the edge portions \n421\n may have a roof radius of curvature that is 0.1 inches or greater, e.g., ranging from a lower limit of 0.1 inches, 0.14 inches, or 0.15 inches to an upper limit of 0.15 inches, 0.2 inches, or 0.25 inches.', 'In some embodiments, at least a portion of the ridge \n420\n extending between the edge portions \n421\n may have a peak \n422\n with a planar surface, in which case the radius of curvature \n404\n of the planar surface portion of the peak \n422\n would be infinity.', 'The ridge \n420\n may further have a roof angle \n402\n measured between oppositely sloping sidewalls \n430\n from the peak \n422\n.', 'The slope of a sidewall \n430\n may be measured along a line \n431\n extending from an interior boundary \n441\n of a chamfer \n440\n (or from the edge \n414\n in embodiments without a chamfer \n440\n) to a point \n426\n of transition from the peak \n422\n to the sidewall \n430\n.', 'In embodiments having planar sidewalls \n430\n, the line \n431\n may be tangent to the sidewall \n430\n surface.', 'According to embodiments of the present disclosure, the roof angle \n402\n may vary along the length \n480\n of the ridge \n420\n.', 'For example, in the embodiment shown in \nFIGS.', '13\n-\n18\n, the edge portions \n421\n of the ridge \n420\n may have a first roof angle \n402\na \nsmaller than a second roof angle \n402\nb \nalong a central portion \n423\n of the ridge \n420\n.', 'As shown in \nFIG. \n17\n which is a cross-sectional view of the ultrahard layer \n400\n taken at plane B-B from \nFIG. \n15\n through the central portion \n423\n of the ridge \n420\n, the second roof angle \n402\nb \nis measured between the lines \n431\nb \ntangent to the sidewalls \n430\n extending laterally from the peak \n422\n toward the edge \n414\n of the ultrahard layer \n400\n.', 'As shown in \nFIG.', '18\n, which is a cross-sectional view of the ultrahard layer \n400\n taken at plane C-C from \nFIG.', '15\n through an edge portion \n421\n of the ridge \n420\n, the first roof angle \n402\na \nis measured between the lines \n431\na \ntangent to the sidewalls \n430\n extending laterally from the peak \n422\n toward the edge \n414\n of the ultrahard layer \n400\n.', 'According to embodiments of the present disclosure, a first roof angle \n402\na \nof an edge portion \n421\n of a ridge \n420\n may be less than 145 degrees, for example, ranging between 100 degrees and 145 degrees.', 'The sidewalls \n430\n on opposite sides of the peak \n422\n in the portion of the ridge \n420\n between the edge portions \n421\n (including central portion \n423\n) may extend from the peak \n422\n at a second roof angle greater than 135 degrees, for example, ranging between 140 degrees and 170 degrees.', 'The sidewalls \n430\n may transition from sloping at the first roof angle \n402\na \nfrom the peak \n422\n to sloping at the second roof angle \n402\nb \nfrom the peak \n422\n along a radiused or curved transition \n424\n along the peak \n422\n.', 'Further, the transition between the sidewalls sloping at the first roof angle \n402\na \n(represented by tangent line slope \n431\na\n) and the sidewalls sloping at the second roof angle \n402\nb \n(represented by tangent line slope \n431\nb\n) may be gradual, such that there is a continuously changing slope between the first slope \n431\na \nand the second slope \n431\nb.', 'The ridge \n420\n may have a ridge height \n460\n measured axially from a lowest portion \n462\n of the edge \n414\n to the ridge peak \n422\n.', 'According to embodiments of the present disclosure, the ridge height \n460\n may range, for example, from a lower limit of 0.05 inches, 0.08 inches, or 0.1 inch to an upper limit of 0.07 inches, 0.1 inch, 0.15 inches, or 0.2 inches.', 'In some embodiments, the ridge height \n460\n may vary along the length \n480\n of the ridge \n420\n.', 'For example, in embodiments where the peak \n422\n of the ridge \n420\n slopes at a roof ridge angle (e.g., \n206\n in \nFIG. \n7\n), the ridge height \n460\n may continuously change along the sloping portion of the ridge \n420\n.', 'In embodiments having one or more concave recesses (e.g., \n270\n in \nFIG. \n6\n), the ridge height \n460\n may vary between the peak \n422\n and the concave recess(es).', 'In embodiments such as shown in \nFIGS.', '13\n-\n18\n having a ridge \n420\n with a roof ridge angle of zero and no concave recesses, the peak \n422\n may be at a uniform ridge height \n460\n along the entire length \n480\n of the ridge \n420\n.', 'According to embodiments of the present disclosure, the length \n481\n of an edge portion \n421\n, as measured by a radial distance from the edge \n414\n of the top surface \n410\n toward the longitudinal axis \n401\n, may be designed to be greater than or equal to a predicted depth of cut when the cutting element is cutting.', 'For example, in some embodiments, the length \n481\n of the edge portion \n421\n may range from about 0.07 inches to 0.3 inches.', 'In embodiments having a chamfer \n440\n formed around the edge \n414\n, the peak \n422\n of the ridge \n420\n within the edge portion \n421\n may extend radially inward from an interior boundary \n441\n of the chamfer \n440\n.', 'A chamfer may extend a radial distance \n442\n between the edge \n414\n of the ultrahard layer \n400\n to the interior boundary \n441\n of the chamfer \n440\n ranging, for example, from about 0.01 inches to about 0.03 inches.', 'Further, a chamfer may have a slope \n443\n with respect to the longitudinal axis \n401\n ranging from, for example, about 40 degrees to about 50 degrees or 15 degrees to 70 degrees.', 'The geometry of the ridge \n420\n in an edge portion \n421\n may include a peak \n422\n having a reduced roof angle \n402\n and a reduced roof radius of curvature \n404\n relative to a central portion \n423\n of the ridge.', 'Further, ridge \n420\n geometry may include opposite ends of the ridge \n420\n (two edge portions \n421\n) having a peak width \n425\na \nthat is less than the peak width \n425\nb \nin a central portion \n423\n of the ridge \n420\n.', 'Such ridge geometry may provide edge portion(s) \n421\n having a relatively reduced contacting area (i.e., the area of the top surface \n410\n and side surface \n403\n of the edge portion \n421\n that contacts a formation during operation), which may reduce the workload of the cutting element when cutting.', 'Ridge geometry may vary while still providing edge portion(s) of the ridge having at least one of a reduced roof angle, a reduced roof radius of curvature, and a reduced peak width relative to a central portion of the ridge.', 'For example, \nFIGS.', '19\n-\n24\n show additional examples of cutting elements having a ridge geometry according embodiments to the present disclosure, where the edge portion(s) of the ridge have at least one of a reduced roof angle, a reduced roof radius of curvature, and a reduced peak width relative to a central portion of the ridge.', 'FIGS.', '19\n-\n21\n show top views of cutting elements \n500\n, \n510\n, \n520\n having ridge \n501\n, \n511\n, \n521\n geometries that include edge portions \n502\n, \n512\n, \n522\n having a reduced peak width \n505\n, \n515\n, \n525\n relative to a central portion \n503\n, \n513\n, \n523\n of the ridge \n501\n, \n511\n, \n521\n.', 'As shown in \nFIG. \n19\n, the ridge \n501\n extends linearly across a major dimension of the top surface \n504\n, where edge portions \n502\n of the ridge \n501\n are at opposite ends of the ridge \n501\n.', 'A central portion \n503\n of the ridge \n501\n extending between the two edge portions \n502\n has a peak width \n505\n that is greater than the peak width \n505\n along the edge portions \n502\n.', 'The peak width \n505\n is measured between opposite points \n507\n of transition from the peak \n506\n of the ridge \n501\n to the sidewalls \n508\n extending outwardly from the peak \n506\n toward an edge \n509\n of the top surface \n504\n.', 'The central portion \n503\n of the ridge \n501\n may have a peak \n506\n with a planar surface having a polygonal shape, which is a diamond-shaped in the embodiment shown in \nFIG. \n19\n.', 'The planar surface portion of the peak \n506\n (in the central portion \n503\n of the ridge \n501\n) may have its planar surface extending along a plane (e.g., plane \n329\n in \nFIG.', '11\n) perpendicular to the longitudinal axis (e.g., \n301\n in \nFIG.', '11\n) of the cutting element.', 'The transitions \n507\n from the planar surface of the peak \n506\n in the central portion \n503\n to the sidewalls \n508\n of the ridge \n501\n may be curved or radiused.', 'Further, the peak \n506\n may be a curved surface along the edge portions \n502\n of the ridge \n501\n, where the curved surface peak \n506\n portions may have a roof radius of curvature (e.g., \n404\na\n, \n404\nb \nin \nFIG.', '13\n) ranging from, for example, less than 0.1 inches.', 'FIG.', '20\n shows another example of a cutting element \n510\n with a ridge \n511\n geometry having a central portion \n513\n of the ridge \n511\n with a peak \n516\n having a polygonal shape.', 'The ridge \n511\n extends linearly across a major dimension of the top surface \n514\n, where edge portions \n512\n of the ridge \n511\n extend inwardly from opposite sides of the edge \n519\n of the top surface \n514\n to a central portion \n513\n of the ridge \n511\n.', 'The width \n515\n of the peak \n516\n in the central portion \n513\n is greater than the width \n515\n of the peak \n516\n along the edge portions \n512\n.', 'The peak width \n515\n is measured between opposite points \n517\n of transition from the peak \n516\n of the ridge \n511\n to the sidewalls \n518\n extending outwardly from the peak \n516\n toward the edge \n519\n of the top surface \n514\n.\n \nFIG.', '21\n shows an example of a cutting element \n520\n with a ridge \n521\n geometry having a central portion \n523\n of the ridge \n521\n with an oval-shaped peak \n526\n surface.', 'The ridge \n521\n extends linearly across a major dimension of the top surface \n524\n, where edge portions \n522\n of the ridge \n521\n extend inwardly from opposite sides of the edge \n529\n of the top surface \n524\n to the central portion \n523\n of the ridge \n521\n.', 'The width \n525\n of the peak \n526\n in the central portion \n523\n is greater than the width \n525\n of the peak \n526\n along the edge portions \n522\n.', 'The oval-shaped portion of the peak \n526\n may have a planar surface, while the peak \n526\n in the edge portions \n522\n may have a curved surface with a radius of curvature (e.g., \n404\na\n, \n404\nb \nin \nFIG.', '13\n) ranging from, for example, less than 0.1 inches.', 'According to some embodiments of the present disclosure, the width \n525\n of the peak \n526\n in the central portion \n523\n of the ridge \n521\n may be up to 2 times greater than the width \n525\n at the edge portion \n522\n, up to 3 times greater than the width \n525\n at the edge portion \n522\n, or more.', 'In some embodiments, the width of a peak in the central portion of the ridge may extend greater than 20 percent of the major dimension, greater than 50 percent of the major dimension, or up to the entire major dimension.', 'FIGS.', '22\n-\n24\n show top views of cutting elements \n600\n, \n610\n, \n620\n having ridge geometry that includes a central portion \n603\n, \n613\n, \n623\n of the ridge \n601\n, \n611\n, \n621\n that extends to opposite sides of the edge \n609\n, \n619\n, \n629\n of the top surface \n604\n, \n614\n, \n624\n, across a major dimension of the top surface \n604\n, \n614\n, \n624\n.', 'The edge portions \n602\n, \n612\n, \n622\n of the ridge \n601\n, \n611\n, \n621\n have a reduced peak width \n605\n, \n615\n, \n625\n relative to the central portion \n603\n, \n613\n, \n623\n of the ridge \n601\n, \n611\n, \n621\n.', 'Described another way, the cutting element \n600\n, \n610\n, \n620\n ridge geometry may include a geometric surface \n606\n, \n616\n, \n626\n axially extended from a plurality of recessed edge portions \n607\n, \n617\n, \n627\n formed around the edge \n609\n, \n619\n, \n629\n of the top surface \n604\n, \n614\n, \n624\n.', 'At least one ridge \n601\n, \n611\n, \n621\n extends radially outward from the geometric surface \n606\n, \n616\n, \n626\n to the edge \n609\n, \n619\n, \n629\n of the top surface \n604\n, \n614\n, \n624\n.', 'Sidewalls may slope downwardly from the geometric surface \n606\n, \n616\n, \n626\n and ridge \n601\n, \n611\n, \n621\n to the recessed edge portions \n607\n, \n617\n, \n627\n.', 'As shown in \nFIG.', '22\n, the ridge geometry includes a geometric surface \n606\n axially extended from multiple recessed edge portions \n607\n formed around the edge \n609\n of the top surface \n604\n, where the geometric surface \n606\n has a polygonal shape.', 'The ridges \n601\n may have a curved peak \n608\n with a roof radius of curvature, and the geometric surface \n606\n may be a planar surface.', 'Further, the peak \n608\n of the ridges \n601\n and the geometric surface \n606\n may lie on a shared plane (e.g., plane \n329\n in \nFIG.', '11\n) perpendicular to the longitudinal axis of the cutting element \n600\n.', 'In some embodiments, the peak \n608\n of one or more ridges \n601\n may slope at a roof ridge angle from the geometric surface \n606\n (e.g., where a line tangent to the ridge peak \n608\n may slope at a roof ridge angle from the plane perpendicular to the longitudinal axis, such as shown in \nFIG. \n11\n).', 'FIG.', '23\n shows another example of ridge geometry according to embodiments of the present disclosure, where a geometric surface \n616\n is axially extended from multiple recessed edge portions \n617\n formed around the edge \n619\n of the top surface \n614\n.', 'The geometric surface \n616\n may have an oval shape or other elongated curved shape.', 'Further, the geometric surface \n616\n may extend across an entire major dimension \n618\n between opposite sides of the edge \n619\n of the top surface \n614\n.', 'In some embodiments, a geometric surface may have an irregular shape, e.g., including both straight and curved boundary lines.', 'For example, \nFIG.', '24\n shows a cutting element \n620\n with a ridge geometry including a geometric surface \n626\n axially extended from multiple recessed edge portions \n627\n formed around the edge \n629\n of the top surface \n624\n, where the geometric surface \n626\n has an irregular shape.', 'The geometric surface \n626\n may extend across an entire major dimension \n628\na \nbetween opposite sides of the edge \n629\n of the top surface \n624\n.', 'Further, the geometric surface \n626\n may have a shape that is symmetrical across both a line \n628\nb \nbisecting the length of the ridges \n621\n and across the major dimension \n628\na \nof the geometric surface \n626\n.', 'As shown in the embodiments shown in \nFIGS.', '19\n-\n24\n, at least a portion of a ridge peak may be formed of a planar surface lying along a plane perpendicular to the longitudinal axis of the cutting element.', 'For example, as described above, the portion of the peaks forming a geometric surface may be a planar surface, while the portions of the peaks in the edge portions may be formed of a curved surface having a radius of curvature.', 'In some embodiments, such as described below, a ridge peak may be entirely formed of a planar surface (along the entire length of the peak).', 'For example, \nFIGS.', '25\n-\n28\n show another example of a cutting element \n700\n according embodiments to the present disclosure having a ridge geometry formed on a top surface \n710\n of an ultrahard layer, where the edge portion(s) \n721\n of the ridge \n720\n have at least one of a reduced roof angle, a reduced roof radius of curvature, and a reduced peak width relative to a central portion of the ridge.', 'The ridge geometry of the top surface \n710\n includes a peak \n722\n of the ridge \n720\n and sidewalls \n730\n extending outwardly from the peak \n722\n to an interior boundary \n741\n of a chamfer \n740\n formed around the edge \n714\n of the top surface \n710\n (or in embodiments without a chamfer \n740\n, extending to the edge \n714\n of the top surface \n710\n).', 'The ridge \n720\n extends a length \n780\n linearly across a major dimension of the top surface \n710\n, where edge portions \n721\n of the ridge \n720\n extend a length \n781\n inwardly from opposite sides of the edge \n714\n of the top surface \n710\n to a central portion \n723\n of the top surface \n710\n.', 'The sidewalls \n730\n may extend downwardly and outwardly from the peak \n722\n to the interior boundary \n741\n of the chamfer \n740\n at a roof angle \n702\n.', 'The roof angle \n702\n may be measured between the lines \n731\n tangent to the sidewalls \n730\n proximate to the peak \n722\n.', 'The roof angle \n702\n may be substantially constant along the length \n780\n of the peak \n722\n.', 'The roof angle \n702\n may range, for example, between about 140 degrees to about 155 degrees.', 'The peak \n722\n may be formed of a planar surface extending substantially perpendicular to the longitudinal axis \n701\n along the length \n780\n of the ridge \n720\n.', 'The peak \n722\n planar surface may form a geometric surface (e.g., as described in \nFIGS.', '22\n-\n24\n) having a geometry defined between opposite points \n726\n of transition from the peak \n722\n to a sidewall \n730\n and between opposite sides of the chamfer \n740\n.', 'A width \n725\n of the peak \n722\n may be measured between opposite points \n726\n of transition from the peak \n722\n to a sidewall \n730\n.', 'The transition from the peak \n722\n to a sidewall \n730\n may be angled or radiused.', 'The width \n725\n of the peak \n722\n may vary along the length \n780\n of the ridge \n720\n.', 'For example, the peak \n722\n in the edge portions \n721\n of the ridge \n720\n may have a first width \n725\na \nproximate the edge \n714\n of the top surface \n710\n, and the portion of the peak \n722\n in a central portion of the top surface \n710\n around the longitudinal axis \n701\n may have a second width \n725\nb \ngreater than the first width \n725\na\n.', 'Further, as shown in \nFIG.', '25\n, the width \n725\n of the peak \n722\n may gradually and continuously increase from the first width \n725\na \nproximate the edge \n714\n toward the central portion of the top surface \n710\n.', 'According to embodiments of the present disclosure, the first width \n725\na \nproximate the edge \n714\n of the peak \n722\n may range, for example, between about 0.05 to about 0.15 inches.', 'By providing a first width \n725\na \nof about 0.05 inches or more proximate the edge \n714\n of the cutting element, the peak \n722\n may form two cutting tips \n790\n that may act as pinch points to build stress concentrations on a working surface, e.g., a rock formation being drilled, and to reduce forces required for the rock fracturing.', 'Three cutting edges \n792\n alternatingly formed around the cutting tips \n790\n may also help with rock fracturing.', 'Further, cutting elements according to embodiments of the present disclosure having a peak \n722\n with a first width \n725\na \nproximate the edge \n714\n of the cutting element of about 0.1 inch, a second width \n725\nb \ngreater than the first width \n725\na\n, and a roof angle \n702\n of about 140 degrees have been shown experimentally to have a lower cutter specific energy (i.e., the energy required to remove a unit volume of rock for a single cutting element) when compared with cutting elements having different cutting face geometry.', 'For example, \nFIG.', '29\n shows a graph of test results comparing cutting performance of a conventional planar top cutting element \n771\n, a cutting element \n772\n having a ridge with a uniform curved peak along its length, a cutting element \n773\n having a ridge geometry such as shown in \nFIGS.', '13\n-\n18\n, and a cutting element \n700\n having a ridge geometry such as shown in \nFIGS.', '25\n-\n28\n with a peak first width \n725\na \nof about 0.1 inches and a roof angle of about 140 degrees.', 'The graph shows the measured normalized forces (cutting force and vertical force) and specific energy of the cutting elements \n771\n, \n772\n, \n773\n, and \n700\n as they cut a rock sample at a depth of cut (DOC) of 0.1 inches at a 20 degrees back rake angle.', 'As shown, the cutting element \n700\n having a ridge geometry with a peak first width \n725\na \nof about 0.1 inches and a roof angle of about 140 degrees has the lowest cutting force, the lowest vertical force, and the lowest specific energy when compared with the other cutting elements \n771\n, \n772\n, and \n773\n in the same rock-cutting movement.', 'Such results indicate that the ridge geometry shown in \nFIGS.', '25\n-\n28\n may use less drilling effort and provide better cutting efficiency when compared with other cutting element geometries.', 'In addition to cutting element geometry that provides improved cutting efficiency by lowering forces during rock fracturing, embodiments of the present disclosure may also include cutting element geometry that aids in rock chip removal.', 'For example, \nFIGS.', '30\n-\n34\n show a cutting element \n800\n having a top surface \n810\n ridge geometry according to embodiments of the present disclosure that includes at least one scooped feature for directing rock chips or other cutting debris away from the cutting tips of the ridge \n820\n.', 'The ridge geometry of the top surface \n810\n includes a ridge \n820\n extending a length \n880\n across an entire major dimension (e.g., diameter) of the cutting element between opposite edges \n814\n of the top surface \n810\n, where the ridge geometry varies along its length \n880\n.', 'For example, edge portions \n821\n of the ridge \n820\n (e.g., portions of the ridge \n820\n extending a length \n881\n radially from the opposite edges \n814\n of the cutting element) may have a different geometry than the central portion \n823\n of the ridge \n820\n (the portion surrounding the longitudinal axis \n801\n of the cutting element).', 'In the embodiment shown, the width \n825\n of the ridge \n820\n may be smaller in the edge portions \n821\n of the ridge \n820\n than in the central portion \n823\n of the top surface \n810\n.', 'Similar to the embodiment shown in \nFIGS.', '25\n-\n28\n, the ridge peak \n822\n may have a planar surface lying along a plane perpendicular to the longitudinal axis \n801\n of the cutting element, where the planar surface peak \n822\n may form a raised geometric surface relative to recessed edge portions \n815\n.', 'The geometric surface of the peak \n822\n may have a geometry defined between opposite lateral sides of the peak \n822\n and between opposite sides of the edge \n814\n.', 'The width \n825\n of the peak \n822\n may measured between opposite sides of the peak \n822\n planar surface.', 'The width \n825\n of the peak \n822\n may increase from a first width \n825\na \nproximate the edge \n814\n of the cutting element to a second width \n825\nb \nin the central portion \n823\n of the top surface \n810\n.', 'As shown in \nFIG. \n34\n, two cutting tips \n890\n may be formed at the cutting element edge \n814\n on opposite sides of the peak \n822\n at the first width \n825\na\n, and three cutting edges \n892\n may be alternatingly formed around the cutting tips \n890\n.', 'The alternating cutting tips \n890\n and cutting edges \n892\n may contact and fracture rock during cutting.', 'Further, the top surface geometry may include undulating sidewalls \n830\n formed on opposite sides of the ridge \n820\n.', 'The undulating sidewalls \n830\n may include scooped regions \n831\n positioned proximate to and on opposite sides of the peak \n822\n in the edge portions \n821\n.', 'The scooped regions \n831\n may have a generally concave geometry and extend between the transition region \n835\na\n, cutting edges \n892\n, and a recessed edge portion \n815\n of the edge \n814\n.', 'The scooped regions \n831\n may provide a path for the flow of rock debris around the peak \n820\n and away from the cutting element.', 'The undulating sidewalls \n830\n may further include raised regions \n832\n positioned between the scooped regions \n831\n on opposite sides of the peak \n822\n and extending from the transition region \n835\nb \nto a raised edge portion \n816\n of the edge \n814\n.', 'In such manner, the edge \n814\n formed around the cutting element may undulate in height between the ridge peak \n822\n, the recessed edge portions \n815\n, and the raised edge portions \n816\n.', 'The ridge geometry may further include a transition region \n835\na\n, \n835\nb \n(collectively referred to as \n835\n) providing a curved transition between the ridge peak \n822\n and undulating sidewalls \n830\n positioned on opposite sides of the peak \n822\n.', 'The transition region \n835\n may have a varying geometry along the length \n880\n of the ridge \n820\n and corresponding with at least one of the geometry of the undulating sidewalls \n830\n and the varying ridge width \n825\n.', 'In the embodiment shown in \nFIGS.', '30\n-\n34\n, first transition regions \n835\na \non opposite sides of the peak \n822\n in the edge portions \n821\n of the ridge \n820\n may have a smaller size than a second transition region \n835\nb \nin the central portion \n823\n of the top surface \n810\n.', 'For example, the first transition regions \n835\na \nmay have a relatively tighter curvature from the peak \n822\n to the scooped regions \n831\n in the undulating sidewalls \n830\n compared to the second transition region \n835\nb \nhaving a relatively larger curvature from the peak \n822\n to the raised regions \n832\n of the undulating sidewalls \n830\n.', 'Additionally, the first transition regions \n835\na \nmay have a relatively smaller width, as measured laterally from the peak \n822\n, compared to the second transition region \n835\nb \nhaving a relatively larger width, as measured laterally from the peak \n822\n.', 'Cutting elements according to embodiments of the present disclosure may be formed, for example, by forming an ultrahard layer having ridge geometry disclosed herein using a mold with a negative of the ridge geometry.', 'The ultrahard layer having ridge geometry according to embodiments of the preset disclosure may be formed on a substrate (e.g., placing ultrahard material such as diamond powder adjacent to a preformed substrate or substrate material in a high pressure high temperature press and sintering the material together) or may be pre-formed and attached to a substrate.', 'In some embodiments, a method of forming a cutting element with ridge geometry according to embodiments disclosed herein may include providing a cutting element having a ridge formed at a top surface of the cutting element, where the ridge may extend along a major dimension of the top surface from an edge of the top surface and has a peak with a first roof radius of curvature and sidewalls sloping away from the peak at a first roof angle.', 'An amount of ultrahard material from the top surface around an edge portion of the ridge may then be removed to form a second peak having a second roof radius of curvature smaller than the first roof radius of curvature and recessed sidewalls sloping away from the second peak at a second roof angle smaller than the first roof angle.', 'The edge portion having the second roof radius of curvature and the second roof angle may extend a partial length of the ridge from the edge toward a longitudinal axis of the cutting element.', 'For example, in some embodiments, an amount of ultrahard material may be removed from the top surface using a laser to form an edge portion of a ridge having a reduced roof radius of curvature and reduced roof angle (and in some embodiments also a roof ridge angle).', 'Substrates according to embodiments of the present disclosure may be formed of cemented carbides, such as tungsten carbide, titanium carbide, chromium carbide, niobium carbide, tantalum carbide, vanadium carbide, or combinations thereof cemented with iron, nickel, cobalt, or alloys thereof.', 'For example, a substrate may be formed of cobalt-cemented tungsten carbide.', 'Ultrahard layers according to embodiments of the present disclosure may be formed of, for example, polycrystalline diamond, such as formed of diamond crystals bonded together by a metal catalyst such as cobalt or other Group VIII metals under sufficiently high pressure and high temperatures (sintering under HPHT conditions), thermally stable polycrystalline diamond (polycrystalline diamond having at least some or substantially all of the catalyst material removed), or cubic boron nitride.', 'Further, it is also within the scope of the present disclosure that the ultrahard layer may be formed from one or more layers, which may have a gradient or stepped transition of diamond content therein.', 'In such embodiments, one or more transition layers (as well as the other layer) may include metal carbide particles therein.', 'Further, when such transition layers are used, the combined transition layers and outer layer may collectively be referred to as the ultrahard layer, as that term has been used in the present application.', 'That is, the interface surface on which the ultrahard layer (or plurality of layers including an ultrahard material) may be formed is that of the cemented carbide substrate.', 'Cutting elements having a ridge geometry according to embodiments of the present disclosure may have improved cutting efficiency.', 'For example, cutting efficiency may be improved due to decreased contacting area between an edge portion of a ridge and a working surface.', 'The inventors of this application have found that cutting element workload grows with the expanding engagement with the rock formation.', 'This engagement is a function of the contacting area as well as the depth of cutting (DOC).', 'Referring to \nFIGS.', '35\n and \n36', ', a study on the performance of ridge geometry according to embodiments of the present disclosure is shown.', 'In the study, three models of cutting elements, including a conventional cutting element \n900\n having a planar top surface, a first ridge cutting element \n910\n having a roof angle of 159 degrees, and a second ridge cutting element \n920\n having a roof angle of 135 degrees, were built for the geometric study and contacted to a working surface at different DOCs.', 'The highlighted portions of the cutting elements \n900\n, \n910\n, \n920\n show the contacting area \n902\n, \n912\n, \n922\n. \nFIG.', '36\n shows a graph of the growth of the contacting area of each sample cutting element \n902\n, \n912\n, \n922\n with the increasing DOC at a constant back-rake angle of 15 degrees.', 'From the study, it was evident that the growth rate varied with the roof angle, where the greater the roof angle, the faster the contacting area \n902\n, \n912\n, \n922\n enlarges with the increasing DOC.', 'Further, contacting area correlates to the penetrating resistance when a cutting element cuts into a rock formation.', 'Therefore, combining various roof angles, e.g., forming an edge portion of a ridge with a smaller roof angle compared with a central portion of the ridge, as described herein, may be used to control the contacting area of the cutting element.', 'When a relatively larger roof angle is formed in the central portion of the ridge, the cutting element may be limited on the amount of penetration at the transition between the smaller roof angle portion (in the edge portion of the ridge) and the larger roof angle portion (in the central portion of the ridge).', 'In such manner, the contacting area of a cutting element may be controlled (and thus reduce effects of overloading the cutting element) by designing a selected edge portion of a ridge to have a reduced roof angle relative to a larger roof angle in a central portion of the ridge.', 'Further, embodiments of the present disclosure may have an edge portion of a ridge having a reduced peak width relative to the peak width of an adjacent central portion of the ridge.', 'By increasing the width of the ridge peak in a central portion of the ridge relative to an edge portion of the ridge, crack propagation may be reduced.', 'For example, if a crack initiates from an edge of a ridge cutting element according to embodiments of the present disclosure, the crack may propagate until meeting an increased amount of ultrahard material at the relatively wider central portion of the ridge, at which point, the relatively wider central portion of the ridge may inhibit further crack growth.', 'While ridge cutting elements having a generally uniform ridge geometry along the entire length of the ridge may have better drilling efficiency when compared with, for example, a conventional planar cutting element, such ridge geometry may suffer from increased loads in operation, and thus experience premature failures (most commonly ultrahard material layer fracturing.', 'By modifying an edge portion of the ridge in accordance with embodiments disclosed herein, the loading may be controlled, and thus improve the life of the cutting element.', 'In another study, cutting elements having a generally uniform ridge geometry along the entire length of the ridge with a roof angle of 175 degrees in a blunter ridge cutting element and with a roof angle of 135 degrees in a sharper ridge cutting element were compared using rock cutting tests on a vertical turret lathe.', 'FIG.', '37\n shows a representation of the ridge cutting elements \n930\n moving in direction \n932\n on a rock sample \n934\n in the vertical turret lathe test.', 'Three forces acting on the ridge cutting elements \n930\n, including vertical force \n940\n, cutting force \n942\n, and side force \n944\n, were recorded during testing.', 'From the test results, it was found that the sharper ridge cutting element with the roof angle of 135 degrees required only half of the vertical force applied on the blunter ridge cutting element with 175 degrees to reach the same depth of cutting \n936\n.', 'It was also found that the sharper ridge cutting element (with 135-degree roof angle) took about 60% of the cutting force applied on the blunter ridge cutting element (with 175-degree roof angle) to drag the ridge cutting element forward.', 'The ridge cutting elements \n930\n were further equipped on bits with back-rake angles \n950\n between 12 and 20 degrees, as shown in \nFIG.', '38\n.', 'In addition, the ridge cutting elements \n930\n included a roof ridge angle of around 5 degrees, which increased the effective back-rake angle \n950\n.', 'In drilling, this back-rake angle \n950\n resulted in compression \n960\n on the ahead rock \n970\n (i.e., the rock directly ahead of the cutting element when cutting) from the vertical force \n940\n and the cutting force \n942\n.', 'Such compression \n960\n may restrict the rock \n970\n fracturing and removal.', 'Thus, a lower back-rake angle \n950\n may reduce such resistance to rock fracturing.', 'Ridge cutting elements according to embodiments of the present disclosure having a reduced roof angle and reduced roof radius of curvature (either with or without a roof ridge angle) were shown to have noticeably reduced compression in the ahead rock \n970\n during testing.', 'In addition, the ridge cutting element having a modified edge portion tended to break the fractured rocks into smaller pieces.', 'According to embodiments of the present disclosure, an edge portion of a ridge cutting element may be modified to have a reduced roof angle (e.g., 125 degrees or less) and a reduced roof radius of curvature (e.g., less than 0.11 inches).', 'The smaller roof radius of curvature may smooth the sharper angle from the reduced roof angle.', 'Further, one or more concave recesses (e.g., a tear-drop shaped dimple) may be introduced on the peak of the ridge for reduced compression on ahead rock and the ease of rock chip breakdown.', 'A concave recess may be employed on the ridge peak between an edge portion and central portion of the ridge (e.g., on a portion of the ridge sloping at a roof ridge angle) to bridge the modified edge portion and the remaining portion of the ridge.', 'The cutting efficiency of a ridge cutting element having a modified edge portion with a reduced roof angle and reduced roof radius of curvature according to embodiments of the present disclosure was estimated by finite element analysis (FEA) modeling.', 'In comparison to a ridge cutting element having a generally uniform ridge geometry, a ridge cutting element having a modified edge portion with a roof angle of 120 degrees and roof radius of curvature of less than 0.11 inches required 10 percent less cutting force.', 'By reducing the cutting force, the bit-turning resistance may also be reduced, thereby improving bit responses to drive changes.', 'Embodiments of a shaped element have been primarily described with reference to wellbore drilling operations; the shaped elements described herein may be used in applications other than the drilling of a wellbore.', 'In other embodiments, shaped elements according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources.', 'For instance, shaped elements of the present disclosure may be used in a borehole used for placement of utility lines.', 'Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.', 'One or more specific embodiments of the present disclosure are described herein.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that is within standard manufacturing or process tolerances, or which still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.']

['1.', 'A cutting element comprising:\na substrate; and\nan ultrahard layer on an upper surface of the substrate, a top surface of the ultrahard layer comprising: a ridge extending along a major dimension of the top surface from an edge of the top surface, the ridge having a peak with at least two different roof radii of curvature; and at least two sidewalls sloping in opposite directions from the peak of the ridge at a roof angle, wherein a first roof angle of the ridge proximate the edge is smaller than a second roof angle in a central portion of the ridge around a longitudinal axis of the cutting element.', '2.', 'The cutting element of claim 1, wherein a roof ridge angle defined between a line tangent to the peak of the ridge proximate the edge and a plane perpendicular to the longitudinal axis ranges from greater than zero to 10 degrees.', '3.', 'The cutting element of claim 1, wherein the sidewalls sloping from the ridge at the first roof angle are recessed from the sidewalls sloping from the ridge at the second roof angle.', '4.', 'The cutting element of claim 1, further comprising a chamfer formed around the edge of the top surface.', '5.', 'The cutting element of claim 1, wherein the ridge has at least one concave recess formed along the peak of the ridge.', '6.', 'The cutting element of claim 1, wherein an interface formed between a bottom surface of the ultrahard layer and the upper surface of the substrate is nonplanar, the bottom surface comprising a protrusion formed opposite the ridge and proximate the edge and the upper surface of the substrate comprising a recessed portion having a corresponding shape to the protrusion.', '7.', 'The cutting element of claim 1, wherein the first roof angle ranges between 110 degrees and 130 degrees, and the second roof angle ranges between 135 degrees and 165 degrees.', '8.', 'A cutting element comprising:\na top surface having a ridge extending from an edge of the top surface along a major dimension of the top surface; and\na peak of the ridge having a width measured between opposite points of transition from the peak to a sidewall, wherein the width of the peak in a central portion of the ridge around a longitudinal axis of the cutting element is greater than the width of the peak at the edge portion of the ridge, the edge portion extending a length of the ridge from the edge to the central portion,\nwherein the peak has a roof radius of curvature along an edge portion of the ridge less than 0.1 inches.', '9.', 'The cutting element of claim 8, wherein the peak in the central portion of the ridge has a polygonal shape.\n\n\n\n\n\n\n10.', 'The cutting element of claim 8, wherein the peak in the central portion of the ridge has an oval shape.', '11.', 'The cutting element of claim 8, wherein the width of the peak in the central portion of the ridge extends greater than 50 percent of the major dimension.', '12.', 'The cutting element of claim 8, wherein the width of the peak in the central portion of the ridge extends to opposite sides of the edge of the top surface.', '13.', 'The cutting element of claim 8, wherein the sidewalls on opposite sides of the peak in the edge portion extend from the peak at a roof angle less than 135 degrees.', '14.', 'The cutting element of claim 8, wherein the peak of the edge portion extends from the central portion at a roof ridge angle defined between a line tangent to the peak of the ridge and a plane perpendicular to the longitudinal axis ranges from greater than zero to 10 degrees.', '15.', 'A cutting element, comprising:\na substrate; and\nan ultrahard layer on an upper surface of the substrate, a top surface of the ultrahard layer comprising: a ridge extending across a major dimension of the top surface between opposite sides of an edge around the top surface, wherein the ridge comprises: a peak, wherein at least a portion of the peak is formed of a planar surface; and a width measured between opposite sides of the peak; wherein the width of the ridge in an edge portion of the ridge is smaller than the width of the ridge in a central portion of the top surface; and sidewalls extending from opposite sides of the ridge to at least one recessed edge portion of the edge.', '16.', 'The cutting element of claim 15, wherein the portion of the peak having a planar surface forms a geometric surface extending between opposite sides of the edge.', '17.', 'The cutting element of claim 15, wherein the peak in the edge portion of the ridge has a roof radius of curvature that is less than 0.1 inches.', '18.', 'The cutting element of claim 15, wherein the sidewalls have an undulating geometry comprising at least one scooped region proximate a cutting edge portion of the edge and at least one raised region extending between the central portion and a raised edge portion of the edge.', '19.', 'The cutting element of claim 15, wherein the top surface further comprises a transition region extending between the peak and the sidewalls.']

['FIG.', '1 is a conventional drill bit.; FIGS. 2 and 3 show side views of a cutting element according to embodiments of the present disclosure.; FIG.', '4 shows an ultrahard layer according to embodiments of the present disclosure.', '; FIG.', '5 shows a side view of the ultrahard layer shown in FIG.', '4.; FIG.', '6 shows a top view of the ultrahard layer shown in FIGS.', '4 and 5.; FIG.', '7 shows another side view of the ultrahard layer shown in FIGS.', '4-6.; FIG.', '8 shows a cutting element according to embodiments of the present disclosure.', '; FIG.', '9 shows an ultrahard layer according to embodiments of the present disclosure.;', 'FIG.', '10 shows a top view of the ultrahard layer shown in FIG.', '9.; FIG.', '11 shows a side view of the ultrahard layer shown in FIGS.', '9 and 10.; FIG.', '12 shows another side view of the ultrahard layer shown in FIGS.', '9-11.; FIG. 13 shows an ultrahard layer according to embodiments of the present disclosure.', '; FIG.', '14 shows a side view of the ultrahard layer shown in FIG.', '13.; FIG.', '15 shows a top view of the ultrahard layer shown in FIGS.', '13 and 14.; FIG.', '16 shows a cross-sectional view of the ultrahard layer of FIGS.', '13-15 along a plane intersecting the longitudinal axis of the ultrahard layer and extending through the length of the ridge on the ultrahard layer.;', 'FIG.', '17 shows another cross-sectional view of the ultrahard layer of FIGS.', '13-16 along a plane intersecting the longitudinal axis of the ultrahard layer and perpendicular to the length of the ridge on the ultrahard layer.;', 'FIG.', '18 shows another cross-sectional view of the ultrahard layer of FIGS.', '13-17 along a plane parallel to the longitudinal axis of the ultrahard layer and perpendicular to the length of the ridge on the ultrahard layer.;', 'FIG. 19 shows a top view of a cutting element according to embodiments of the present disclosure.; FIG.', '20 shows a top view of a cutting element according to embodiments of the present disclosure.', '; FIG.', '21 shows a top view of a cutting element according to embodiments of the present disclosure.', '; FIG.', '22 shows a top view of a cutting element according to embodiments of the present disclosure.;', 'FIG.', '23 shows a top view of a cutting element according to embodiments of the present disclosure.;', 'FIG.', '24 shows a top view of a cutting element according to embodiments of the present disclosure.; FIGS.', '25-28 show different views of a cutting element according to embodiments of the present disclosure.', '; FIG.', '29 shows a graph comparing forces and specific energy during testing of different cutting element types with a cutting element according to embodiments of the present disclosure.; FIGS.', '30-34 show different views of a cutting element according to embodiments of the present disclosure.', '; FIG.', '35 shows a comparison between the contacting area of a planar cutting element with ridge cutting elements at a depth of cut.; FIG.', '36 shows a graph of the change in contacting area at different depths of cut for the cutting elements shown in FIG.', '35.; FIG.', '37 shows a schematic of forces acting on a ridge cutting element.; FIG.', '38 shows a cross-sectional view of a ridge cutting element as it cuts a formation.; FIGS.', '4-7 show the ultrahard layer 200 portion of a cutting element, which may be attached to (or formed to) a substrate at a planar or non-planar interface to form the cutting element.', 'For example, in the embodiment shown in FIGS.', '4-7, the ultrahard layer 200 may have a bottom surface 207 that may be attached to an upper surface of a substrate having a geometry corresponding to the bottom surface 207 geometry, forming an interface between the ultrahard layer 200 and substrate.; FIGS. 9-12 show another example of an ultrahard layer 300 according to embodiments of the present disclosure.', 'FIG.', '9 is a perspective view, FIG.', '10 is a top view, and FIGS.', '11 and 12 are side views of the ultrahard layer 300.', 'The ultrahard layer 300 has a top surface 310 and a bottom surface 307 opposite the top surface, where a thickness 350 of the ultrahard layer 300 is measured axially between the top surface 310 and bottom surface 307 of the ultrahard layer 300.; FIGS.', '13-18 show another example of an ultrahard layer 400 according to embodiments of the present disclosure.', 'FIG.', '13 is a perspective view of the ultrahard layer 400.', 'FIG.', '14 is a side view of the ultrahard layer 400.', 'FIG.', '15 is a schematic of a top view of the ultrahard layer 400 (looking at the top surface 410 of the ultrahard layer 400).', 'FIGS.', '16-18 are cross-sectional views of the ultrahard layer 400 taken along cross-sections A-A, B-B, and C-C, respectively, shown in FIG.', '15.; FIGS.', '19-21 show top views of cutting elements 500, 510, 520', 'having ridge 501, 511, 521 geometries that include edge portions 502, 512, 522 having a reduced peak width 505, 515, 525 relative to a central portion 503, 513, 523 of the ridge 501, 511, 521.', 'As shown in FIG.', '19, the ridge 501 extends linearly across a major dimension of the top surface 504, where edge portions 502 of the ridge 501 are at opposite ends of the ridge 501.', 'A central portion 503 of the ridge 501 extending between the two edge portions 502 has a peak width 505 that is greater than the peak width 505 along the edge portions 502.', 'The peak width 505 is measured between opposite points 507 of transition from the peak 506 of the ridge 501 to the sidewalls 508 extending outwardly from the peak 506 toward an edge 509 of the top surface 504.; FIG.', '20 shows another example of a cutting element 510 with a ridge 511 geometry having a central portion 513 of the ridge 511 with a peak 516 having a polygonal shape.', 'The ridge 511 extends linearly across a major dimension of the top surface 514, where edge portions 512 of the ridge 511 extend inwardly from opposite sides of the edge 519 of the top surface 514 to a central portion 513 of the ridge 511.', 'The width 515 of the peak 516 in the central portion 513 is greater than the width 515 of the peak 516 along the edge portions 512.', 'The peak width 515 is measured between opposite points 517 of transition from the peak 516 of the ridge 511 to the sidewalls 518 extending outwardly from the peak 516 toward the edge 519 of the top surface 514.; FIG.', '21 shows an example of a cutting element 520 with a ridge 521 geometry having a central portion 523 of the ridge 521 with an oval-shaped peak 526 surface.', 'The ridge 521 extends linearly across a major dimension of the top surface 524, where edge portions 522 of the ridge 521 extend inwardly from opposite sides of the edge 529 of the top surface 524 to the central portion 523 of the ridge 521.', 'The width 525 of the peak 526 in the central portion 523 is greater than the width 525 of the peak 526 along the edge portions 522.', 'The oval-shaped portion of the peak 526 may have a planar surface, while the peak 526 in the edge portions 522 may have a curved surface with a radius of curvature (e.g., 404a, 404b in FIG. 13) ranging from, for example, less than 0.1 inches.; FIGS.', '22-24 show top views of cutting elements 600, 610, 620 having ridge geometry that includes a central portion 603, 613, 623 of the ridge 601, 611, 621 that extends to opposite sides of the edge 609, 619, 629 of the top surface 604, 614, 624, across a major dimension of the top surface 604, 614, 624.', 'The edge portions 602, 612, 622 of the ridge 601, 611, 621 have a reduced peak width 605, 615, 625 relative to the central portion 603, 613, 623 of the ridge 601, 611, 621.; FIG.', '23 shows another example of ridge geometry according to embodiments of the present disclosure, where a geometric surface 616 is axially extended from multiple recessed edge portions 617 formed around the edge 619 of the top surface 614.', 'The geometric surface 616 may have an oval shape or other elongated curved shape.', 'Further, the geometric surface 616 may extend across an entire major dimension 618 between opposite sides of the edge 619 of the top surface 614.']

US11791092

Slide-on inductive coupler system

Jul 15, 2022

Benoit Deville, Yann Dufour

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Application PCT/US2014/064522, dated Feb. 23, 2015 (8 pages).

5174340; December 29, 1992; Peterson; 6311774; November 6, 2001; Brockman; 6325150; December 4, 2001; Rayssiguier; 7168487; January 30, 2007; Salamitou et al.; 7212173; May 1, 2007; Chen; 7219729; May 22, 2007; Bostick, III; 7795872; September 14, 2010; Clark; 8334786; December 18, 2012; Bowles et al.; 8683859; April 1, 2014; Godager; 8689621; April 8, 2014; Godager; 9000873; April 7, 2015; Deville et al.; 20020066561; June 6, 2002; Brockman; 20020114216; August 22, 2002; Veneruso; 20040026086; February 12, 2004; Patel; 20040182582; September 23, 2004; Bosma; 20040263414; December 30, 2004; Chen et al.; 20060048941; March 9, 2006; Borst; 20070068673; March 29, 2007; Daily; 20090008078; January 8, 2009; Patel; 20090045974; February 19, 2009; Patel; 20090066535; March 12, 2009; Patel; 20090085701; April 2, 2009; Veneruso; 20090151950; June 18, 2009; Patel; 20100018305; January 28, 2010; Maute; 20110192593; August 11, 2011; Roddy; 20110284216; November 24, 2011; Addis; 20130048269; February 28, 2013; Tarayre; 20130120093; May 16, 2013; Deville; 20130264063; October 10, 2013; Hallundbæk; 20130334894; December 19, 2013; Borgen; 20140266210; September 18, 2014; Godager; 20160268041; September 15, 2016; Deville et al.; 20170074048; March 16, 2017; Patel

2011141173; November 2011; WO; 2012091575; July 2012; WO

['A technique facilitates use of an inductive coupler assembly with casing, e.g. well casing.', 'An inductive coupler is formed as a female inductive coupler with an inductive coil.', 'The inductive coupler is constructed for sliding movement along an exterior of the casing so that it may ultimately be positioned and secured at a suitable location along the casing.', 'The inductive coupler is designed for connection with an electrical device, e.g. a sensor.', 'The inductive coupler facilitates the transfer of sensor data and/or power signals across the casing.', 'Signal transfer across the casing is further enabled by a male inductive coupler positioned within the casing at a location which allows it to cooperate with the exterior, female inductive coupler.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nAny and all applications for which a foreign or domestic priority claim is identified in the Application Data Sheet as filed with the present application are hereby incorporated by reference under 37 CFR 1.57.', 'The present application is a continuation of U.S. application Ser.', 'No. 15/034,911, filed May 6, 2016, which is a National Stage of International Application No. PCT/US2014/064522, filed Nov. 7, 2014, which claims priority benefit of U.S. Provisional Application No. 61/902,069, filed Nov. 8, 2013, the entirety of each of which is incorporated by reference herein and should be considered part of this specification.', 'BACKGROUND\n \nThis disclosure relates to well completions and more particularly to methods and apparatuses for communicating data and/or power signals across a casing.', 'DESCRIPTION OF THE RELATED ART\n \nA wide variety of well equipment may be installed in a well to facilitate operation and monitoring of the well.', 'For example, the well equipment may comprise completion systems installed in a wellbore to enable production of hydrocarbon fluids, such as oil and gas, or to facilitate injection of fluids into the well.', 'The well equipment often includes electrical devices which are powered.', 'In some applications, the electrical devices also provide data which is transmitted to a control system located at a surface of the earth or at another suitable location.', 'In some applications, the power and/or data signals may be transmitted through inductive couplers.', 'SUMMARY', 'In general, a system and methodology are provided for utilizing an inductive coupler assembly with casing, e.g. well casing.', 'An inductive coupler is formed as a female inductive coupler with an inductive coil.', 'The inductive coupler is constructed for sliding movement along an exterior of the casing so that it may ultimately be positioned and secured at a suitable location along the casing.', 'The inductive coupler may be connected with an electrical device, e.g. a sensor.', 'The inductive coupler facilitates the transfer of sensor data and/or power signals across the casing.', 'Signal transfer across the casing is further enabled by a male inductive coupler positioned within the casing at a location which allows it to cooperate with the exterior, female inductive coupler.', 'For example, power signals may be sent to the electrical device (or devices) across the casing, and communication signals may be sent bidirectionally across the casing to and from the electrical device (or devices).', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features can be understood in detail, a more particular description may be had by reference to embodiments, some of which are illustrated in the appended drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the appended drawings illustrate various embodiments and are therefore not to be considered limiting of its scope, and may admit to other equally effective embodiments.', 'FIG.', '1\n is a schematic illustration of an example of an inductive coupler located along a well casing deployed in a wellbore, the inductive coupler being connected to an electrical device, according to an embodiment of the disclosure.\n \nFIG.', '2\n is a schematic illustration of an inductive coupler electrical model, according to an embodiment of the disclosure.\n \nFIG.', '3\n is an orthogonal view of an example of an inductive coupler positioned on casing with an associated electrical device, according to an embodiment of the disclosure.\n \nFIG.', '4\n is a cross-sectional view of an example of an inductive coupler assembly, according to an embodiment of the disclosure.\n \nFIG.', '5\n is a cross-sectional view of another example of an inductive coupler positioned along a casing, according to an embodiment of the disclosure.\n \nFIG.', '6\n is an exploded view of an example of a female inductive coupler assembly and casing section, according to an embodiment of the disclosure.\n \nFIG.', '7\n is an orthogonal view of an example of a section of casing connected to a casing coupling, according to an embodiment of the disclosure.\n \nFIG.', '8\n is an orthogonal view of an example of a female inductive coupler slid onto the section of casing illustrated in \nFIG.', '7\n, according to an embodiment of the disclosure.', 'FIG.', '9\n is an enlarged orthogonal view of a spring member which may be disposed between the female inductive coupler and the casing coupling, according to an embodiment of the disclosure.\n \nFIG.', '10\n is an orthogonal view of an example of a female inductive coupler and an electrical device with a device protector slid onto the section of casing illustrated in \nFIG.', '7\n, according to an embodiment of the disclosure.', 'FIG.', '11\n is an orthogonal view similar to that of \nFIG.', '10\n but showing a second casing coupling securing the female inductive coupler and the sensor/device protector on the section of casing, according to an embodiment of the disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of the present disclosure.', 'It will be understood by those skilled in the art, however, that the embodiments of the present disclosure may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'In the specification and appended claims: the terms “connect”, “connection”, “connected”, “in connection with”, and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element”.', 'Further, the terms “couple”, “coupling”, “coupled”, “coupled together”, and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements”.', 'As used herein, the terms “up” and “down”, “upper” and “lower”, “upwardly” and downwardly”, “upstream” and “downstream”; “above” and “below”; and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure.', 'The disclosure herein generally involves a system and methodology for utilizing an inductive coupler system with casing.', 'For example, the inductive coupler system may be used with well casing deployed along a wellbore extending into a subterranean formation.', 'The inductive coupler system comprises an inner or male inductive coupler and an outer or female inductive coupler each having an inductive coil.', 'The outer inductive coupler is constructed for sliding movement along an exterior of the casing.', 'In many applications, the outer inductive coupler may be slid over the casing and secured without modifications to the casing, thus ensuring casing integrity.', 'The outer or female inductive coupler ultimately is positioned at a suitable location along the casing and secured at that location.', 'The female inductive coupler also is designed to be operatively connected with an electrical device, e.g. a sensor.', 'Data may be sent from or to the electrical device across the casing via the inductive coupler.', 'Depending on the application, power signals also may be transferred across the casing via the inductive coupler.', 'In some applications, the male inductive coupler is mounted within the casing or positioned within the casing via well equipment (e.g. positioned as part of a well completion or well tool).', 'The male inductive coupler is positioned at a location which allows it to cooperate with the outer, female inductive coupler for transmitting signals across the casing.', 'Embodiments described herein use induction principles to enable power and/or information data to be conveyed between the male and female inductive couplers.', 'The male inductive coupler and the female inductive coupler each may comprise at least one coil, a magnetic core, and a metal sleeve enclosing the at least one coil and magnetic core.', 'The coil and magnetic core of the male inductive coupler are radially aligned with the coil and magnetic core of the female inductive coupler to facilitate inductive transfer of power and/or data signals.', 'A magnetic field is created by running electrical current through the coil or coils of one of the inductive couplers.', 'The electrical current induces a current flow in the opposed coil or coils of the other inductive coupler.', 'This allows power and/or data signals to be transferred across the casing, i.e. across the casing wall.', 'The construction of the outer or female inductive coupler enables the female inductive coupler to be readily slid onto the casing and moved to a desired position without detrimentally affecting the integrity of the casing.', 'Referring generally to \nFIG.', '1\n, an example of an inductive coupler system \n20\n is illustrated as disposed along a casing \n22\n.', 'By way of example, the casing \n22\n may be disposed along a wellbore \n24\n drilled into a subterranean formation \n26\n.', 'In some well applications, the well casing \n22\n is formed of non-magnetic, low conductivity metal.', 'The casing \n22\n has an interior surface \n28\n and an exterior surface \n30\n.', 'An outer or female inductive coupler \n32\n of inductive coupler system \n20\n is illustrated as positioned at a desired exterior location along the exterior surface \n30\n of casing \n22\n.', 'The female inductive coupler \n32\n may be constructed with a circular interior \n34\n sized to encircle the casing \n22\n.', 'This construction allows the female inductive coupler \n32\n to be slid along the exterior surface \n30\n until positioned at the desired exterior location.', 'The female inductive coupler \n32\n can then be secured at the desired exterior location by suitable fasteners and/or devices as described in greater detail below.', 'The inductive coupler system \n20\n also comprises a male inductive coupler \n36\n positioned at a desired interior location within the casing \n22\n and along the interior surface \n28\n.', 'The male inductive coupler \n36\n may be constructed with a circular exterior \n38\n sized to fit within casing \n22\n generally adjacent interior surface \n28\n.', 'The male inductive coupler \n36\n also may have an internal passage \n40\n sized to enable movement therethrough of equipment and/or fluids as represented by arrow \n41\n.', 'The male inductive coupler \n36\n may be mounted and secured at the desired location within casing \n22\n via appropriate fasteners or mounting devices.', 'However, the male inductive coupler \n36\n also may be positioned at the desired location within casing \n22\n via well equipment carrying the male inductive coupler \n36\n through the interior of the casing \n22\n.', 'For example, the male inductive coupler \n36\n may be mounted on a well tool, well completion, or other well tubing string which carries the coupler \n36\n to the desired interior location.', 'As further illustrated in \nFIG.', '1\n, the inductive coupler system \n20\n may be connected to a control system \n42\n, such as a surface control system.', 'The control system \n42\n may be used to send and/or receive power and data signals via a suitable communication line \n44\n, such as a wired or wireless communication line.', 'By way of example, the control system \n42\n may be designed to send power and data signals downhole while receiving data signals from an electrical device \n46\n (or devices \n46\n) located downhole.', 'In the example illustrated, the electrical device \n46\n is connected with female inductive coupler \n32\n and positioned externally of casing \n22\n.', 'The electrical device \n46\n may be connected directly with female inductive coupler \n32\n or connected via a suitable cable \n47\n, e.g. a permanent downhole cable.', 'The electrical device \n46\n also may comprise a variety of sensors or other devices used to accumulate data on formation parameters or other well related parameters.', 'In some applications, the electrical device \n46\n may comprise one or more pressure sensors to monitor pressure outside of casing \n22\n.', 'As described in greater detail below, the female inductive coupler \n32\n and the male inductive coupler \n36\n may each comprise a coil (or coils) enclosed by a metallic sleeve or tube.', 'Each inductive coupler \n32\n and \n36\n may be constructed so as to have a higher efficiency by utilizing a substantial number of turns on each coil.', 'Additionally, the metallic sleeve behaves as a secondary coil in short-circuit and thus the voltage for one turn of the coil can be minimized to minimize losses in the metallic sleeve.', 'In \nFIG.', '2\n, a circuit diagram is provided to show an equivalent circuit for a one-turn inductive coupler (each coil has one turn) with RmF and RmM being the metallic sleeve resistance.', 'For n turns of primary coil, the equivalent circuit is similar but with resistances in parallel and will become RmF*n\n2 \nand RmM*n\n2\n.', 'To minimize the current in those branches, a high n may be employed to create higher resistance and lower current in the branch.', 'The principal also can be extended to transferring power and telemetry signals via inductive coupling to the casing.', 'Various parameters can be optimized.', 'For example, a high electrical resistivity, non-magnetic (e.g. relative magnetic permeability=1) material may be used for the casing; power may be transferred at low frequency (e.g. 50 Hz or less) and low voltage (e.g. 5-10V); and telemetry signals may be transferred via a low frequency carrier (e.g. around 1 kHz or less) and at low voltage (e.g. below 5V).', 'Referring generally to \nFIG.', '3\n, an example of inductive coupler system \n20\n is illustrated as comprising female inductive coupler \n32\n slid over well casing \n22\n.', 'However, other embodiments of female inductive coupler \n32\n may be constructed for sliding engagement with the well casing \n22\n or with other types of casing \n22\n.', 'In this particular example, the female inductive coupler \n32\n comprises a plurality of female inductive coupler coils \n48\n, e.g. two coils, mounted in a female inductive coupler body \n50\n.', 'The body \n50\n has circular interior \n34\n sized to enable the female inductive coupler \n32\n to be slid onto casing \n22\n along an exterior surface \n30\n to a desired location.', 'In this example, one of the coils \n48\n may be used for power signals and the other of the coils \n48\n may be used for data, e.g. telemetry, signals.', 'In the example illustrated, electrical device \n46\n comprises a sensor cartridge \n52\n directly integrated into the slide-on, female inductive coupler \n32\n.', 'The sensor cartridge \n52\n comprises a sensor \n54\n, such as a pressure gauge.', 'In some embodiments, the electrical device \n46\n, e.g. sensor \n54\n, may be connected to female inductive coupler \n32\n via cable \n47\n or via another suitable signal carrier.', 'The use of cable \n47\n enables placement of the electrical device \n46\n, e.g. sensor \n54\n, at a location along the exterior of casing \n22\n and farther away from the body \n50\n of female inductive coupler \n32\n.', 'It should be noted that electrical device \n46\n may comprise a variety of other devices, including actuators or other downhole tools which may be connected with the female inductive coupler \n32\n directly or via cable \n47\n.', 'Referring generally to \nFIG.', '4\n, a cross-sectional view of an example of inductive coupler system \n20\n is illustrated.', 'In this example, female inductive coupler \n32\n is again slid along the exterior of casing \n22\n until further motion is blocked by an abutment \n56\n, such as an abutment formed by a casing coupling \n58\n connected to casing \n22\n.', 'Casing coupling \n58\n may be connected to casing \n22\n via a threaded engagement region \n60\n or via other suitable connectors.', 'In the illustrated embodiment, female inductive coupler \n32\n again comprises a plurality, e.g. two, coils \n48\n for transfer of power and data/telemetry signals, respectively.', 'A magnetic core \n62\n is positioned circumferentially around each coil \n48\n and a metallic sleeve or tube \n64\n is positioned circumferentially around the magnetic cores \n62\n and coils \n48\n.', 'In some embodiments, a single metallic tube \n64\n may enclose the magnetic cores \n62\n and coils \n48\n collectively.', 'In the specific example illustrated, the sets of corresponding coils \n48\n and magnetic cores \n62\n are positioned axially between spacers \n66\n, e.g. spacer rings, and radially between metallic tube \n64\n on their exterior and casing \n22\n on their interior.', 'In the example illustrated in \nFIG.', '4\n, the male inductive coupler \n36\n is moved along the interior of casing \n22\n and positioned along interior surface \n28\n at a desired location.', 'The illustrated male inductive coupler \n36\n comprises a plurality of male inductive coupler coils \n68\n, e.g. two male inductive coupler coils \n68\n.', 'The male inductive coupler \n36\n is moved along the interior of casing \n22\n until the male inductive coupler coils \n68\n are generally radially aligned with the female inductive coupler coils \n48\n, as illustrated.', 'The radial alignment of coil \n68\n with coils \n48\n facilitates transfer of power and data/telemetry signals across casing \n22\n, i.e. across the tubular wall forming casing \n22\n.', 'As with the female inductive coupler \n32\n, the male inductive coupler \n36\n may comprise a male inductive coupler body \n70\n into which coils \n68\n are mounted.', 'A male magnetic core \n72\n may be positioned circumferentially within each coil \n68\n and the male inductive coupler body \n70\n may be constructed as a metallic sleeve or tube positioned circumferentially within the magnetic cores \n72\n and coils \n68\n.', 'In some embodiments, the coupler body \n70\n also may comprise spacer rings \n74\n which may be formed integrally with coupler body \n70\n or as separate rings.', 'The sets of corresponding coils \n68\n and male magnetic cores \n72\n are positioned axially between the spacer rings \n74\n.', 'Additionally, the sets of corresponding coils \n68\n and male magnetic cores \n72\n are located radially between the metallic coupler body \n70\n on their interior and the casing \n22\n on their exterior.', 'Referring generally to \nFIG.', '5\n, another embodiment of inductive coupler system \n20\n is illustrated.', 'In this example, the female inductive coupler \n32\n is illustrated to facilitate explanation, but the male inductive coupler \n36\n may have a similar corresponding construction along the interior of casing \n22\n.', 'Additionally, the embodiment of \nFIG.', '5\n illustrates a single coil \n48\n, but other applications may utilize similar constructions with a plurality of coils \n48\n separated by, for example, additional spacers \n66\n.', 'In this example, the coil \n48\n and magnetic core \n62\n are positioned axially between a pair of the spacers \n66\n.', 'However, the coil \n48\n and the magnetic core \n62\n are positioned radially between an inner metallic sleeve or tube \n76\n and outer metallic sleeve or tube \n64\n.', 'The female inductive coupler \n32\n (as well as the male inductive coupler \n36\n) may be constructed so that the coils \n48\n, magnetic core \n62\n, and corresponding magnetic circuits are fully encased in metallic material.', 'By way of example, the female inductive coupler \n32\n may be constructed by inserting spacers \n66\n on inner metallic tube \n76\n.', 'In some applications, the spacers \n66\n are formed of high resistivity, non-magnetic metal.', 'Depending on the application and environment, an insulation layer \n78\n may be disposed between inner metallic tube \n76\n and coil \n48\n in the region axially between spacers \n66\n.', 'The coil \n48\n may be wound or otherwise constructed in the axial region between spacers \n66\n.', 'The magnetic core \n62\n is then placed around the coil \n48\n, i.e. placed radially above or outward of coil \n48\n.', 'Axially outer rings \n80\n are then placed adjacent the axially outer ends of spacers \n66\n and outer metallic tube \n64\n is inserted and slid over axially outer rings \n80\n, spacer \n66\n, and magnetic core \n62\n.', 'The inner metallic tube \n76\n, outer metallic tube \n64\n, and axially outer rings \n80\n may then be secured together by suitable fasteners to fully enclose the coil \n48\n and magnetic core \n62\n within metallic material.', 'By way of example, a plurality of welds \n82\n may be made between axially outer rings \n80\n and inner and outer metallic tubes \n76\n, \n64\n.', 'However other fastening techniques, e.g. brazing or threaded fasteners, may be used to secure the components and to enclose coil \n48\n and magnetic core \n62\n.', 'The electrical device \n46\n, e.g. sensor, may be operatively coupled with coil \n48\n and magnetic core \n62\n via a suitable magnetic circuit \n84\n.', 'Engagement between the electrical device \n46\n (or cable \n47\n) and the suitable magnetic circuit \n84\n may be facilitated via a connector \n86\n engaging a port \n88\n.', 'The port \n88\n may extend through one of the axially outer rings \n80\n or through another suitable component of the inductive coupler.', 'In some applications, the connector \n86\n may be sealed via welding (or otherwise sealed) with one of the end rings \n80\n.', 'A variety of component constructions and arrangements may be used to assemble the female inductive coupler \n32\n and/or the male inductive coupler \n36\n.', 'As illustrated in \nFIG.', '6\n, for example, the female inductive coupler \n32\n may be slid onto and secured along casing \n22\n via a variety of cooperating components.', 'In this specific example, an overall assembly \n90\n comprises casing coupling \n58\n, casing \n22\n, and female inductive coupler \n32\n which may include or be coupled with electrical device \n46\n comprising sensor \n54\n.', 'Additionally, the illustrated embodiment of assembly \n90\n comprises a spring member \n92\n, a protective device \n94\n to protect sensor \n54\n, and a second casing coupling \n96\n.', 'The illustrated components, as well as additional and/or other components, may be connected together via various fastening devices, such as clamps, threaded fasteners, interference fits, weldments, adhesives, and/or other fastening devices and techniques.', 'In a specific example, the casing \n22\n comprises in part a casing spacer to which casing coupling \n58\n is threadably engaged, as illustrated in \nFIG.', '7\n.', 'Subsequently, the spring member \n92\n is slid onto casing \n22\n and female inductive coupler \n32\n is slid onto casing \n22\n following spring member \n92\n.', 'The female inductive coupler \n32\n is slid along the exterior surface \n30\n of casing \n22\n until further travel is blocked via abutment \n56\n created by casing coupling \n58\n.', 'As illustrated in \nFIGS. \n8\n and \n9\n, the female inductive coupler \n32\n is positioned via casing coupling \n58\n and spring member \n92\n, the spring member \n92\n being trapped between casing coupling \n58\n and female inductive coupler \n32\n.', 'Subsequently, protective device \n94\n is slid onto casing \n22\n and into engagement with an axial end of female inductive coupler \n32\n opposite casing coupling \n58\n, as illustrated in \nFIG.', '10\n.', 'Depending on the configuration of device \n46\n, the protective device \n94\n may have a variety of sizes, shapes and configurations.', 'In the example illustrated, the protective device \n94\n is generally circular and sized to receive casing \n22\n therethrough.', 'In some applications, the protective device \n94\n may be clamped to casing \n22\n.', 'The protective device \n94\n further comprises a sensor/device receiving cavity \n98\n sized to receive and protect electrical device \n46\n.', 'In the example illustrated, electrical device \n46\n comprises sensor \n54\n, such as a pressure gauge, which slides into receiving cavity \n98\n for protection during deployment downhole and during operation downhole in wellbore \n24\n.', 'The female inductive coupler \n32\n and protective device \n94\n may be secured in place along casing \n22\n via second casing coupling \n96\n, as illustrated in \nFIG.', '11\n.', 'By way of example, casing coupling \n96\n may be threadably engaged with casing \n22\n and appropriately torqued to hold the female inductive coupler \n32\n, device \n46\n, and protective device \n94\n in compression, thus avoiding unwanted movement of these devices during operation of device/sensor \n46\n.', 'In this example, the overall casing \n22\n comprises the illustrated casing spacer which is connected into the rest of the casing \n22\n via casing couplings \n58\n and \n96\n.', 'However, various other fasteners and devices may be used along casing \n22\n to secure the slide-on, female inductive coupler \n32\n at a desired location along the casing \n22\n without otherwise modifying the casing or detrimentally affecting the integrity of the casing.', 'Depending on the parameters of a given application, the structure and components of the inductive coupling system \n20\n, casing \n22\n, device or devices \n46\n, and control system \n42\n may vary.', 'For example, casing \n22\n may be constructed in a variety of sizes and forms along the wellbore \n24\n for cooperation with many types of well completions and other downhole equipment.', 'In some applications, the casing may comprise a non-well related casing.', 'Similarly, the electrical device or devices \n46\n may comprise many types of sensors, e.g. pressure sensors, temperature sensors, resistivity sensors, flow sensors, and/or many other sensors deployed to monitor well related parameters external to the casing.', 'The control system \n42\n also may comprise various types of power supplies and/or processing systems for processing data transmitted uphole with the aid of inductive coupler system \n20\n.', 'The inductive coupler system \n20\n also may comprise many configurations of female inductive couplers and male inductive couplers.', 'In some applications, each of the female and male inductive couplers comprises a single coil.', 'However, other applications may utilize two or more coils in each of the female and male inductive couplers.', 'Various materials, e.g. various metals, also may be used to form the components of inductive coupler system \n20\n.', 'Similarly, the number of turns of each coil and the electromagnetic circuitry associated with those coils may vary according to the configuration of the inductive coupler system and the environment in which the system is operated.', 'Although the preceding description has been described herein with reference to particular means, materials and embodiments, it is not intended to be limited to the particulars disclosed herein; rather, it extends to all functionally equivalent structures, methods, and uses, such as are within the scope of the appended claims.']

['1.', 'A system for use in a well, comprising:\na well casing having an interior surface and an exterior surface;\na male inductive coupler positioned at a desired interior location within the well casing along the interior surface, the male inductive coupler comprising a male inductive coupler coil; and\na female inductive coupler separate from the well casing, sized to slide along the exterior surface, and positioned at a desired exterior location external to the well casing along the exterior surface, the female inductive coupler comprising a female inductive coupler coil;\nthe female inductive coupler coil being generally radially aligned with the male inductive coupler coil to enable inductive transfer of signals across the well casing;\nwherein an axial end of the female inductive coupler is positioned proximate and axially aligned with an axial end of a casing coupling connected to the well casing and wherein the system further comprises a spring positioned axially between the axial end of the casing coupling and the axial end of the female inductive coupler.', '2.', 'The system as recited in claim 1, wherein the male inductive coupler and the female inductive coupler cooperate to transmit telemetry data signals across the well casing.', '3.', 'The system as recited in claim 1, wherein the male inductive coupler and the female inductive coupler cooperate to transmit power signals across the well casing.', '4.', 'The system as recited in claim 1, wherein the male inductive coupler comprises a second male inductive coupler coil and the female inductive coupler comprises a second female inductive coupler coil generally radially aligned with the second male inductive coupler coil.', '5.', 'The system as recited in claim 4, wherein the male inductive coupler and the female inductive coupler cooperate to transmit telemetry data signals and power signals across the well casing.', '6.', 'The system as recited in claim 1, further comprising a sensor coupled to the female inductive coupler.', '7.', 'The system as recited in claim 6, further comprising a protection device slid onto the casing, disposed adjacent an axial end of the female inductive coupler, and positioned to protect the sensor.\n\n\n\n\n\n\n8.', 'A system for use in a well, comprising:\na well casing having an interior surface and an exterior surface;\na male inductive coupler positioned at a desired interior location within the well casing along the interior surface, the male inductive coupler comprising a male inductive coupler coil; and\na female inductive coupler separate from the well casing, sized to slide along the exterior surface, and positioned at a desired exterior location external to the well casing along the exterior surface, the female inductive coupler comprising a female inductive coupler coil;\nthe female inductive coupler coil being generally radially aligned with the male inductive coupler coil to enable inductive transfer of signals across the well casing;\nwherein the female inductive coupler further comprises:\nan inner metal tube; and\nan outer metal tube, the inner metal tube and the outer metal tube being positioned radially inward and radially outward, respectively, of the female inductive coupler coil.', '9.', 'A method of inductively transferring signals in a well environment, comprising:\nlocating a first inductive coil of a first inductive coupler along an interior of a well casing;\nsliding a second inductive coil of a second inductive coupler along an exterior of the well casing until generally radially aligned with the first inductive coil;\ncoupling a sensor to the second inductive coupler; and\nfurther comprising forming the second inductive coupler by:\nplacing the second inductive coil between spacers positioned at axial ends of the second inductive coil;\npositioning a magnetic core around the second inductive coil; and\nlocating the second inductive coil and the magnetic core radially between an inner metallic tube and an outer metallic tube.\n\n\n\n\n\n\n10.', 'The method as recited in claim 9, further comprising using the sensor to obtain data on parameters external to the casing; and inductively transferring the data from the second inductive coil, across the well casing, and to the first inductive coil.', '11.', 'The method as recited in claim 10, further comprising transferring power across the well casing between the first and second inductive coils to power the sensor positioned external to the well casing.\n\n\n\n\n\n\n12.', 'The method as recited in claim 9, wherein coupling comprises coupling the sensor to the second inductive coupler with a cable.', '13.', 'The method as recited in claim 9, wherein sliding comprises positioning the second inductive coupler by sliding the second inductive coupler until further motion is blocked by an abutment formed by an axial end of a casing coupling connected to the well casing.\n\n\n\n\n\n\n14.', 'The method as recited in claim 9, further comprising forming each of the first inductive coil and the second inductive coil as a plurality of axially separated inductive coils.', '15.', 'A method comprising:\nforming a female inductive coupler with a coil and a magnetic core positioned axially between a pair spacers and radially between a pair of metallic tubes;\nsliding the female inductive coupler along an exterior of a casing until further sliding motion is blocked by an abutment; and\nsecuring the female inductive coupler on the casing via a casing coupling by torqueing the casing coupling sufficiently to hold the female inductive coupler in compression axially between the casing coupling and the abutment.', '16.', 'The method as recited in claim 15, further comprising moving a male inductive coupler along an interior of the casing to a location radially inward of the position at which the female inductive coupler is secured on the casing.', '17.', 'The method as recited in claim 15, wherein a spring is positioned between the abutment and the female inductive coupler.']

['FIG.', '1 is a schematic illustration of an example of an inductive coupler located along a well casing deployed in a wellbore, the inductive coupler being connected to an electrical device, according to an embodiment of the disclosure.', '; FIG.', '2 is a schematic illustration of an inductive coupler electrical model, according to an embodiment of the disclosure.', '; FIG.', '3 is an orthogonal view of an example of an inductive coupler positioned on casing with an associated electrical device, according to an embodiment of the disclosure.', '; FIG.', '4 is a cross-sectional view of an example of an inductive coupler assembly, according to an embodiment of the disclosure.', '; FIG.', '5 is a cross-sectional view of another example of an inductive coupler positioned along a casing, according to an embodiment of the disclosure.', '; FIG.', '6 is an exploded view of an example of a female inductive coupler assembly and casing section, according to an embodiment of the disclosure.', '; FIG. 7 is an orthogonal view of an example of a section of casing connected to a casing coupling, according to an embodiment of the disclosure.', '; FIG. 8 is an orthogonal view of an example of a female inductive coupler slid onto the section of casing illustrated in FIG. 7, according to an embodiment of the disclosure.', '; FIG.', '9 is an enlarged orthogonal view of a spring member which may be disposed between the female inductive coupler and the casing coupling, according to an embodiment of the disclosure.', '; FIG.', '10 is an orthogonal view of an example of a female inductive coupler and an electrical device with a device protector slid onto the section of casing illustrated in FIG.', '7, according to an embodiment of the disclosure.', '; FIG.', '11 is an orthogonal view similar to that of FIG.', '10', 'but showing a second casing coupling securing the female inductive coupler and the sensor/device protector on the section of casing, according to an embodiment of the disclosure.']

US11803530

Converting uni-temporal data to cloud based multi-temporal data

Dec 16, 2020

Abhay Dutt Paroha, Chinmoy Mohanty, Naman Bairagi

SCHLUMBERGER TECHNOLOGY CORPORATION

NPL References not found.

20130018849; January 17, 2013; Johnston; 20140214896; July 31, 2014; Hotta; 20140222843; August 7, 2014; Sareen; 20150156213; June 4, 2015; Baker; 20160050269; February 18, 2016; Botticelli; 20160125053; May 5, 2016; Willson; 20160328432; November 10, 2016; Raghunathan; 20180329967; November 15, 2018; Lee; 20210174013; June 10, 2021; Harada

Foreign Citations not found.

['A method includes receiving configuration data that maps an agent of a source computing system to a node of a graph, maps the node to a table, and maps the agent to an agent topic; and receiving time series data at the agent topic as uni-temporal data from the agent mapped to the node.', 'The method further includes generating a row key, from the configuration data and for the time series data, that includes a value identifier and an acquisition time value; and generating a column identifier, from the configuration data and for the time series data from the agent, that includes a version time value identifying when the time series data is received.', 'The method further includes forming the table as a multi-temporal table by storing the time series data in the table with the row key and with the column identifier.']

['Description\n\n\n\n\n\n\nThis application claims the benefit of India Patent Application No. 201921052724 filed on Dec. 18, 2019 and is hereby incorporated by reference in its entirety.', 'BACKGROUND', 'Well logs record multiple properties of a borehole of a well.', 'The data in well logs may be changed to more accurately reflect the properties recorded in the well log.', 'A challenge is to keep track of the large amounts of data that is continuously growing and being updated as well as servicing the flow of data through networks of computing systems.', 'SUMMARY\n \nIn general, in one or more aspects, the disclosure relates to a method that includes receiving configuration data that maps an agent of a source computing system to a node of a graph, maps the node to a table, and maps the agent to an agent topic; and receiving time series data at the agent topic as uni-temporal data from the agent mapped to the node.', 'The method further includes generating a row key, from the configuration data and for the time series data, that includes a value identifier and an acquisition time value, the value identifier describing a meaning of the time series data and the acquisition time value identifying when the time series data is acquired by the source computing system; and generating a column identifier, from the configuration data and for the time series data from the agent, that includes a version time value identifying when the time series data is received.', 'The method further includes forming the table as a multi-temporal table by storing the time series data in the table with the row key and with the column identifier, the table being mapped to the node that is mapped to the agent.', 'BRIEF DESCRIPTION OF DRAWINGS\n \nFIG.', '1\n shows a diagram of a system in accordance with disclosed embodiments.\n \nFIG.', '2\n shows a diagram of a system in accordance with disclosed embodiments.\n \nFIG.', '3\n.', '1\n, \nFIG.', '3\n.', '2\n, and \nFIG.', '3\n.\n3\n show flowcharts in accordance with disclosed embodiments.', 'FIG.', '4\n.', '1\n, \nFIG.', '4\n.', '2\n, \nFIG.', '4\n.', '3\n, \nFIG.', '4\n.', '4\n, \nFIG.', '5\n, and \nFIG.', '6\n show examples in accordance with disclosed embodiments.\n \nFIG.', '7\n.', '1\n and \nFIG.', '7\n.\n2\n show computing systems in accordance with disclosed embodiments.', 'DETAILED DESCRIPTION\n \nSpecific embodiments will now be described in detail with reference to the accompanying figures.', 'Like elements in the various figures are denoted by like reference numerals for consistency.', 'In the following detailed description of embodiments of the technology, numerous specific details are set forth in order to provide a more thorough understanding.', 'However, it will be apparent to one of ordinary skill in the art that various embodiments may be practiced without these specific details.', 'In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description.', 'Throughout the application, ordinal numbers (e.g., first, second, third, etc.) may be used as an adjective for an element (i.e., any noun in the application).', 'The use of ordinal numbers is not to imply or create any particular ordering of the elements nor to limit any element to be a single element unless expressly disclosed, such as by the use of the terms “before”, “after”, “single”, and other such terminology.', 'Rather, the use of ordinal numbers is to distinguish between the elements.', 'By way of an example, a first element is distinct from a second element, and the first element may encompass more than one element and succeed (or precede) the second element in an ordering of elements.', 'In general, uni-temporal time series data from wells is received from agents and converted to multi-temporal time series data.', 'The data may be pulled from or pushed by the agents and may be provided on demand.', 'Additionally, the agents provide structure data that identifies the well entities (e.g., fields, batteries, and wells) of the well data and is mapped to a hierarchical graph.', 'The multi-temporal well data and the graphs may be accessed based on the different versions and dates and times that the well data and structure data were received by the system.', 'Uni-temporal data may include time series data and structure data.', 'Time series data includes data points indexed, listed, or graphed in time order and may be at successive equally spaced points in time.', 'Uni-temporal data may have a single axis of time or version.', 'The time series data may form part of a well log and include measurements of properties of a well and borehole.', 'As an example, uni-temporal data may be time series data retrieved from a data source without identifying the version of the time series data or without identifying the retrieval date and time.', 'A subsequent retrieval of same time series from the data source may include data with different values based on updates made to the time series data by operators of the data source.', 'The data source may not identify that the time series has changed.', 'Multi-temporal data may include time series data and structure data from the uni-temporal data.', 'Multi-temporal data includes additional axes for the time or the version of the data that distinguishes multiple sets of the same data.', 'As an example, multi-temporal data may be generated from the same time series data retrieved from the data source, but which includes a version or retrieval date and time for the time series.', 'A subsequent retrieval of same time series may be identified by a different version or different date and time.', 'Differences between a previous version of the time series and a subsequent version of the time series may be identified by comparing the previous and subsequent versions of the multi-temporal time series data in contrast to the uni-temporal time series data, which may not allow for such comparison.', 'Turning now to the Figures, \nFIG.', '1\n depicts a schematic view, partially in cross section, of an onshore field (\n101\n) and an offshore field (\n102\n) in which one or more embodiments may be implemented.', 'The embodiments of \nFIG.', '1\n may include the features and embodiments described in \nFIGS. \n2\n, \n3\n.\n1\n, \n3\n.\n2\n, \n3\n.\n3\n, \n4\n, \n5\n, \n6\n, \n7\n.\n1\n, and \n7\n.\n2\n.', 'One or more of the modules and elements shown in \nFIG.', '1\n may be omitted, repeated, and/or substituted.', 'Accordingly, embodiments should not be considered limited to the specific arrangement of modules shown in \nFIG.', '1\n.', 'As shown in \nFIG.', '1\n, the fields (\n101\n), (\n102\n) include a geologic sedimentary basin (\n106\n), wellsite systems (\n192\n), (\n193\n), (\n195\n), (\n197\n), wellbores (\n112\n), (\n113\n), (\n115\n), (\n117\n), data acquisition tools (\n121\n), (\n123\n), (\n125\n), (\n127\n), surface units (\n141\n), (\n145\n), (\n147\n), well rigs (\n132\n), (\n133\n), (\n135\n), production equipment (\n137\n), surface storage tanks (\n150\n), production pipelines (\n153\n), and an E&P computer system (\n180\n) connected to the data acquisition tools (\n121\n), (\n123\n), (\n125\n), (\n127\n), through communication links (\n171\n) managed by a communication relay (\n170\n).', 'The geologic sedimentary basin (\n106\n) contains subterranean formations.', 'As shown in \nFIG. \n1\n, the subterranean formations may include several geological layers (\n106\n-\n1\n through \n106\n-\n6\n).', 'As shown, the formation may include a basement layer (\n106\n-\n1\n), one or more shale layers (\n106\n-\n2\n, \n106\n-\n4\n, \n106\n-\n6\n), a limestone layer (\n106\n-\n3\n), a sandstone layer (\n106\n-\n5\n), and any other geological layer.', 'A fault plane (\n107\n) may extend through the formations.', 'In particular, the geologic sedimentary basin includes rock formations and may include at least one reservoir including fluids, for example the sandstone layer (\n106\n-\n5\n).', 'The rock formations may include at least one seal rock, for example, the shale layer (\n106\n-\n6\n), which may act as a top seal.', 'The rock formations may include at least one source rock, for example the shale layer (\n106\n-\n4\n), which may act as a hydrocarbon generation source.', 'The geologic sedimentary basin (\n106\n) may further contain hydrocarbon or other fluids accumulations associated with certain features of the subsurface formations.', 'For example, accumulations (\n108\n-\n2\n), (\n108\n-\n5\n), and (\n108\n-\n7\n) associated with structural high areas of the reservoir layer (\n106\n-\n5\n) and containing gas, oil, water or any combination of these fluids.', 'Data acquisition tools (\n121\n), (\n123\n), (\n125\n), and (\n127\n), may be positioned at various locations along the field (\n101\n) or field (\n102\n) for collecting data from the subterranean formations of the geologic sedimentary basin (\n106\n), referred to as survey or logging operations.', 'In particular, various data acquisition tools are adapted to measure the formation and detect the physical properties of the rocks, subsurface formations, fluids contained within the rock matrix and the geological structures of the formation.', 'For example, data plots (\n161\n), (\n162\n), (\n165\n), and (\n167\n) are depicted along the fields (\n101\n) and (\n102\n) to demonstrate the data generated by the data acquisition tools.', 'Specifically, the static data plot (\n161\n) is a seismic two-way response time.', 'Static data plot (\n162\n) is core sample data measured from a core sample of any of subterranean formations (\n106\n-\n1\n to \n106\n-\n6\n).', 'Static data plot (\n165\n) is a logging trace, referred to as a well log.', 'Production decline curve or graph (\n167\n) is a dynamic data plot of the fluid flow rate over time.', 'Other data may also be collected, such as historical data, analyst user inputs, economic information, and/or other measurement data and other parameters of interest.', 'The acquisition of data shown in \nFIG.', '1\n may be performed at various stages of planning a well.', 'For example, during early exploration stages, seismic data (\n161\n) may be gathered from the surface to identify possible locations of hydrocarbons.', 'The seismic data may be gathered using a seismic source that generates a controlled amount of seismic energy.', 'In other words, the seismic source and corresponding sensors (\n121\n) are an example of a data acquisition tool.', 'An example of seismic data acquisition tool is a seismic acquisition vessel (\n141\n) that generates and sends seismic waves below the surface of the earth.', 'Sensors (\n121\n) and other equipment located at the field may include functionality to detect the resulting raw seismic signal and transmit raw seismic data to a surface unit (\n141\n).', 'The resulting raw seismic data may include effects of seismic wave reflecting from the subterranean formations (\n106\n-\n1\n to \n106\n-\n6\n).', 'After gathering the seismic data and analyzing the seismic data, additional data acquisition tools may be employed to gather additional data.', 'Data acquisition may be performed at various stages in the process.', 'The data acquisition and corresponding analysis may be used to determine where and how to perform drilling, production, and completion operations to gather downhole hydrocarbons from the field.', 'Generally, survey operations, wellbore operations and production operations are referred to as field operations of the field (\n101\n) or (\n102\n).', 'These field operations may be performed as directed by the surface units (\n141\n), (\n145\n), (\n147\n).', 'For example, the field operation equipment may be controlled by a field operation control signal that is sent from the surface unit.', 'Further as shown in \nFIG.', '1\n, the fields (\n101\n) and (\n102\n) include one or more wellsite systems (\n192\n), (\n193\n), (\n195\n), and (\n197\n).', 'A wellsite system is associated with a rig or a production equipment, a wellbore, and other wellsite equipment configured to perform wellbore operations, such as logging, drilling, fracturing, production, or other applicable operations.', 'For example, the wellsite system (\n192\n) is associated with a rig (\n132\n), a wellbore (\n112\n), and drilling equipment to perform drilling operation (\n122\n).', 'A wellsite system may be connected to a production equipment.', 'For example, the well system (\n197\n) is connected to the surface storage tank (\n150\n) through the fluids transport pipeline (\n153\n).', 'The surface units (\n141\n), (\n145\n), and (\n147\n), may be operatively coupled to the data acquisition tools (\n121\n), (\n123\n), (\n125\n), (\n127\n), and/or the wellsite systems (\n192\n), (\n193\n), (\n195\n), and (\n197\n).', 'In particular, the surface unit is configured to send commands to the data acquisition tools and/or the wellsite systems and to receive data therefrom.', 'The surface units may be located at the wellsite system and/or remote locations.', 'The surface units may be provided with computer facilities (e.g., an E&P computer system) for receiving, storing, processing, and/or analyzing data from the data acquisition tools, the wellsite systems, and/or other parts of the field (\n101\n) or (\n102\n).', 'The surface unit may also be provided with, or have functionality for actuating, mechanisms of the wellsite system components.', 'The surface unit may then send command signals to the wellsite system components in response to data received, stored, processed, and/or analyzed, for example, to control and/or optimize various field operations described above.', 'The surface units (\n141\n), (\n145\n), and (\n147\n) may be communicatively coupled to the E&P computer system (\n180\n) via the communication links (\n171\n).', 'The communication between the surface units and the E&P computer system may be managed through a communication relay (\n170\n).', 'For example, a satellite, tower antenna or any other type of communication relay may be used to gather data from multiple surface units and transfer the data to a remote E&P computer system for further analysis.', 'Generally, the E&P computer system is configured to analyze, model, control, optimize, or perform management tasks of the aforementioned field operations based on the data provided from the surface unit.', 'The E&P computer system (\n180\n) may be provided with functionality for manipulating and analyzing the data, such as analyzing seismic data to determine locations of hydrocarbons in the geologic sedimentary basin (\n106\n) or performing simulation, planning, and optimization of E&P operations of the wellsite system.', 'The results generated by the E&P computer system may be displayed for user to view the results in a two-dimensional (2D) display, three-dimensional (3D) display, or other suitable displays.', 'Although the surface units are shown as separate from the E&P computer system in \nFIG.', '1\n, in other examples, the surface unit and the E&P computer system may also be combined.', 'The E&P computer system and/or surface unit may correspond to a computing system, such as the computing system shown in \nFIGS.', '7\n.', '1\n and \n7\n.', '2\n and described below.', 'FIG.', '2\n shows a diagram of embodiments in accordance with the disclosure.', 'The embodiments of \nFIG.', '2\n may include the features and embodiments described in \nFIGS. \n1\n, \n3\n.\n1\n, \n3\n.\n2\n, \n3\n.\n3\n, \n4\n, \n5\n, \n6\n, \n7\n.\n1\n, and \n7\n.\n2\n.', 'The various elements, systems, and components shown in \nFIG.', '2\n may be omitted, repeated, combined, and/or altered as shown from \nFIG.', '2\n.', 'Accordingly, the scope of the present disclosure should not be considered limited to the specific arrangements shown in \nFIG.', '2\n.', 'Turning to \nFIG.', '2\n, the system (\n200\n) includes the cloud computing system (\n222\n) that converts uni-temporal data to multi-temporal data.', 'The cloud computing system (\n222\n) includes the server application (\n224\n).', 'The server application (\n224\n) includes the configuration component (\n226\n), ingestion component (\n234\n), and the consumption component (\n236\n).', 'The system (\n200\n) may include the features and embodiments described in \nFIGS.', '1\n, \n3\n.', '1\n, \n3\n.', '2\n, \n3\n.', '3\n, \n4\n, \n5\n, \n6\n, \n7\n.', '1\n, and \n7\n.', '2\n.', 'The configuration component (\n226\n) is a set of programs on the cloud computing system (\n222\n).', 'The configuration component (\n226\n) controls the import of uni-temporal data as multi-temporal data.', 'The configuration component (\n226\n) includes the data gateway (\n232\n) and the configuration gateway (\n230\n).', 'The configuration component (\n226\n) may receive configuration data that is used to control the conversion of uni-temporal data to multi-temporal data.', 'The configuration data may specify the configuration gateway (\n230\n) and the data gateway (\n232\n) as the gateways to which the agent (\n206\n) of the source computing system (\n204\n) transmits information.', 'The configuration data may also identify databases in the repository (\n218\n) into which data from the agent (\n206\n) is stored.', 'The configuration gateway (\n230\n) is a set of programs on the cloud computing system (\n222\n) that receives structure data that is analyzed and processed by the configuration component (\n226\n).', 'The data gateway (\n232\n) is a set of programs on the cloud computing system (\n222\n) that receives uni-temporal data and passes the uni-temporal data to the ingestion component (\n234\n).', 'The data gateway (\n232\n) and the configuration gateway (\n230\n) may be third party components provided by a cloud components provider hosting the cloud computing system (\n222\n).', 'The data gateway (\n232\n) and the configuration gateway (\n230\n) may receive data at agent topics.', 'An agent topic may be a uniform resource locator (URL) and port number to which an agent transmits information, including time series data and structure data.', 'The agent topics for the data gateway (\n232\n) and the configuration gateway (\n230\n) may be unique to the agent (\n206\n).', 'The time series data may include data from the surface units (\n141\n), (\n145\n), and (\n147\n) and the wellsite systems (\n192\n), (\n193\n), (\n195\n), and (\n197\n) of \nFIG. \n1\n.', 'The ingestion component (\n234\n) is a set of programs on the cloud computing system (\n222\n).', 'The ingestion component (\n234\n) receives uni-temporal data and stores the data as multi-temporal data.', 'The ingestion component (\n234\n) converts data by tagging the uni-temporal data with a version that may identify when the data is received by the cloud computing system (\n222\n).', 'The ingestion component (\n234\n) may also include programs for scheduling the retrieval of data from the source computing system (\n204\n).', 'The consumption component (\n236\n) is a set of programs on the cloud computing system (\n222\n).', 'The consumption component (\n236\n) provides the multi-temporal time series data and multi-temporal structure data in response to queries from external programs, applications, and services.', 'The consumption component (\n236\n) may expose multiple application programming interfaces (APIs) to access, using requests and queries, time series data and structure data (e.g., graphs) stored on the repository (\n218\n).', 'The cloud computing system (\n222\n) is an embodiment of the computing system (\n700\n) and the nodes (\n722\n) and (\n724\n) of \nFIG.', '7\n.', '1\n and \nFIG.', '7\n.', '2\n.', 'The cloud computing system (\n222\n) includes the server application (\n224\n).', 'The cloud computing system (\n222\n) may be operated by an oilfield services provider to retrieve, convert, and store uni-temporal data from the source computing system (\n204\n) as multi-temporal data in the repository (\n218\n).', 'The server application (\n224\n) is a set of programs on the cloud computing system (\n222\n) that manages and maintains time series data and structure data from the source computing system.', 'The server application (\n224\n) may convert time series data and structure data from uni-temporal data to multi-temporal data with the ingestion component (\n234\n) and provide access to the multi-temporal data to external programs, including the client application (\n216\n).', 'The server application (\n224\n) may form a Software-as-a-Service (Saas) platform and utilize container based deployment, event-driven protocols, non-blocking input output (I/O) models, NoSQL (no structured query language) data modelling, representational state transfer application programming interface (RESTful API) design, etc.', 'The programs that form the server application (\n224\n) may be deployed in local containers on the cloud computing system (\n222\n).', 'The source computing system (\n204\n) provides data to the cloud computing system (\n222\n) and includes the agent (\n206\n).', 'The source computing system (\n204\n) may be an embodiment of the surface units (\n141\n), (\n145\n), and (\n147\n) and the wellsite systems (\n192\n), (\n193\n), (\n195\n), and (\n197\n) of \nFIG.', '1\n.', 'The agent (\n206\n) set of programs on the source computing system (\n204\n).', 'The agent (\n206\n) may expose an application programming interface (API) utilized by services and applications (including the server application (\n224\n)) to retrieve data that is stored or acquired with the source computing system (\n204\n).', 'The client device (\n214\n) is an embodiment of the computing system (\n700\n) and the nodes (\n722\n) and (\n724\n) of \nFIG.', '7\n.', '1\n and \nFIG.', '7\n.', '2\n.', 'The client device (\n214\n) includes the client application (\n216\n) for accessing the server application (\n224\n).', 'The client application (\n216\n) may include a graphical user interface for interacting with the server application (\n224\n).', 'A user may operate the client application (\n216\n) to generate configuration data that configures the tagging, conversion, and storage of the uni-temporal data as multi-temporal data.', 'Additionally, users may operate the client application (\n216\n) to consume multi-temporal data through the consumption component (\n236\n) using one or more queries.', 'The client application (\n216\n) may be a web browser that accesses the server application (\n224\n) using web pages hosted by the cloud computing system (\n222\n).', 'Additionally, the client application (\n216\n) may be a web service that communicates with the server application (\n224\n) using a representational state transfer application programming interface (RESTful API).', 'Although a client server architecture is shown, one or more parts of the server application (\n224\n) may be a local application on the client device without departing from the claimed scope.', 'The repository (\n218\n) is a computing system that may include multiple computing devices in accordance with the computing system (\n700\n) and the nodes (\n722\n) and (\n724\n) described below in \nFIGS.', '7\n.', '1\n and \n7\n.', '2\n.', 'The repository (\n218\n) may be hosted by a cloud service provider for the oilfield services provider.', 'The cloud service provider may provide hosting, virtualization, and data storage services as well as other cloud services and the oilfield services provider may operate and control the data, programs, and applications that convert the uni-temporal data to multi-temporal data.', 'The data in the repository (\n218\n) may include multiple versions of time series data, structure data, and configuration data for multiple wells of multiple geographic locations.', 'The data in the repository (\n218\n) may be processed by programs executing on the cloud computing system (\n222\n) as described below.', 'The repository (\n218\n) may be hosted by the same cloud services provider as the cloud computing system (\n222\n).', 'The repository (\n218\n) may include multiple databases.', 'A time series database may store time series data, a structure database may store structure data, and a configuration database may store configuration data.', 'The time series database may use row keys and column identifiers to store the time series data.', 'Different tables in the time series database may be used to store the time series data for different nodes of the graphs defined by the configuration data and stored in the structure data.', 'Row keys may include value identifiers and acquisition time values.', 'A value identifier may describe a meaning of the time series data by identifying the property measured with the time series data.', 'The properties may include the amount of oil produced at the well and measurements of physical properties of the well and borehole.', 'The acquisition time value may identify when the time series data is acquired by the source computing system (\n204\n).', 'The column identifiers may include a version time value identifying when the time series is received by the server application.', 'The version time value may also identify the version of the time series data.', 'The column identifier may also include configuration data, such as an identifier of the node and graph to which the time series belongs, and identifier of the source computing system (\n204\n).', 'The version time value may be an unsigned integer that represents an hour of a day with a starting date of about eight thousand years before current era (BCE), e.g., midnight Jan. 1, 8000 BCE.', 'The starting date may be selected to allow for the use of historical well data.', 'The structure data may include graphs of nodes that describe entities of wells (e.g., fields, batteries, and wells).', 'The structure data may be stored in an event based format on the repository (\n218\n).', 'The events may identify when the structure data was received by the server application (\n224\n) and identify a sequence of additions and removals of nodes and edges to graphs in the repository (\n218\n).', 'A graph may contain nodes and edges that describe hierarchical relationships between the well elements for geographic locations.\n \nFIG.', '3\n.', '1\n, \nFIG.', '3\n.', '2\n, and \nFIG.', '3\n.\n3\n show flowcharts of the process (\n300\n), the process (\n320\n), and the process (\n350\n) in accordance with the disclosure for converting uni-temporal data to cloud based multi-temporal data.', 'The embodiments of \nFIGS.', '3\n.', '1\n, \n3\n.', '2\n, and \n3\n.', '3\n may be combined and may include the features and embodiments described in \nFIGS.', '1\n, \n2\n, \n4\n, \n5\n, \n6\n, \n7\n.', '1\n, and \n7\n.', '2\n.', 'While the various blocks in the flowcharts are presented and described sequentially, one of ordinary skill will appreciate that at least some of the blocks may be executed in different orders, may be combined or omitted, and at least some of the blocks may be executed in parallel.', 'Furthermore, the blocks may be performed actively or passively.', 'For example, some blocks may be performed using polling or be interrupt driven.', 'By way of an example, determination blocks may not have a processor process an instruction unless an interrupt is received to signify that condition exists.', 'As another example, determinations may be performed by performing a test, such as checking a data value to test whether the value is consistent with the tested condition.', 'Turning to \nFIG.', '3\n.', '1\n, the process (\n300\n) converts uni-temporal data to multi-temporal data.', 'In Block \n302\n, configuration data is received.', 'The configuration data may be received from a client application that may be operated by a user.', 'The client application may generate configuration data that may map agents of source systems to graph nodes of graphs, map graph nodes to tables of databases, and map agents to agent topics.', 'In Block \n304\n, time series data is received that is uni-temporal.', 'The time series data may be received at an agent topic as uni-temporal data from an agent that is mapped to a node of a graph.', 'The agent may be configured to transmit to the agent topic by receiving the agent topic from the server application.', 'The time series data that is received may not include a change log or other identification that changes to the time series data has been made.', 'The time series data may be received in response to sending a subscription request to the agent for the time series data.', 'The subscription request may identify the data that an agent is to send and when the agent is to send the data.', 'For example, the subscription request may indicate that the agent may send updates to the data when the updates are made to the data.', 'The time series data may also be received in response to scheduling and sending a periodic request to the agent for the time series data.', 'The scheduling may be maintained by a job scheduler that schedules when periodic requests are sent to agents.', 'The periodic request may indicate whether an agent is to send a full set of data or a partial set of data (e.g., the updates to the data since a previous periodic update request).', 'In Block \n306\n, row keys are generated for time series data.', 'A row key may be generated for the time series data from the configuration data.', 'The row key may include a value identifier and an acquisition time value.', 'The value identifier may describe a meaning of the time series data and be specified in the configuration data.', 'The acquisition time value may identify when the time series data is acquired by the source computing system.', 'In Block \n308\n, column identifiers are generated for time series data.', 'The column identifiers may be generated by the ingestion component from the configuration data for time series data from the agent.', 'The column identifiers may include a version time value identifying when the time series is received by the cloud computing system.', 'In Block \n310\n, tables are formed as multi-temporal tables with time series data.', 'The ingestion service may form a table in a database as a multi-temporal table by storing the time series data in the table with the row key and with the column identifier.', 'The ingestion service may identify the table as being mapped to the node that is mapped to the agent that transmitted the time series data.', 'Turning to \nFIG.', '3\n.', '2\n, the process (\n320\n) handles requests for time series data.', 'In Block \n322\n, time series requests are received.', 'A time series request may be received that requests a time series stored in a table in a database with a column identifier.', 'The time series data being requested may be previous time series data that may be a version of the time series that is not the most current version of the time series and is identified with a previous column identifier.', 'The previous column identifier may identify a date and time before the current date and time.', 'The server application may receive a time series request through the consumption component.', 'In Block \n324\n, the time series data is located in a table.', 'The consumption component may locate the time series data within the time series database of the repository.', 'The time series data may be previous time series data that is located in a table.', 'The request for the time series data may identify the requested time series data by combinations of one or more of a date, a time, a version, a property type, a measurement value, etc., of the time series data.', 'If the requesting system does not specify a date, time, or version of the time series data, the consumption component may locate the most recent version of the time series data, which may be different from the original version of the time series data.', 'By specifying the date, time, or version, a requesting system may use the same actual data of the time series data for different reports, processes, and applications that are processed at different dates and times.', 'In Block \n326\n, the time series data that was located is transmitted.', 'The time series data may be a previous time series data that is transmitted in response to the time series request.', 'The time series data may be transmitted by the consumption component of the server application to the system that transmitted to the request.', 'Turning to \nFIG.', '3\n.', '3\n, the process (\n350\n) processes graphs.', 'In Block \n352\n, graphs are stored in an event based format.', 'The graph, which may be constructed from structure data, may be stored in an event based format that includes a set of events.', 'The events may identify changes to the nodes and edges of the graphs (including the addition or removal of nodes and edges to the graphs) described in the structure data in the messages from agents, may identify the date and time of the changes, and may identify versions of the graph.', 'The events may be stored in the structure database of the repository.', 'Graphs may be constructed from the sets of events that describe the addition and removal of nodes and edges to the graphs.', 'In Block \n354\n, graph requests are received.', 'The graph request may be a previous graph request for a previous graph that is not the current graph of a set of well entities.', 'Graph requests may be received by the consumption component of the server application.', 'Graph requests may identify graphs by the dates and times and by the versions of the graphs.', 'In Block \n356\n, graphs in event-based formats are located.', 'A graph in the event based format may be located and loaded from the set of events that describe the graph.', 'The graph may be a previous graph that is not the current graph in the repository.', 'A graph may be located by identifying the set of events for a graph from an initial event and including the events with dates and times that are prior to the target date time from the graph request.', 'A graph may be loaded from the set of events by constructing the graph in memory by adding and removing the nodes and edges specified in the set up events in the order of the set of events.', 'In Block \n356\n, graphs are transmitted in response to requests.', 'A graph may be transmitted by the consumption component of the server application in response to the graph request received by the consumption component.', 'The graph may be a previous graph that is in response to a previous graph request.', 'FIG.', '4\n.', '1\n, \nFIG.', '4\n.', '2\n, \nFIG.', '4\n.', '3\n, \nFIG.', '4\n.', '4\n, \nFIG.', '5\n, and \nFIG.', '6\n show examples that may be combined and may include the features and embodiments described in \nFIGS.', '1\n, \n2\n, \n3\n.', '1\n, \n3\n.', '2\n, \n3\n.', '3\n, \n7\n.', '1\n, and \n7\n.', '2\n.', 'The various elements, widgets, components, and interfaces shown in \nFIG.', '4\n.', '1\n, \nFIG.', '4\n.', '2\n, \nFIG.', '4\n.', '3\n, \nFIG.', '4\n.', '4\n, \nFIG.', '5\n, and \nFIG.', '6\n may be omitted, repeated, combined, and/or altered as shown.', 'Accordingly, the scope of the present disclosure should not be considered limited to the specific arrangements shown in \nFIG.', '4\n.', '1\n, \nFIG.', '4\n.', '2\n, \nFIG.', '4\n.', '3\n, \nFIG.', '4\n.', '4\n, \nFIG.', '5\n, and \nFIG.', '6\n.', 'The system (\n400\n), shown with \nFIG.', '4\n.', '1\n, \nFIG.', '4\n.', '2\n, \nFIG.', '4\n.', '3\n, and \nFIG.', '4\n.', '4\n, includes the cloud computing system (\n402\n) and the source computing system (\n412\n).', 'The cloud computing system (\n402\n) includes the configuration component (\n404\n), the routing component (\n406\n), the ingestion component (\n408\n), and the consumption component (\n410\n).', 'The source computing system (\n412\n) includes the agents (\n414\n).', 'The cloud computing system (\n402\n) also includes the structure database (\n472\n), the configuration database (\n474\n), the cloud structured query language (SQL) database (\n476\n), and the big table database (\n478\n), which may be parts of one or more repositories.', 'The structure database (\n472\n) may store the structure data.', 'The configuration database (\n474\n) may store the configuration data.', 'The cloud SQL database (\n476\n) may store the job scheduling data used to schedule when data is transferred from the agents (\n414\n).', 'The big table database (\n478\n) may store the time series data from the agents (\n414\n) that is tagged and converted to multi-temporal data.', 'The configuration component (\n404\n) may handle the control and storage of configuration data and structure data with multiple programs and services.', 'The configuration component (\n404\n) may execute on the cloud computing system (\n402\n).', 'The register and configuration agent (\n403\n) is an interface that acts as a portal to the configuration component (\n403\n) and may be accessed by an external application, such as a web browser on a client device.', 'The administration and configuration user interface (UI) (\n416\n) is a set of programs in the configuration component (\n402\n).', 'The administration and configuration user interface (UI) (\n416\n) may be an application used to register and configure the agents (\n414\n).', 'The administration and configuration user interface (UI) (\n416\n) includes the agent configuration (\n417\n) and the agent registration (\n419\n), which are the configuration and registration information for the agents (\n414\n).', 'The configuration for an agent is pushed to the agent when the agent that is registered with the system is installed and activated.', 'The configuration indicates the different types of data (structure data and time series data) that may be fetched by the agents (\n414\n) and pushed to the cloud computing system (\n402\n).', 'The agents (\n414\n) may be programs of the source computing system (\n204\n) of \nFIG.', '2\n and may be programs of the surface units (\n141\n), (\n145\n), and (\n147\n) and the wellsite systems (\n192\n), (\n193\n), (\n195\n), and (\n197\n) of \nFIG.', '1\n.', 'The tag mapping service (\n418\n) may be used to manually map tag information from sources like a corporate historian into a production data integration (PDI) system.', 'The PDI system acts as a database that stores and provides data to cloud native production engineering workflows.', 'The tag information may be sent to the agents (\n414\n) using the routing component (\n406\n).', 'The type configuration service (\n420\n) may be used to store and retrieve the configuration data for the agents (\n414\n).', 'The configuration data may identify the agent topics and graph node and edge mappings for the agents (\n414\n).', 'The agent controller (\n422\n) may be a service is that registers and stores information about the agents (\n414\n).', 'As an example, the agent controller (\n422\n) may store or push the agent topics for the agents (\n414\n) in response to commands received with the administration and configuration user interface (\n416\n).', 'The structure auto import service (\n424\n) consolidates, processes, and sends messages to the structure storage service (\n428\n) for creation of new entity identifiers (field nodes, well nodes, links between fields and wells, etc.)', 'in the system, which uses an event based format to store the graphs that describe the hierarchical structure of the fields, batteries, and wells.', 'The created entity identifiers for the nodes may be sent to auto time series import service (\n426\n).', 'The auto time series import service (\n426\n) creates identifiers (with source information) for various measurements for which time series data is to be ingested.', 'The identifiers are stored in the configuration database (\n474\n).', 'When one of the agents (\n414\n) is activated, the appropriate identifier information is sent over to the agent.', 'The agent may include the identifier when pushing the time series data to the cloud computing system (\n402\n) which may include the identifier in the row key for the time series data.', 'The structure storage service (\n428\n) is a set of programs responsible for storing structure data into the structure database (\n472\n).', 'The structure storage service may receive commands from the structure auto import service (\n424\n).', 'The source reference service (\n430\n) facilitates the storage and retrieval of different information in the system, including agent registration information, measurement identifiers (also referred to as stream identifiers (IDs)), etc.', 'The agent registration information may include a serial number for an agent, an install date and time for the agent, and an activation date and time for the agent and may be stored within the configuration data in the configuration database (\n474\n).', 'The measurement identifiers identify the types of measurements in the time series data, may be used in the row key for the time series data, and may be stored within the configuration data in the configuration database (\n474\n).', 'The router service (\n432\n) functions as a router for messages (configuration, health, job updates, etc.) coming in from the agents (\n414\n).', 'The router service (\n432\n) routes the incoming messages to the appropriate services in the cloud computing system (\n402\n).', 'For example, a configuration message may include configuration data update the entities of fields or wells, for which corresponding updates need to be made to the graphs describing the fields and wells.', 'The router service (\n432\n) may pass the integration message with the configuration data to the structure auto import service (\n424\n), which updates the graphs, nodes, and edges stored in the configuration database (\n474\n) with the configuration data from the configuration message.', 'The routing component (\n406\n) may be an interface for the agents (\n414\n) and may be provided by a third-party, such as a cloud services provider hosting the cloud computing system (\n402\n).', 'The routing component (\n406\n) may execute on the cloud computing system (\n402\n).', 'The routing component (\n406\n) may receive the agent topics (\n481\n) from the agent controller (\n422\n) that are used to configure the configuration gateway (\n480\n) and the data gateway (\n482\n) that receive data from the agents (\n414\n).', 'The ingestion component (\n408\n) may handle the scheduling and storage of data from the source computing system (\n412\n).', 'The ingestion component (\n408\n) may execute on the cloud computing system (\n402\n).', 'The job scheduler (\n434\n) is a service that keeps a record of data load jobs processed by the agents (\n414\n).', 'The data load jobs may be for an entire set of data or for an incremental set of data.', 'When the agents (\n414\n) finish sessions of incremental data loads, the agents (\n414\n) send the status of the job to the job scheduler (\n434\n) through the router service (\n432\n) and the configuration gateway (\n480\n).', 'The job tracker (\n436\n) schedules and sends on-demand jobs to the agents (\n414\n).', 'On-demand jobs may be non-periodic data retrieval jobs that request time series data from the agents (\n414\n).', 'The ingestion service (\n438\n) is responsible for ingesting time series data into the cloud computing system (\n402\n).', 'When the agents (\n414\n) send time series data from the source computing system (\n412\n), the ingestion service (\n438\n) transforms the uni-temporal time series data to multi-temporal data and stores the multi-temporal data in the big table database (\n478\n).', 'The consumption component (\n410\n) may handle the retrieval of structure data and time series data in response to requests from external programs and services.', 'The consumption component (\n410\n) may execute on the cloud computing system (\n402\n).', 'The structure query service (\n440\n) exposes a set of application programming interfaces (APIs) for querying structure data (entities, links, etc.) stored in the structure database (\n472\n).', 'The APIs of the structure query service (\n440\n) provide a time effective and versioned access to the structure data.', 'The time series query service (\n442\n) exposes a set of APIs for querying time series data (measurements, properties, etc.) stored in the big table database (\n478\n).', 'The APIs of the time series query service (\n442\n) provide a time effective and versioned access to the time series data.', 'Turning to \nFIG.', '5\n, the system (\n500\n) tags and stores time series data and structure data.', 'The time series data (\n502\n) may be from an agent of a source computing system and received by the ingestion component (\n504\n).', 'The time series data (\n502\n) is uni-temporal data.', 'The ingestion component (\n504\n) converts the uni-temporal time series data (\n502\n) to multi-temporal time series data that is stored in the time series repository (\n506\n).', 'The conversion may be performed by tagging the time series data (\n502\n).', 'The time series repository (\n506\n) receives the multi-temporal time series data from the ingestion component (\n504\n).', 'The time series repository (\n506\n) includes the data elements (\n522\n) through (\n534\n).', 'The data elements (\n522\n) through (\n526\n) are a first version of a time series.', 'The data elements (\n528\n) through (\n532\n) are a second version of a time series.', 'The data element (\n534\n) is part of a third version of a time series.', 'The data elements include corresponding version numbers, row key identifiers, and values.', 'For example, the data element (\n522\n) includes the version number “V1”, the row key identifier “Oil_Vol 12:00 PM”, and the value “3.4 bbl”.', 'The time series repository (\n506\n) may store the differences between different versions of a time series.', 'The current version of the time series stored in the time series repository (\n506\n), which may responsive to a request for the current data, may include the second version data elements (\n528\n) and (\n530\n) and the third version data element (\n534\n).', 'A request for the first version of data may return the first version data (\n522\n) through (\n526\n).', 'The structure data (\n552\n) may be from an agent of a source computing system and received by the configuration component (\n554\n).', 'The structure data (\n552\n) is uni-temporal data.', 'The configuration component (\n554\n) converts the uni-temporal structure data (\n552\n) to multi-temporal structure data that is event based and stored in the structure data repository (\n556\n).', 'The conversion may be performed by tagging the structure data (\n502\n).', 'The structure data repository (\n552\n) receives the multi-temporal structure data from the configuration component (\n554\n).', 'The structure data repository (\n552\n) includes the events (\n562\n) and (\n564\n).', 'The event (\n562\n) may be received in a message from an agent and the event (\n564\n) may be received in a subsequent message from an agent and include additional changes to the structure data.', 'The event (\n562\n) includes the structure data elements (\n574\n) through (\n578\n).', 'The event (\n564\n) includes the structure data elements (\n584\n) through (\n588\n).', 'The structure data elements include corresponding version numbers, and identifiers.', 'For example, the structure data elements of the event (\n562\n) include the version number “V1”.', 'The structure data element (\n574\n) includes the identifier “Well-1” to identify the node of the graph to which the data element (\n574\n) belongs.', 'The structure data element (\n576\n) includes the identifier “Battery-1”, which identifies another node of the graph.', 'The structure data element (\n578\n) identifies an edge from the node of the structure data element (\n576\n) to the node of the structure data element (\n574\n), i.e., a link from “Battery-1” to “Well-1”.', 'A structure query for the most current graph may include a graph constructed from the structure data elements from the events (\n562\n) and (\n564\n).', 'A structure query for a previous graph may include a graph constructed from the structured data of the event (\n562\n).', 'Turning to \nFIG.', '6\n, the graphical user interface (\n600\n) is displayed on a computing system, such as those described in the other Figures, including the E&P computer system (\n180\n), the client device (\n214\n), and the computing system (\n700\n) of \nFIGS.', '1\n, \n2\n, and \n7\n.', '1\n.', 'The graphical user interface (\n600\n) includes the time series view (\n602\n) and the graph view (\n652\n).', 'The time series view (\n602\n) includes the table (\n604\n) with the rows (\n606\n) through (\n612\n) and the columns (\n614\n) through (\n620\n).', 'The row (\n606\n) is a header row that shows the column identifiers for the columns (\n614\n) through (\n620\n).', 'The column (\n614\n) is a header column that shows the row keys for the rows (\n608\n) through (\n612\n).', 'The row keys for the rows (\n608\n) through (\n612\n) include value identifiers and acquisition time values.', 'The row (\n608\n) is the oil volume at 12:00 PM on the acquisition date; the row (\n610\n) is the oil volume at 14:00 PM on the acquisition date; and the row (\n612\n) is the oil volume at 15:00 PM on the acquisition date.', 'The column identifiers for the columns (\n616\n) through (\n620\n) include version time values.', 'The column (\n616\n) is for the time series that was received on October 12 at 1:00 PM, the column (\n618\n) is for the time series that was received on October 13 at 1:00 PM, and the column (\n620\n) is for the time series that was received on October 14 at 1:00 PM.', 'The original acquisition date may be before the initial retrieval date, e.g., the original acquisition date may be on October 11.', 'The column (\n616\n) may be returned in response to a request for the first version of the data and the columns (\n618\n) and (\n620\n) may be returned in response to requests for subsequent versions of the data.', 'The table (\n604\n) only shows data in cells where the value is changed between versions of the time series.', 'The blank cells in the column (\n620\n) indicate that the values for those rows did not change from the version of the column (\n618\n) to the version of the column (\n620\n).', 'The graph view (\n652\n) shows two versions of a graph.', 'The version tag (\n654\n) indicates that the graph (\n658\n) was generated on October 12 at 1:00 PM.', 'The version tag (\n656\n) indicates that the graph (\n660\n) was generated on October 13 at 1:00 PM.', 'The graphs (\n658\n) and (\n660\n) are reconstructed from an event based format from a structure data repository.', 'A node “Well-2”, a node for “Well-3”, an edges from “Battery-1” to “Well-2”, and an edge from “Battery-2” to “Well-3” are added to the graph (\n660\n) and were not in the graph (\n658\n).', 'Embodiments disclosed herein may be implemented on a computing system.', 'Any combination of mobile, desktop, server, router, switch, embedded device, or other types of hardware may be used.', 'For example, as shown in \nFIG. \n7\n.\n1\n, the computing system (\n700\n) may include one or more computer processors (\n702\n), non-persistent storage (\n704\n) (e.g., volatile memory, such as random access memory (RAM), cache memory), persistent storage (\n706\n) (e.g., a hard disk, an optical drive such as a compact disk (CD) drive or digital versatile disk (DVD) drive, a flash memory, etc.), a communication interface (\n712\n) (e.g., Bluetooth interface, infrared interface, network interface, optical interface, etc.), and numerous other elements and functionalities.', 'The computer processor(s) (\n702\n) may be an integrated circuit for processing instructions.', 'For example, the computer processor(s) may be one or more cores or micro-cores of a processor.', 'The computing system (\n700\n) may also include one or more input devices (\n710\n), such as a touchscreen, keyboard, mouse, microphone, touchpad, electronic pen, or any other type of input device.', 'The communication interface (\n712\n) may include an integrated circuit for connecting the computing system (\n700\n) to a network (not shown) (e.g., a local area network (LAN), a wide area network (WAN) such as the Internet, mobile network, or any other type of network) and/or to another device, such as another computing device.', 'Further, the computing system (\n700\n) may include one or more output devices (\n708\n), such as a screen (e.g., a liquid crystal display (LCD), a plasma display, touchscreen, cathode ray tube (CRT) monitor, projector, or other display device), a printer, external storage, or any other output device.', 'One or more of the output devices may be the same or different from the input device(s).', 'The input and output device(s) may be locally or remotely connected to the computer processor(s) (\n702\n), non-persistent storage (\n704\n), and persistent storage (\n706\n).', 'Many different types of computing systems exist, and the aforementioned input and output device(s) may take other forms.', 'Software instructions in the form of computer readable program code to perform embodiments of the technology may be stored, in whole or in part, temporarily or permanently, on a non-transitory computer readable medium such as a CD, DVD, storage device, a diskette, a tape, flash memory, physical memory, or any other computer readable storage medium.', 'Specifically, the software instructions may correspond to computer readable program code that, when executed by a processor(s), is configured to perform one or more embodiments of the technology.', 'The computing system (\n700\n) in \nFIG.', '7\n.\n1\n may be connected to or be a part of a network.', 'For example, as shown in \nFIG. \n7\n.', '2\n, the network (\n720\n) may include multiple nodes (e.g., node X (\n722\n), node Y (\n724\n)).', 'Each node may correspond to a computing system, such as the computing system shown in \nFIG.', '7\n.', '1\n, or a group of nodes combined may correspond to the computing system shown in \nFIG.', '7\n.', '1\n.', 'By way of an example, embodiments of the technology may be implemented on a node of a distributed system that is connected to other nodes.', 'By way of another example, embodiments of the technology may be implemented on a distributed computing system having multiple nodes, where each portion of the technology may be located on a different node within the distributed computing system.', 'Further, one or more elements of the aforementioned computing system (\n700\n) may be located at a remote location and connected to the other elements over a network.', 'Although not shown in \nFIG. \n7\n.\n2\n, the node may correspond to a blade in a server chassis that is connected to other nodes via a backplane.', 'By way of another example, the node may correspond to a server in a data center.', 'By way of another example, the node may correspond to a computer processor or micro-core of a computer processor with shared memory and/or resources.', 'The nodes (e.g., node X (\n722\n), node Y (\n724\n)) in the network (\n720\n) may be configured to provide services for a client device (\n726\n).', 'For example, the nodes may be part of a cloud computing system.', 'The nodes may include functionality to receive requests from the client device (\n726\n) and transmit responses to the client device (\n726\n).', 'The client device (\n726\n) may be a computing system, such as the computing system shown in \nFIG.', '7\n.', '1\n.', 'Further, the client device (\n726\n) may include and/or perform all or a portion of one or more embodiments of the technology.', 'The computing system or group of computing systems described in \nFIGS.', '7\n.', '1\n and \n7\n.', '2\n may include functionality to perform a variety of operations disclosed herein.', 'For example, the computing system(s) may perform communication between processes on the same or different system.', 'A variety of mechanisms, employing some form of active or passive communication, may facilitate the exchange of data between processes on the same device.', 'Examples representative of these inter-process communications include, but are not limited to, the implementation of a file, a signal, a socket, a message queue, a pipeline, a semaphore, shared memory, message passing, and a memory-mapped file.', 'Further details pertaining to a couple of these non-limiting examples are provided below.', 'Based on the client-server networking model, sockets may serve as interfaces or communication channel end-points enabling bidirectional data transfer between processes on the same device.', 'Foremost, following the client-server networking model, a server process (e.g., a process that provides data) may create a first socket object.', 'Next, the server process binds the first socket object, thereby associating the first socket object with a unique name and/or address.', 'After creating and binding the first socket object, the server process then waits and listens for incoming connection requests from one or more client processes (e.g., processes that seek data).', 'At this point, when a client process wishes to obtain data from a server process, the client process starts by creating a second socket object.', 'The client process then proceeds to generate a connection request that includes at least the second socket object and the unique name and/or address associated with the first socket object.', 'The client process then transmits the connection request to the server process.', 'Depending on availability, the server process may accept the connection request, establishing a communication channel with the client process, or the server process, busy in handling other operations, may queue the connection request in a buffer until server process is ready.', 'An established connection informs the client process that communications may commence.', 'In response, the client process may generate a data request specifying the data that the client process wishes to obtain.', 'The data request is subsequently transmitted to the server process.', 'Upon receiving the data request, the server process analyzes the request and gathers the requested data.', 'Finally, the server process then generates a reply including at least the requested data and transmits the reply to the client process.', 'The data may be transferred, more commonly, as datagrams or a stream of characters (e.g., bytes).', 'Shared memory refers to the allocation of virtual memory space in order to substantiate a mechanism for which data may be communicated and/or accessed by multiple processes.', 'In implementing shared memory, an initializing process first creates a shareable segment in persistent or non-persistent storage.', 'Post creation, the initializing process then mounts the shareable segment, subsequently mapping the shareable segment into the address space associated with the initializing process.', 'Following the mounting, the initializing process proceeds to identify and grant access permission to one or more authorized processes that may also write and read data to and from the shareable segment.', 'Changes made to the data in the shareable segment by one process may immediately affect other processes, which are also linked to the shareable segment.', 'Further, when one of the authorized processes accesses the shareable segment, the shareable segment maps to the address space of that authorized process.', 'Often, only one authorized process may mount the shareable segment, other than the initializing process, at any given time.', 'Other techniques may be used to share data, such as the various data described in the present application, between processes without departing from the scope of the technology.', 'The processes may be part of the same or different application and may execute on the same or different computing system.', 'Rather than or in addition to sharing data between processes, the computing system performing one or more embodiments of the technology may include functionality to receive data from a user.', 'For example, a user may submit data via a graphical user interface (GUI) on the user device.', 'Data may be submitted via the graphical user interface by a user selecting one or more graphical user interface widgets or inserting text and other data into graphical user interface widgets using a touchpad, a keyboard, a mouse, or any other input device.', 'In response to selecting a particular item, information regarding the particular item may be obtained from persistent or non-persistent storage by the computer processor.', "Upon selection of the item by the user, the contents of the obtained data regarding the particular item may be displayed on the user device in response to the user's selection.", 'By way of another example, a request to obtain data regarding the particular item may be sent to a server operatively connected to the user device through a network.', 'For example, the user may select a uniform resource locator (URL) link within a web client of the user device, thereby initiating a Hypertext Transfer Protocol (HTTP) or other protocol request being sent to the network host associated with the URL.', 'In response to the request, the server may extract the data regarding the particular selected item and send the data to the device that initiated the request.', "Once the user device has received the data regarding the particular item, the contents of the received data regarding the particular item may be displayed on the user device in response to the user's selection.", 'Further to the above example, the data received from the server after selecting the URL link may provide a web page in Hyper Text Markup Language (HTML) that may be rendered by the web client and displayed on the user device.', 'Once data is obtained, such as by using techniques described above or from storage, the computing system, in performing one or more embodiments of the technology, may extract one or more data items from the obtained data.', 'For example, the extraction may be performed as follows by the computing system in \nFIG.', '7\n.', '1\n.', 'First, the organizing pattern (e.g., grammar, schema, layout) of the data is determined, which may be based on one or more of the following: position (e.g., bit or column position, Nth token in a data stream, etc.), attribute (where the attribute is associated with one or more values), or a hierarchical/tree structure (consisting of layers of nodes at different levels of detail-such as in nested packet headers or nested document sections).', 'Then, the raw, unprocessed stream of data symbols is parsed, in the context of the organizing pattern, into a stream (or layered structure) of tokens (where each token may have an associated token “type”).', 'Next, extraction criteria are used to extract one or more data items from the token stream or structure, where the extraction criteria are processed according to the organizing pattern to extract one or more tokens (or nodes from a layered structure).', 'For position-based data, the token(s) at the position(s) identified by the extraction criteria are extracted.', 'For attribute/value-based data, the token(s) and/or node(s) associated with the attribute(s) satisfying the extraction criteria are extracted.', 'For hierarchical/layered data, the token(s) associated with the node(s) matching the extraction criteria are extracted.', 'The extraction criteria may be as simple as an identifier string or may be a query presented to a structured data repository (where the data repository may be organized according to a database schema or data format, such as XML).', 'The extracted data may be used for further processing by the computing system.', 'For example, the computing system of \nFIG.', '7\n.', '1\n, while performing one or more embodiments of the technology, may perform data comparison.', 'Data comparison may be used to compare two or more data values (e.g., A, B).', 'For example, one or more embodiments may determine whether A>B, A=B, A !=B, A B, B may be subtracted from A (i.e., A−B), and the status flags may be read to determine if the result is positive (i.e., if A>B, then A−B>0).', 'In one or more embodiments, B may be considered a threshold, and A is deemed to satisfy the threshold if A=B or if A>B, as determined using the ALU.', 'In one or more embodiments of the technology, A and B may be vectors, and comparing A with B includes comparing the first element of vector A with the first element of vector B, the second element of vector A with the second element of vector B, etc.', 'In one or more embodiments, if A and B are strings, the binary values of the strings may be compared.', 'The computing system in \nFIG.', '7\n.\n1\n may implement and/or be connected to a data repository.', 'For example, one type of data repository is a database.', 'A database is a collection of information configured for ease of data retrieval, modification, re-organization, and deletion.', 'Database Management System (DBMS) is a software application that provides an interface for users to define, create, query, update, or administer databases.', 'The user, or software application, may submit a statement or query into the DBMS.', 'Then the DBMS interprets the statement.', 'The statement may be a select statement to request information, update statement, create statement, delete statement, etc.', 'Moreover, the statement may include parameters that specify data, or data container (database, table, record, column, view, etc.), identifier(s), conditions (comparison operators), functions (e.g. join, full join, count, average, etc.), sort (e.g. ascending, descending), or others.', 'The DBMS may execute the statement.', 'For example, the DBMS may access a memory buffer, a reference or index a file for read, write, deletion, or any combination thereof, for responding to the statement.', 'The DBMS may load the data from persistent or non-persistent storage and perform computations to respond to the query.', 'The DBMS may return the result(s) to the user or software application.', 'The computing system of \nFIG.', '7\n.\n1\n may include functionality to present raw and/or processed data, such as results of comparisons and other processing.', 'For example, presenting data may be accomplished through various presenting methods.', 'Specifically, data may be presented through a user interface provided by a computing device.', 'The user interface may include a GUI that displays information on a display device, such as a computer monitor or a touchscreen on a handheld computer device.', 'The GUI may include various GUI widgets that organize what data is shown as well as how data is presented to a user.', 'Furthermore, the GUI may present data directly to the user, e.g., data presented as actual data values through text, or rendered by the computing device into a visual representation of the data, such as through visualizing a data model.', 'For example, a GUI may first obtain a notification from a software application requesting that a particular data object be presented within the GUI.', 'Next, the GUI may determine a data object type associated with the particular data object, e.g., by obtaining data from a data attribute within the data object that identifies the data object type.', 'Then, the GUI may determine any rules designated for displaying that data object type, e.g., rules specified by a software framework for a data object class or according to any local parameters defined by the GUI for presenting that data object type.', 'Finally, the GUI may obtain data values from the particular data object and render a visual representation of the data values within a display device according to the designated rules for that data object type.', 'Data may also be presented through various audio methods.', 'In particular, data may be rendered into an audio format and presented as sound through one or more speakers operably connected to a computing device.', 'Data may also be presented to a user through haptic methods.', 'For example, haptic methods may include vibrations or other physical signals generated by the computing system.', 'For example, data may be presented to a user using a vibration generated by a handheld computer device with a predefined duration and intensity of the vibration to communicate the data.', 'The above description of functions presents a few examples of functions performed by the computing system of \nFIG.', '7\n.', '1\n and the nodes and/or client device in \nFIG.', '7\n.', '2\n.', 'Other functions may be performed using one or more embodiments of the technology.', 'While the technology has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope as disclosed herein.', 'Accordingly, the scope of the technology should be limited only by the attached claims.']

['1.', 'A method comprising:\nreceiving configuration data that maps an agent of a source computing system to a node of a graph, maps the node to a table, and maps the agent to an agent topic;\nreceiving time series data at the agent topic as uni-temporal data from the agent mapped to the node;\ngenerating a row key, from the configuration data and for the time series data, that includes a value identifier and an acquisition time value, the value identifier describing the time series data and the acquisition time value identifying when the time series data is acquired by the source computing system;\ngenerating a column identifier, from the configuration data and for the time series data from the agent, that includes a version time value identifying when the time series data is received;\nforming the table as a multi-temporal table with a row comprising the row key and a column comprising the column identifier by storing the time series data in the table using the acquisition time value of the row key and using the version time value of the column identifier, the table being mapped to the node that is mapped to the agent; and\npresenting the row key and the column identifier in the multi-temporal table in a graphical user interface.', '2.', 'The method of claim 1, wherein the table is a first table and the node is a first node, further comprising:\nreceiving the time series data from the agent at a data gateway with the agent topic;\nreceiving a message, which includes structure data, from the agent at a configuration gateway with a configuration topic specified in the configuration data;\nupdating the configuration data based on a structure data; and\nforming a second table that is mapped to a second node based on the updated configuration data.', '3.', 'The method of claim 1, further comprising:\nreceiving a time series request for previous time series data stored in the table with a previous column identifier;\nlocating the previous time series data in the table; and\ntransmitting the previous time series data in response to the time series request.', '4.', 'The method of claim 1, further comprising:\nstoring the graph in an event based format that includes a set of events;\nreceiving a previous graph request for a previous graph;\nlocating the previous graph in the event based format and loading the previous graph from the set of events; and\ntransmitting the previous graph in response to the previous graph request.', '5.', 'The method of claim 1, wherein the version time value is an unsigned integer that represents an hour of a day with a starting date of eight thousand years before current era.\n\n\n\n\n\n\n6.', 'The method of claim 1, further comprising:\nsending a subscription request to the agent; and\nreceiving the time series data in response to the subscription request.', '7.', 'The method of claim 1, further comprising:\nscheduling a periodic request for the agent;\nsending the periodic request to the agent; and\nreceiving the time series data in response to the periodic request.', '8.', 'A system comprising:\na memory coupled to a processor;\nan application that executes on the processor, uses the memory, and is configured for:\nreceiving, by a configuration service of the application, configuration data that maps an agent of a source computing system to a node of a graph, maps the node to a table, and maps the agent to an agent topic;\nreceiving time series data at the agent topic as uni-temporal data from the agent mapped to the node;\ngenerating, by an ingestion service of the application, a row key, from the configuration data and for the time series data, that includes a value identifier and an acquisition time value, the value identifier describing the time series data and the acquisition time value identifying when the time series data is acquired by the source computing system;\ngenerating a column identifier, from the configuration data and for the time series data from the agent, that includes a version time value identifying when the time series data is received;\nforming the table as a multi-temporal table with a row comprising the row key and a column comprising the column identifier by storing the time series data in the table using the acquisition time value of the row key and using the version time value of the column identifier, the table being mapped to the node that is mapped to the agent; and\npresenting the row key and the column identifier in the multi-temporal table in a graphical user interface.', '9.', 'The system of claim 8, wherein the table is a first table, wherein the node is a first node, and wherein the application is further configured for:\nreceiving the time series data from the agent at a data gateway with the agent topic;\nreceiving a message, which includes structure data, from the agent at a configuration gateway with a configuration topic specified in the configuration data;\nupdating the configuration data based on a structure data; and\nforming a second table that is mapped to a second node based on the updated configuration data.', '10.', 'The system of claim 8, wherein the application is further configured for:\nreceiving a time series request for previous time series data stored in the table with a previous column identifier;\nlocating the previous time series data in the table; and\ntransmitting the previous time series data in response to the time series request.', '11.', 'The system of claim 8, wherein the application is further configured for:\nstoring the graph in an event based format that includes a set of events;\nreceiving a previous graph request for a previous graph;\nlocating the previous graph in the event based format and loading the previous graph from the set of events; and\ntransmitting the previous graph in response to the previous graph request.', '12.', 'The system of claim 8, wherein the version time value is an unsigned integer that represents an hour of a day with a starting date of eight thousand years before current era.\n\n\n\n\n\n\n13.', 'The system of claim 8, wherein the application is further configured for:\nsending a subscription request to the agent; and\nreceiving the time series data in response to the subscription request.', '14.', 'The system of claim 8, wherein the application is further configured for:\nscheduling a periodic request for the agent;\nsending the periodic request to the agent; and\nreceiving the time series data in response to the periodic request.', '15.', 'A non-transitory computer readable medium comprising computer readable program code for:\nreceiving configuration data that maps an agent of a source computing system to a node of a graph, maps the node to a table, and maps the agent to an agent topic;\nreceiving time series data at the agent topic as uni-temporal data from the agent mapped to the node;\ngenerating a row key, from the configuration data and for the time series data, that includes a value identifier and an acquisition time value, the value identifier describing the time series data and the acquisition time value identifying when the time series data is acquired by the source computing system;\ngenerating a column identifier, from the configuration data and for the time series data from the agent, that includes a version time value identifying when the time series data is received;\nforming the table as a multi-temporal table with a row comprising the row key and a column comprising the column identifier by storing the time series data in the table using the acquisition time value of the row key and using the version time value of the column identifier, the table being mapped to the node that is mapped to the agent; and\npresenting the row key and the column identifier in the multi-temporal table in a graphical user interface.\n\n\n\n\n\n\n16.', 'The non-transitory computer readable medium of claim 15, wherein the table is a first table and the node is a first node, further comprising computer readable program code for:\nreceiving the time series data from the agent at a data gateway with the agent topic;\nreceiving a message, which includes structure data, from the agent at a configuration gateway with a configuration topic specified in the configuration data;\nupdating the configuration data based on a structure data; and\nforming a second table that is mapped to a second node based on the updated configuration data.', '17.', 'The non-transitory computer readable medium of claim 15, further comprising computer readable program code for:\nreceiving a time series request for previous time series data stored in the table with a previous column identifier;\nlocating the previous time series data in the table; and\ntransmitting the previous time series data in response to the time series request.', '18.', 'The non-transitory computer readable medium of claim 15, further comprising computer readable program code for:\nstoring the graph in an event based format that includes a set of events;\nreceiving a previous graph request for a previous graph;\nlocating the previous graph in the event based format and loading the previous graph from the set of events; and\ntransmitting the previous graph in response to the previous graph request.', '19.', 'The non-transitory computer readable medium of claim 15, wherein the version time value is an unsigned integer that represents an hour of a day with a starting date of eight thousand years before current era.', '20.', 'The non-transitory computer readable medium of claim 15, further comprising computer readable program code for:\nsending a subscription request to the agent; and\nreceiving the time series data in response to the subscription request.']

['FIG.', '1 shows a diagram of a system in accordance with disclosed embodiments.; FIG.', '2 shows a diagram of a system in accordance with disclosed embodiments.; FIG.', '3.1, FIG.', '3.2, and FIG.', '3.3 show flowcharts in accordance with disclosed embodiments.; FIG.', '4.1, FIG.', '4.2, FIG.', '4.3, FIG.', '4.4, FIG.', '5, and FIG.', '6 show examples in accordance with disclosed embodiments.; FIG. 7.1 and FIG.', '7.2 show computing systems in accordance with disclosed embodiments.; FIG.', '2 shows a diagram of embodiments in accordance with the disclosure.', 'The embodiments of FIG.', '2 may include the features and embodiments described in FIGS.', '1, 3.1, 3.2, 3.3, 4, 5, 6, 7.1, and 7.2.', 'The various elements, systems, and components shown in FIG. 2 may be omitted, repeated, combined, and/or altered as shown from FIG.', '2.', 'Accordingly, the scope of the present disclosure should not be considered limited to the specific arrangements shown in FIG.', '2.; FIG.', '3.1, FIG.', '3.2, and FIG.', '3.3 show flowcharts of the process (300), the process (320), and the process (350) in accordance with the disclosure for converting uni-temporal data to cloud based multi-temporal data.', 'The embodiments of FIGS. 3.1, 3.2, and 3.3 may be combined and may include the features and embodiments described in FIGS.', '1, 2, 4, 5, 6, 7.1, and 7.2.', 'While the various blocks in the flowcharts are presented and described sequentially, one of ordinary skill will appreciate that at least some of the blocks may be executed in different orders, may be combined or omitted, and at least some of the blocks may be executed in parallel.', 'Furthermore, the blocks may be performed actively or passively.', 'For example, some blocks may be performed using polling or be interrupt driven.', 'By way of an example, determination blocks may not have a processor process an instruction unless an interrupt is received to signify that condition exists.', 'As another example, determinations may be performed by performing a test, such as checking a data value to test whether the value is consistent with the tested condition.; FIG.', '4.1, FIG.', '4.2, FIG.', '4.3, FIG.', '4.4, FIG.', '5, and FIG.', '6 show examples that may be combined and may include the features and embodiments described in FIGS.', '1, 2, 3.1, 3.2, 3.3, 7.1, and 7.2.', 'The various elements, widgets, components, and interfaces shown in FIG. 4.1, FIG. 4.2, FIG. 4.3, FIG.', '4.4, FIG.', '5, and FIG.', '6 may be omitted, repeated, combined, and/or altered as shown.', 'Accordingly, the scope of the present disclosure should not be considered limited to the specific arrangements shown in FIG.', '4.1, FIG.', '4.2, FIG.', '4.3, FIG.', '4.4, FIG.', '5, and FIG.', '6.']

US11919086

Hot isostatic pressing (HIP) fabrication of multi-metallic components for pressure-controlling equipment

Dec 16, 2020

Micah Threadgill, Terry Clancy, Herman Ernesto Amaya, Christopher Nault, Thomas Berglund

No Companies Listed

Lindwall et al., “Experimental and Theoretical Investigations of Hot Isostatically Pressed-Produced Stainless Steel/High Alloy Tool Steel Compound Materials”, Metallurgical and Materials Transactions, vol. 42A, May 2011, pp. 1165-1172.; International Search Report and Written Opinion issued in International Patent application PCT/US2021/072935 dated Apr. 11, 2022, 10 pages.; Philip et al., “Ultrahigh-Strength Steels”, ASM Handbook, vol. 1—Properties and Selection: Irons, Steels, and High-Performance Alloys, pp. 430-448, 1990.; Azom, “W1 Tool Steel-Water-Hardening Tool Steel (UNS T72301)”, Jul. 16, 2013, AZoNetwork, Accessed Aug. 22, 2022) (Year: 2013), 10 pages.; Butrim et al., “Experience in HIP Diffusion Welding of Dissimilar Metals and Alloys”, Proceedings of 12th International Conference on Hot Isostatic Pressing—HIP'17, Materials Research Proceedings, vol. 10, 2019, pp. 65-72.; Jacobs, “Surface engineering of materials”, Materials & Design, Jan. 1, 1993, vol. 14, No. 1, pp. 33-37.; International Preliminary Report on Patentability issued in PCT Application No. PCT/US2021/072935 dated Jun. 29, 2023, 7 pages.

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209163772; July 2019; CN; 0740589; November 1996; EP; 2236229; July 2015; EP; 3335820; June 2018; EP; 3335820; June 2018; EP; 3335820; July 2018; EP; 3502297; June 2019; EP; S5798602; June 1982; JP; S61144229; July 1986; JP; 2010053431; May 2010; WO; 2020022464; January 2020; WO

['A multi-metallic pressure-controlling component and a hot isostatic pressure (HIP) manufacturing process and system are disclosed.', 'An example multi-metallic component for use in the oil field services industry includes a first metal alloy that forms a first portion of the multi-metallic pressure-controlling component, and a second metal alloy that forms a second portion of the multi-metallic pressure-controlling component.', 'A diffusion bond is disposed at an interface between the first metal alloy and the second metal alloy that joins the first metal alloy to the second metal alloy within the multi-metallic pressure-controlling component.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThis section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'A blowout preventer (BOP) is installed on a wellhead to seal and control an oil and gas well during various operations.', 'For example, during drilling operations, a drill string may be suspended from a rig through the BOP into a wellbore.', 'A drilling fluid is delivered through the drill string and returned up through an annulus between the drill string and a casing that lines the wellbore.', 'In the event of a rapid invasion of formation fluid in the annulus, commonly known as a “kick,” the BOP may be actuated to seal the annulus and to contain fluid pressure in the wellbore, thereby protecting well equipment positioned above the BOP.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein:\n \nFIG.', '1\n is a block diagram of a drilling system for mineral extraction, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\n is a cross-sectional top view of a portion of a blowout preventer (BOP) that may be used in the drilling system of \nFIG.', '1\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '3\n is a front isometric view of a component, namely an upper ram, that may be used in the BOP of \nFIG.', '2\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '4\n is a front isometric view of another component, namely a lower ram, that may be used in conjunction with the upper ram of \nFIG.', '3\n and the BOP of \nFIG.', '2\n, in accordance with an embodiment of the present disclosure;\n \nFIGS.', '5\n, \n6\n, \n7\n, and \n8\n are cross-sectional views of the components of \nFIGS.', '3\n and \n4\n, in accordance with various embodiments of the present disclosure;\n \nFIG.', '9\n is a block diagram of a hot isostatic pressure (HIP) manufacturing system that is configured to carry out a HIP manufacturing process to fabricate the components of \nFIGS.', '3\n and \n4\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '10\n is a flow diagram of the HIP manufacturing process, in accordance with an embodiment of the present disclosure; and\n \nFIGS.', '11\nA, \n11\nB, and \n11\nC\n are cross-sectional views of portions of a loaded canister prior to a HIP process of the HIP manufacturing process, in accordance with an embodiment of the present disclosure.', 'DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS\n \nOne or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only exemplary of the present disclosure.', 'Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Present embodiments are generally directed to systems and methods for the hot isostatic pressing (HIP) fabrication of components for use in the oil field services industry, which may relate generally to any activities (e.g., drilling, producing, monitoring, and/or maintaining) that facilitate access to and/or extraction of natural resources (e.g., hydrocarbons) from the earth.', 'The components may be any of a variety of components for use in equipment, such as pressure-containing and/or pressure-controlling equipment.', 'Present embodiments enable the production of multi-metallic (e.g., bimetallic, trimetallic) components, such as pressure-containing components and/or pressure-controlling components.', 'An example embodiment includes a HIP-fabricated multi-metallic ram of a blowout preventer (BOP).', 'A traditional BOP ram is fabricated using a subtractive manufacturing technique in which a forged block of a particular metal alloy is precisely machined into a complex shape, and then a number of conventional and unconventional heat treatments are performed to impart different material properties to different portions of the part.', 'As used herein, the term metal alloy refers to either a pure metal or a metallic solid solution including a number of different metallic and/or non-metallic chemical elements.', 'In contrast, present embodiments involve the use of a HIP-fabrication process in which different metal alloys (e.g., different metal alloy powders, different metal alloy boundary layers) are combined and sealed in a canister before being heated and pressurized during a HIP process (e.g., in an autoclave) to form a multi-metallic pressure-controlling component (e.g., a BOP ram).', 'As a result, the different metal alloys are disposed in different portions of the part to impart different material properties to these portions of the part (e.g., higher strength and hardness in a blade area of the ram, higher toughness in the body of the ram).', 'Additionally, a finite (e.g., narrow) diffusion bond forms at the interface between different metal alloys, yielding a dense, seamless pressure-controlling component.', 'It is presently recognized that the disclosed HIP manufacturing process enables substantially greater freedom of design by enabling the joining of metal alloys that may be chemically incompatible using traditional joining methods (e.g., welding).', 'Additionally, by using different metal alloys in different portions of the part, a greater range of material properties (e.g., strength, toughness, ductility, hardness, corrosion resistance) is available compared to the range of material properties achievable using a traditional, single metal alloy ram with multiple thermal processing steps.', 'Within the HIP manufacturing process, a HIP process chemically bonds powder metal into a solid part under “extreme” temperature and pressure.', 'After the HIP process is complete, the final part may be achieved with reduced processing time, compared with the traditional manufacturing techniques.', 'For example, after the HIP process has been applied to join the metal powders of the multi-metallic part, the final part may be realized with reduced machining time, with little or no welding, and without special heat treatment processes of traditional manufacturing techniques, thereby reducing manufacturing time and cost relative to traditional manufacturing techniques.', 'Furthermore, the disclosed HIP manufacturing process generally provides the capability to efficiently construct pressure-controlling equipment components having a complex shape while avoiding or reducing time-consuming and/or costly complex thermal processing, welding, and/or machining steps.', 'While the present embodiments are described in the context of a ram of a BOP for a drilling system to facilitate discussion, it should be appreciated that the systems and methods for HIP fabrication of multi-metallic components may be adapted for fabrication of other equipment, such as another component of the BOP for the drilling system and/or another component of another device for any type of system (e.g., drilling system, production system).', 'With the foregoing in mind, \nFIG.', '1\n is a block diagram of an embodiment of a drilling system \n10\n for mineral extraction.', 'The drilling system \n10\n may be configured to drill (e.g., circulate drilling mud and take drilling cuttings up to surface) for the eventual extraction of extract various minerals and natural resources, including hydrocarbons (e.g., oil and/or natural gas), from the earth and/or to inject substances into the earth.', 'The drilling system \n10\n may be a land-based system (e.g., a surface system) or an offshore system (e.g., an offshore platform system).', 'As shown, a BOP stack \n12\n may be mounted to a wellhead \n14\n, which is coupled to a mineral deposit \n16\n via a wellbore \n18\n.', 'The wellhead \n14\n may include or be coupled to any of a variety of other components such as a spool, a hanger, and a “Christmas” tree.', 'The wellhead \n14\n may return drilling fluid or mud toward a surface during drilling operations, for example.', 'Downhole operations are carried out by a conduit \n20\n (e.g., drill string) that extends through a central bore \n22\n of the BOP stack \n12\n, through the wellhead \n14\n, and into the wellbore \n18\n.', 'As discussed in more detail below, the BOP stack \n12\n may include one or more BOPs \n24\n (e.g., ram BOPs), and component (e.g., rams) of the one or more BOPs \n24\n may be manufactured using systems and methods for HIP fabrication disclosed herein.', 'To facilitate discussion, the BOP stack \n12\n and its components may be described with reference to a vertical axis or direction \n30\n, an axial axis or direction \n32\n, and/or a lateral axis or direction \n34\n.', 'FIG.', '2\n is a cross-sectional top view of a portion of an embodiment of the BOP \n24\n that may be used in the drilling system \n10\n of \nFIG.', '1\n, in accordance with an embodiment of the present disclosure.', 'As shown, the BOP \n24\n includes opposed rams \n50\n, including upper ram \n50\nA and lower ram \n50\nB, also generally referred to herein as pressure-controlling components \n26\n or multi-metallic pressure-controlling components \n26\n of the BOP \n24\n.', 'In the illustrated embodiment, the opposed rams \n50\n are in an open configuration \n54\n of the BOP \n24\n in which the opposed rams \n50\n are withdrawn from the central bore \n22\n, do not contact the conduit \n20\n, and/or do not contact one another.', 'As shown, the BOP \n24\n includes a bonnet flange \n56\n surrounding the central bore \n22\n.', 'The bonnet flange \n56\n is generally rectangular in the illustrated embodiment, although the bonnet flange \n56\n may have any cross-sectional shape, including any polygonal shape and/or annular shape.', 'Bonnet assemblies \n60\n are mounted on opposite sides of the bonnet flange \n56\n (e.g., via threaded fasteners).', 'Each bonnet assembly \n60\n includes an actuator \n62\n, which may include a piston \n64\n and a connecting rod \n66\n.', 'The actuators \n62\n may drive the opposed rams \n50\n toward one another along the axial axis \n32\n to reach a closed position in which the opposed rams \n50\n are positioned within the central bore \n22\n, contact and/or shear the conduit \n20\n to seal the central bore \n22\n, and/or contact one another to seal the central bore \n22\n.', 'Each of the opposed rams \n50\n may include a body section \n68\n (e.g., ram body), a leading surface \n70\n (e.g., side, portion, wall) and a rearward surface \n72\n (e.g., side, portion, wall, rearmost surface).', 'The leading surfaces \n70\n may be positioned proximate to the central bore \n22\n and may face one another when the opposed rams \n50\n are installed within the housing \n56\n.', 'The rearward surfaces \n72\n may be positioned distal from the central bore \n22\n and proximate to a respective one of the actuators \n62\n when the opposed rams \n50\n are installed within the housing \n56\n.', 'The leading surfaces \n70\n may be configured to couple to and/or support sealing elements (e.g., elastomer or polymer seals) that are configured to seal the central bore \n22\n in the closed position, and the rearward surfaces \n72\n may include an attachment interface \n74\n (e.g., recess) that is configured to engage with the connecting rod \n66\n of the actuator \n62\n.', 'The body section \n68\n also includes lateral surfaces \n76\n (e.g., walls) that are on opposite lateral sides of the body section \n68\n and that extend along the axial axis \n32\n between the leading surface \n70\n and the rearward surface \n72\n.', 'In \nFIG.', '2\n, the opposed rams \n50\n have a generally rectangular shape to facilitate discussion; however, it should be appreciated that the opposed rams \n50\n may have any of a variety of shapes or features (e.g., curved portions to seal against the conduit \n20\n, edges to shear the conduit \n20\n).', 'FIG.', '3\n is a front isometric view of an embodiment of the upper ram \n50\nA, and \nFIG.', '4\n is a front isometric view of an embodiment of the lower ram \n50\nB, which may be used together as pressure-controlling components \n26\n in the embodiment of BOP \n24\n of \nFIG.', '2\n.', 'As illustrated in \nFIGS. \n3\n and \n4\n, the pressure-controlling components \n26\n each include the body section \n68\n and a blade section \n69\n.', 'Each blade section \n69\n includes the leading surface \n70\n, while the body section \n68\n includes the rearward surface \n72\n of the rams \n50\n.', 'Because the rams \n50\n of \nFIGS.', '3\n and \n4\n are shear rams, each blade section \n69\n includes a respective edge portion \n77\n that is formed in the leading surface \n70\n and that extends along the lateral axis \n34\n of each of the rams \n50\n.', 'In a closed configuration, the respective edge portions \n77\n of the upper ram \n50\nA and the lower ram \n50\nB are configured to shear the conduit \n20\n and/or support the seal elements that seal against the central bore \n22\n of the BOP illustrated in \nFIG.', '2\n.', 'However, it should be appreciated that the rams \n50\n may have any of a variety of other configurations (e.g., the rams \n50\n may be pipe rams that lack the respective edge portions \n77\n).', 'The blade section \n69\n of each of the rams \n50\n of \nFIGS.', '3\n and \n4\n also includes a leading cutout \n78\n formed in the leading surfaces \n70\n (e.g., positioned above and below the respective edge portion \n77\n along the vertical axis \n30\n).', 'The leading surface \n70\n, the rearward surface \n72\n, the lateral surfaces \n76\n, a top surface \n82\n (e.g., top-most surface), and a bottom surface \n84\n (e.g., bottom-most surface) may be considered the respective outer surfaces of the rams \n50\n.', 'For the illustrated rams \n50\n, the outer surfaces include grooves or channels \n86\n.', 'In certain embodiments, at least a portion of these grooves may be sealing grooves designed to receive or interface with a polymeric material (e.g., an elastomeric seal), while a portion of these grooves may be sliding grooves designed to receive a slide along a metallic extension during operation of the BOP.', 'For the pressure-controlling components \n26\n illustrated in \nFIGS.', '3\n and \n4\n, at least the body section \n68\n and the blade section \n69\n have a different metal alloy composition (e.g., a different chemical composition).', 'For example, in certain embodiments, the body section \n68\n of the rams \n50\n may be made of a first metal alloy, while at least a portion of the blade section \n69\n (e.g., an outer surface) is made of a second metal alloy.', 'The various metal alloys of the pressure-controlling components \n26\n may be selected for desirable material properties, including but not limited to: toughness, percent elongation, percent reduction of area, tensile strength, yield strength, impact strength, ductility, hardness, and corrosion resistance.', 'A non-limiting list of example metal alloys includes, but is not limited to: chromium-molybdenum (Cr—Mo) steels (e.g., Unified Numbering System (UNS) G41300, UNS G41400, UNS K21590); chromium-nickel-molybdenum (Cr—Ni—Mo) steels (e.g., UNS G43400); maraging (also known as martensitic-aged) steels (e.g., UNS K91973, UNS K44220, UNS K93120); super martensitic stainless steels (e.g., Euronorm (EN) 1.4418, UNS S41425, UNS S41426, UNS S41427); precipitation-hardened nickel alloys (e.g., UNS N07718, UNS N09946); precipitation-hardened martensitic steels (e.g., UNS S35000, UNS S17400); solution-annealed nickel alloys (e.g., UNS N06625, UNS N08825); tool steels (e.g., UNS T41907, UNS T30402, UNS T20813); cobalt or nickel-bound tungsten-carbides, nickel-cobalt (Ni—Co) alloys (e.g. UNS R30035); and cobalt-chromium (Co—Cr) alloys (e.g. UNS R30006).', 'In certain embodiments, one or more of the metal alloys of the pressure-controlling components \n26\n may be compliant with the National Association of Corrosion Engineers (NACE) MR0175 standard (also referred to as ISO 15156), which is a materials standard intended to assess the suitability of materials for oil and gas applications in which where sulfide stress corrosion cracking may be a risk in hydrogen sulfide-rich (sour) environments.\n \nFIG.', '5\n is a cross-sectional view of an embodiment of the upper ram \n50\nA illustrated in \nFIG.', '3\n.', 'For the illustrated embodiment, the blade section \n69\n of illustrated upper ram \n50\nA is made of a first metal alloy \n94\n.', 'The body section \n68\n includes a first portion \n68\nA that is made of a second metal alloy \n96\n and a second portion \n68\nB that is made of a third metal alloy \n98\n, resulting in a substantially trimetallic upper ram \n50\nA.', 'In some embodiments, both portions of the body section \n68\n may only include a single metal alloy, resulting in a substantially bimetallic upper ram \n50\nA, in which the blade section \n69\n and the body section \n68\n each are made entirely of a different respective metal alloy.', 'The metal alloys of the pressure-controlling component \n26\n (e.g., metal alloys \n94\n, \n96\n, \n98\n) may be selected based on a number of criteria.', 'For example, for the embodiment illustrated in \nFIG.', '5\n, it may be desirable for the blade section \n69\n to have a greater strength (e.g., a tensile and/or yield strength that is at least 5 percent greater, at least 10 percent greater, at least 20 percent greater, 200 percent greater, 250 percent greater, 300 percent greater) than that of the body section \n68\n.', 'Additionally or alternatively, it may be desirable for the body section \n68\n to have a greater toughness (e.g., a percent elongation and/or percent reduction in area that is at least 5 percent greater, at least 10 percent greater, at least 20 percent greater, 200 percent greater, 250 percent greater, 300 percent greater) than that of the blade section \n69\n.', 'This can result in the formation of rams \n50\n having a stronger blade section \n69\n, while also having a tougher, more ductile, and more resilient body section \n68\n.', 'As such, for the embodiment illustrated in \nFIG.', '5\n, the first metal alloy \n94\n that forms the blade section \n69\n may be selected based on having a suitably higher strength relative to the second metal alloy \n96\n that forms at least a substantial portion of the body section \n68\n.', 'For embodiments that include the second boundary and the third metal alloy \n98\n, the third metal alloy may be selected based on having a higher corrosion resistance relative to the second metal alloy \n96\n.', 'For example, in an example embodiment, the blade section \n69\n may be formed using a high-alloy steel alloy \n94\n, which has relatively higher strength; the first portion \n68\nA of body section \n68\n may be formed using low-alloy steel \n96\n, which has a relatively higher toughness; and the second portion \n68\nB of the body section \n68\n may be formed using a high-chrome or high-nickel steel \n98\n, which has relatively higher corrosion resistance.', 'While corrosion resistance may be desirable when the second portion \n68\nB of the body section \n68\n will contact a elastomer or polymer seal, for embodiments in which the second portion \n68\nB will contact and slide against a metallic surface during operation, the second portion \n68\nB may instead be formed from a metal alloy having a relatively greater hardness (e.g., at least 5 percent greater hardness, at least 10 percent greater hardness), which can improve sliding against the metallic part (e.g., reducing or preventing galling, reducing wear).', 'Additionally, the selected metal alloys should be compatible with one another for the HIP process.', 'In other words, in certain embodiments, certain material properties of the selected metal alloys (e.g., melting point, sintering point) should be similar (e.g., within a predetermined threshold), such that simultaneous, preferential microstructural develops in each material during a single HIP process, as discussed below.', 'Additionally, the embodiment of the upper ram \n50\nA illustrated in \nFIG.', '5\n includes planar (e.g., straight, flat) boundaries or interfaces \n100\n, at which the two different metal alloys meet and join via a narrow (e.g., less than 5 millimeter, less than 3 millimeter, about 1 millimeter) diffusion bond, which may also be referred to as the diffusion bond zone.', 'For the embodiment of \nFIG.', '5\n, these boundaries \n100\n include a first boundary \n100\nA disposed between the blade section \n69\n and the first portion \n68\nA of the body section \n68\n, as well as a second boundary \n100\nB disposed between the first portion \n68\nA and the second portion \n68\nB of the body section \n68\n.', 'For the illustrated embodiment, the boundaries \n100\n are aligned with planes oriented in the vertical and lateral directions (e.g., along a plane defined by axes \n30\n and \n34\n).', 'In certain embodiments, as discussed below, a thin boundary layer may be present along the interface \n100\n and be made of a metal alloy that is the same as or different from the metal alloys present on either side of the boundaries \n100\n.', 'For clarity, since the boundary layer contributes little to the overall composition of the upper ram \n50\nA, the upper ram \n50\nA illustrated in \nFIG.', '5\n may be described herein as being “substantially trimetallic,” meaning that it predominantly includes only metal alloys \n94\n, \n96\n, and \n98\n, even when boundary layers are used having different compositions relative to the metal alloys \n94\n, \n96\n, and \n98\n.', 'It may be appreciated that, for certain embodiments of pressure-controlling components \n26\n, it may be desirable for the diffusion bonds at the boundaries \n100\n to demonstrate certain features or material properties.', 'For example, in certain embodiments, the strength (e.g., tensile strength, yield strength) at each interface \n100\n between different metal alloys is greater than the strength of the material that is used to form at least a substantial portion of the body \n68\n.', 'For the embodiment of \nFIG.', '5\n, this would mean that the diffusion bond at the boundary \n100\n between the blade section \n69\n and the body section \n68\n would have a greater strength than that of the metal alloy \n96\n that forms the bulk of the body section \n68\n.', 'It may also be desirable, in certain embodiments, for the sintering of the metal alloys at and/or near the boundary \n100\n, and therefore the resulting grain structure, to be substantially homogenous.', 'In certain embodiments, it may be desirable that the integrity of the body between the different metal alloys to be stable and maintained through any heating and quenching processes used in the fabrication of the pressure-controlling components \n26\n.', 'In some embodiments, the boundaries \n100\n that define the diffusion bonds between the different metal alloys of the pressure-controlling components \n26\n may not be planar boundaries.', 'For example, \nFIGS.', '6\n and \n7\n are cross-sectional views of embodiments of substantially bimetallic lower rams \n50\nB having a curved boundary \n100\n (e.g., a curved diffusion bond) disposed between a first metal alloy \n94\n and a second metal alloy \n96\n that form the lower ram \n50\nB.', 'In \nFIG.', '6\n, the curved boundary \n100\n results in the blade section \n69\n having both the first and the second metal alloys, while the curved boundary in \nFIG. \n7\n results in the body section \n68\n having both the first and the second metal alloys.', 'In certain embodiments, it may be desirable to use the curved boundary \n100\n, as opposed to the planar boundaries discussed above, to reduce the amount of the first alloy \n94\n or the second alloy \n96\n used to make the pressure-controlling component \n26\n.', 'In some embodiments, it may be desirable to include the curved boundary \n100\n increase the surface area of the interface \n100\n (e.g., the surface area of the diffusion bond) between the first and second metal alloys \n94\n, \n96\n to enhance the material properties (e.g., strength, toughness) of the pressure-controlling component \n26\n at the interface \n100\n.', 'Additionally, while regular curved boundaries are illustrated, in some embodiments, the boundaries \n100\n may have substantial irregularity (e.g., ripples, undulations) without departing from the techniques disclosed herein.', 'In some embodiments, the boundaries that define the diffusion bonds between different metal alloys may be complex and correspond to (e.g., follow, match) one or more contours in the outer surface of the pressure-controlling components \n26\n.', 'For example, \nFIG.', '8\n is a cross-sectional view of an embodiment of a substantially trimetallic lower ram \n50\nB having boundaries \n100\n that follow along features defined in the outer surface of the part.', 'In particular, a layer of the first metal alloy \n94\n defines the outer surface of the blade section \n69\n of the part, while the second metal alloy \n96\n fills the interior of the blade section \n69\n and defines the outer surface of the body section \n68\n of the ram \n50\nB. Additionally, for the illustrated embodiment, the third metal alloy \n98\n (e.g., a corrosion resistant alloy) defines the outer surface of a seal region \n102\n in the body section \n68\n of the ram \n50\nB.', 'It should be appreciated that any of the boundaries \n100\n (e.g., planar, curved, complex) may be used in the upper ram \n50\nA, the low ram \n50\nB, or both in any suitable combination (e.g., all planar, all curved, at least one planar and at least one curved).', 'For certain embodiments of the lower ram \n50\nB illustrated in \nFIG. \n8\n, at least a portion of the first metal alloy \n94\n or the third metal alloy \n98\n may be disposed on the second metal alloy \n96\n to form the outer surfaces of the pressure-controlling components \n26\n using a welding-based deposition process (e.g., an overlay, inlay, or cladding process) after the formation of the remainder of the part using the HIP manufacturing process set forth below.', 'However, in some embodiments, all of the metal alloys (e.g., metal alloys \n94\n, \n96\n, and \n98\n) of the pressure-controlling component \n26\n are joined together during the HIP manufacturing process discussed below.', 'For example, the layer of the first metal alloy \n94\n may have a defined first thickness \n104\n in the blade section \n69\n of the part, while the third metal alloy \n98\n may have a second thickness \n106\n in the seal region \n102\n of the ram \n50', 'B. Using the disclosed HIP manufacturing process, the first and second thicknesses \n104\n and \n106\n may be independently controlled to any suitable thickness, such as 0.125 inch (in) (0.3157 centimeter (cm), about 3 millimeters (mm)) or greater, 0.25 in (0.635 cm, about 6 mm) or greater, 0.375 in (0.9525 cm, about 10 mm) or greater, between 0.125 in (0.3157 cm, about 3 mm) and 1 in (2.54 cm, about 25 mm), between 0.25 in (0.635 cm, about 6 mm) and 1 in (2.54 cm, about 25 mm), 1 in (2.54 cm, about 25 mm) or greater.', 'As such, it may be appreciated that, for embodiments in which the metal alloys of the pressure-controlling components \n26\n are joined during HIP process in the disclosed HIP manufacturing process, there is an advantageous reduction in manufacturing time and cost by avoiding the welding-based deposition processes, as well as any subsequent post-welding activity (e.g., clean-up, analysis, inspection).', 'By using the disclosed HIP manufacturing process, the thicknesses \n104\n and \n106\n of the metal alloy layers \n94\n and \n98\n can also reach substantially greater thicknesses than can be suitably deposited using welding-based deposition processes.', 'Additionally, since the HIP manufacturing process does not require depositing the metal alloys \n94\n and \n98\n via a welding-based process, metal alloys \n94\n, \n96\n, and \n98\n may be metal alloys that are less conducive or completely incompatible with welding-based processes.', 'Furthermore, by avoiding the welding-based processes, the potential to introduce issues in the part as a side-effect of the welding-based deposition processes (e.g., unintended thermally-induced changes in the grain structure at or near the weld deposit, unintended introduction of stress or strain in the part, unintended imperfections in the fusion zone) can also be advantageously avoided.\n \nFIG.', '9\n is a block diagram of an embodiment of a HIP manufacturing system \n110\n that may be used to construct the multi-metallic pressure-controlling component \n26\n (e.g., the upper ram \n50\nA, the lower ram \n50\nB, other components of the BOP \n24\n).', 'For the illustrated embodiment, the HIP manufacturing system \n110\n includes a controller \n112\n, a user interface \n114\n, a canister \n116\n, a heat source \n118\n, and a pressure source \n120\n, which, as discussed below, may be used to carry out the steps of the manufacturing process \n130\n of \nFIG.', '10\n to form the pressure-controlling component \n26\n.', 'In certain embodiments, the controller \n112\n is an electronic controller having electrical circuitry configured to process data from various components of the system \n110\n, for example.', 'In the illustrated embodiment, the controller \n112\n includes a processor \n122\n and a memory device \n124\n.', 'The controller \n112\n may also include one or more storage devices and/or other suitable components.', 'By way of example, the processor \n122\n may be used to execute software, such as software for controlling the user interface \n114\n, controlling the heat source \n118\n, the pressure source \n120\n, and so forth.', 'Moreover, the processor \n122\n may include multiple microprocessors, one or more “general-purpose” microprocessors, one or more special-purpose microprocessors, and/or one or more application specific integrated circuits (ASICS), or some combination thereof.', 'For example, the processor \n122\n may include one or more reduced instruction set (RISC) processors.', 'The memory device \n124\n may include a volatile memory, such as random access memory (RAM), and/or a nonvolatile memory, such as read-only memory (ROM).', 'The memory device \n124\n may store a variety of information and may be used for various purposes.', 'For example, the memory device \n124\n may store processor-executable instructions (e.g., firmware or software) for the processor \n122\n to execute, such as instructions for controlling the user interface \n114\n, the heat source \n118\n, the pressure source \n120\n, and so forth.', 'The storage device(s) (e.g., nonvolatile storage) may include read-only memory (ROM), flash memory, a hard drive, or any other suitable optical, magnetic, or solid-state storage medium, or a combination thereof.', 'The user interface \n114\n may include suitable input and output devices communicatively coupled to the controller \n112\n.', 'The user interface \n114\n is configured to receive user input defining parameters of the HIP manufacturing process (e.g., temperature/pressure programs).', 'The controller \n112\n may store received inputs in the memory device \n124\n until used by the processor \n122\n to perform portions of the HIP manufacturing process.', 'During the HIP manufacturing process, information about the state of the controller \n112\n, the heat source \n118\n, the pressure source \n120\n, and measurements from various sensors (e.g., temperature sensors, pressure sensors, displacement sensors) of the HIP manufacturing system \n110\n may be suitably presented on a display device of the user interface \n114\n.', 'The canister \n116\n is generally a sacrificial metal alloy (e.g., steel) container that serves as a mold during the HIP processing.', 'As such, the canister \n116\n includes an internal cavity that generally corresponds to the shape of the pressure-controlling component \n26\n being manufactured, although notably larger due to the reduction in volume experienced during HIP process.', 'As discussed below, the canister \n116\n is designed to receive multiple metal alloy powders, and potentially receive metal alloy foil boundary layers (e.g., nickel foil boundary layers) that are disposed between each layer of distinct metal alloy powder.', 'During HIP processing of the canister \n116\n, the pressure provided by the pressure source \n120\n and the heat provided by the heat source \n118\n condenses the materials (e.g., metal alloy powders, boundary layers) within the canister \n116\n into an integral, dense, multi-metallic pressure-controlling component \n26\n.', 'In certain embodiments, the heat source \n118\n and the pressure source \n120\n are integrated into a single element (e.g., an autoclave furnace).', 'With the foregoing in mind, \nFIG.', '10\n is a flow diagram of a process \n130\n for manufacturing the pressure-controlling component \n26\n (e.g., the upper ram \n50\nA, the lower ram \n50\nB, other components of the BOP \n24\n).', 'In particular, the process \n130\n includes steps for constructing the pressure-controlling component \n26\n using the HIP manufacturing system \n110\n illustrated in \nFIG.', '9\n.', 'In certain embodiments, at least a portion of the steps of the process \n130\n (e.g., loading of the canister) may be performed by a human operator, while at least a portion of the steps of the process \n130\n (e.g., HIP processing) may be performed by the controller \n112\n based on instructions stored in the memory device \n124\n and/or input received from the user interface \n114\n.', 'It may be appreciated that the process \n130\n is merely provided as an example, and in some embodiments, the process \n130\n may include additional steps, omitted steps, repeated steps, and so forth, in accordance with the present disclosure.', 'For the embodiment illustrated in \nFIG. \n10\n, the process \n130\n begins with depositing (block \n132\n) a first metal alloy powder into the canister \n116\n.', 'The first metal alloy may be any of a variety of suitable materials, including those mentioned above.', 'In certain embodiments, the first metal alloy added to the canister \n116\n may correspond to the metal alloy that forms at least a substantial portion of the body section \n68\n of the rams \n50\n (e.g., metal alloy \n96\n in \nFIGS.', '6\n and \n7\n).', 'In some embodiments, the first metal alloy powder added into the canister \n116\n may correspond to the metal alloy that will be disposed nearest the rearward surface \n72\n of the part (e.g., metal alloy \n98\n in \nFIG.', '5\n) or nearest the leading surface \n70\n of the part (e.g., metal alloy \n94\n in \nFIG.', '5\n), depending on the orientation of the part in the canister \n116\n.', 'In certain embodiments, adding the first metal alloy powder into the canister \n116\n may include packing or shaping the powder, for example, using vibration, tamping, or other suitable methods.', 'In certain embodiments, the metal alloy powder may be stored under inert atmosphere (e.g., nitrogen, helium, argon, an oxygen-depleted atmosphere) and/or the canister may be loaded under an inert atmosphere to block oxidation of the surface of the metal alloy powder.', 'Continuing through the embodiment illustrated in \nFIG.', '10\n, the process \n130\n continues with disposing (block \n134\n) a boundary layer on top of the first metal alloy layer in the canister \n116\n.', 'Subsequently, a second metal alloy powder is deposited (block \n136\n) into the canister \n116\n, above the first metal alloy layer in the canister \n116\n and above the boundary layer (when present).', 'In certain embodiments, a boundary layer may not be used and the actions of block \n134\n may be skipped.', 'As mentioned, the boundary layer is a thin piece of a metal alloy (e.g., a metallic foil, a flat sheet) that may be disposed between layers of different metal alloy powders to prevent mixing of the powders during placement within the canister prior to carrying out the HIP processing and/or in the part after the HIP processing, which may enable a sharp and well-defined boundary between the different metal alloy powders and/or facilitate bonding.', 'In certain embodiments, the boundary layer may have a composition that is the same as, or similar to, one of the metal alloy powders it separates.', 'In some embodiments, the boundary layer may have a composition that is different than the composition of the metal alloy powders separated by the boundary layer.', 'For example, the boundary layer may serve as a “butter layer” to facilitate the formation of a strong bond between the metal alloy powder layers.', 'That is, the boundary layer may be a metal alloy that is more conducive towards bonding with the first and second metal alloy powders than the first and second metal alloy powders are toward bonding directly with each other.', 'In some embodiments, the actions of blocks \n134\n and \n136\n may be repeated to add a third metal alloy, a fourth metal alloy, etc., to the canister \n116\n as desired.', 'The actions of blocks \n132\n, \n134\n, and \n136\n may be better understood by way of \nFIGS.', '11\nA-C\n.', 'These figures illustrate cross-sectional views of portions of the canister \n116\n loaded with a first layer \n138\n of a first metal alloy powder (as set forth in block \n132\n), a boundary layer \n140\n (as set forth in block \n134\n), and a second layer \n142\n of a second metal alloy powder (as set forth in block \n136\n).', 'As shown in \nFIG.', '11\nA\n, in certain embodiments, the boundary layer \n140\n may provide a substantially flat interface separating the two planar layers of metal alloy powder \n138\n and \n142\n, which results in a flat planar boundary \n100\n in the pressure-controlling component \n26\n, as illustrated and discussed above with respect to \nFIG. \n5\n.', 'As shown in \nFIG. \n11\nB\n, in certain embodiments, the boundary layer \n140\n may provide a curved interface separating the two layers of metal alloy powder \n138\n and \n142\n, which would result in a curved boundary \n100\n in the pressure-controlling component \n26\n, as illustrated and discussed above with respect to \nFIGS. \n5\n and \n6\n.', 'As shown in \nFIG.', '11\nC\n, in certain embodiments, the boundary layer \n140\n may have a shape that corresponds to one or more features of the canister \n116\n (and eventually to the features on an outer surface of the pressure-controlling component \n26\n) to provide a complex interface separating the two layers of metal alloy powder \n138\n and \n140\n, which would result in a complex boundary \n100\n in the pressure-controlling component \n26\n, as illustrated and discussed above with respect to \nFIG. \n8\n.', 'Returning to \nFIG.', '10\n, the process \n130\n continues with sealing the canister \n116\n (block \n144\n).', 'For example, in certain embodiments, the canister \n116\n is placed under vacuum (e.g., to remove ambient oxygen) and then welded closed.', 'Once sealed, heat and pressure are applied (block \n146\n) to the materials (e.g., metal alloy powders, metal alloy boundary layers) disposed within the canister to consolidate the materials to form the pressure-controlling component \n26\n in a HIP process.', 'For example, heat and pressure may be applied to the canister \n116\n via the heat source \n118\n and the pressure source \n120\n (e.g., an autoclave furnace), and the walls of the canister \n116\n impart the desired heat and pressure to the materials within the canister \n116\n.', 'The heat and pressure cause the materials within the canister \n116\n to condense and bond to one another.', 'More specifically, each of the powdered metal alloys may sinter together to form portions of the component \n26\n, while narrow (e.g., 1 millimeter or less) diffusion bonds form at the boundaries \n100\n between the different metal alloys.', 'In other words, there is only a limited amount of mixing of the metal alloys of the two metal alloy powders and/or mixing of the metal alloys with the boundary layer at the interfaces \n100\n, and there is no substantial mixing of the metal alloys and/or the boundary layer a short distance (e.g., 1 millimeter) outside of each of these boundaries.', 'In certain embodiments, the materials sealed within the canister \n116\n may be heated to approximately 1050 to 1100 degrees Celsius, and the hydrostatic pressure within the canister may be approximately 400 to 450 Megapascals.', 'However, any suitable temperature and/or pressure may be utilized to cause formation of the pressure-controlling component \n26\n.', 'For example, in some embodiments, the temperature may be between approximately 900 to 1200, 950 to 1150, or 1000 to 1100 degrees Celsius and/or the pressure may be approximately 300 to 600, 350 to 550, or 400 to 500 Megapascals.', 'In certain embodiments, the temperature and/or the pressure may be varied at different times during HIP processing as part of a temperature/pressure program, for example, with various ramps to increase or decrease the temperature and/or pressure over predefined time windows, and with various holds times during which the temperature and/or pressure are held substantially constant.', 'It may be appreciated that the particular temperatures and pressures used in the HIP process of block \n146\n may be selected based on the material properties (e.g., melting point, sintering point) of the powder metal alloys and boundary layers disposed within the canister \n116\n.', 'It may be noted that there is a substantial reduction in volume (e.g., between 15 percent and 25 percent, about 20 percent) of the materials disposed within the canister \n116\n during this HIP process.', 'Upon completion of the HIP process of block \n146\n, the pressure-controlling component \n26\n is subsequently removed from the canister \n116\n.', 'The resulting pressure-controlling component \n26\n may have a substantially uniform density (e.g., plus or minus 10 percent, plus or minus 5 percent) and/or the various regions of the component \n26\n with different metal alloys may be coupled to one another via narrow diffusion bonds.', 'In certain embodiments, the pressure-controlling component \n26\n may undergo additional processing steps (e.g., machining, welding overlays, thermal treatment) to yield the final part.', 'The disclosed techniques enable the HIP fabrication of multi-metallic (e.g., bimetallic, trimetallic) pressure-controlling components for pressure-controlling equipment used in oil and gas applications.', 'The disclosed HIP manufacturing process enables multiple, distinct metal alloys to be used to form particular portions of a pressure-controlling component, wherein the different metal alloys can be joined using a single HIP process.', 'Compared with traditional subtractive manufacturing techniques, the disclosed HIP manufacturing process reduces the manufacturing time and cost, enables greater freedom of design in the selection of metal alloys, and enables a broader range of different material properties (e.g., strength, toughness, corrosion resistance) in different portions of the pressure-controlling component.', 'Additionally, the disclosed HIP manufacturing technique can enable the formation of surface layers of metal alloy at thicknesses not achievable using weld-based processes (e.g., inlaying, overlaying, cladding) and using metal alloys that are not conducive to welding-based processes.', 'While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein.', 'However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed.', 'Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims.']

['1.', 'A method of manufacturing a multi-metallic pressure-controlling component, comprising:\ndisposing a first metal alloy powder in a canister;\ndisposing a metal alloy boundary layer on top of the first metal alloy powder in the canister;\ndisposing a second metal alloy powder on top of the metal boundary layer in the canister;\nsealing the canister; and\nperforming a hot isostatic pressure (HIP) process by applying heat and pressure to the canister to condense the first metal alloy powder, the metal boundary layer, and the second metal alloy powder to form the multi-metallic pressure-controlling component,\nwherein the metal boundary layer is positioned to enable the first metal alloy powder to form opposed exterior surfaces of a first section of the multi-metallic pressure-controlling component, to enable the second metal alloy powder to form an interior in the first section between the opposed exterior surfaces of the multi-metallic pressure-controlling component, and to enable the second metal alloy powder to define an outer surface of a second section of the multi-metallic pressure-controlling component.', '2.', 'The method of claim 1, comprising, before sealing the canister:\ndisposing a second metal boundary layer on top of the second metal alloy powder in the canister; and\ndisposing a third metal alloy powder on top of the second metal boundary layer in the canister, and wherein performing the HIP process condenses the first metal alloy powder, the metal boundary layer, the second metal alloy powder, the second metal boundary layer, and the third metal alloy powder to form the multi-metallic pressure-controlling component.', '3.', 'The method of claim 1, wherein the metal boundary layer between the first metal alloy powder and the second metal alloy powder has contours that correspond to features of the canister and to features on an outer surface of the multi-metallic pressure-controlling component.', '4.', 'The method of claim 1, wherein the metal boundary layer is positioned to provide a curved interface between the first metal alloy powder and the second metal alloy powder.', '5.', 'The method of claim 1, wherein the first metal alloy powder and the second metal alloy powder are independently selected from the group consisting of: chromium-molybdenum (Cr—Mo) steels, chromium-nickel-molybdenum (Cr—Ni—Mo) steels, maraging steels, super martensitic stainless steels, precipitation-hardened nickel alloys, precipitation-hardened martensitic steels, solution-annealed nickel alloys, tool steels, cobalt-bound tungsten-carbides, nickel-bound tungsten-carbides, nickel-cobalt (Ni—Co) alloys, and cobalt-chromium (Co—Cr) alloys.', '6.', 'The method of claim 1, wherein the first section of the multi-metallic pressure-controlling component comprises a blade section of a shear ram, and wherein the second section of the mult-metallic pressure-controlling component comprises a body section of the shear ram.\n\n\n\n\n\n\n7.', 'A method of manufacturing a multi-metallic pressure-controlling component, comprising:\ndisposing a first metal alloy powder in a canister;\ndisposing a metal alloy foil on top of the first metal alloy powder in the canister;\ndisposing a second metal alloy powder on top of the metal alloy foil in the canister;\nsealing the canister; and\nperforming a hot isostatic pressure (HIP) process by applying heat and pressure to the canister to condense the first metal alloy powder and the second metal alloy powder to form the multi-metallic pressure-controlling component;\nwherein the first metal alloy and the second metal alloy are independently selected from the group consisting of: chromium-molybdenum (Cr—Mo) steels, chromium-nickel-molybdenum (Cr—Ni—Mo) steels, maraging steels, super martensitic stainless steels, precipitation-hardened nickel alloys, precipitation-hardened martensitic steels, solution-annealed nickel alloys, tool steels, cobalt-bound tungsten-carbides, nickel-bound tungsten-carbides, nickel-cobalt (Ni—Co) alloys, and cobalt-chromium (Co—Cr) alloys,\nwherein the metal alloy foil is positioned to enable the first metal alloy powder to form opposed exterior surfaces of a first section of the multi-metallic pressure-controlling component, to enable the second metal alloy powder to fill an interior in the first section between the opposed exterior surfaces of the multi-metallic pressure-controlling component, and to enable the second metal alloy powder to define an outer surface of a second section of the multi-metallic pressure-controlling component.', '8.', 'The method of claim 7, comprising, before sealing the canister:\ndisposing a second metal alloy foil on top of the second metal alloy powder in the canister; and\ndisposing a third metal alloy powder on top of the second metal alloy foil in the canister, and wherein performing the HIP process condenses the first metal alloy powder, the metal alloy foil, the second metal alloy powder, the second metal alloy foil, and the third metal alloy powder to form the multi-metallic pressure-controlling component.', '9.', 'The method of claim 7, wherein the metal alloy foil between the first metal alloy powder and the second metal alloy powder has contours that correspond to features of the canister and to features on an outer surface of the multi-metallic pressure-controlling component.', '10.', 'The method of claim 7, wherein the metal alloy foil is positioned to provide a curved interface between the first metal alloy powder and the second metal alloy powder.', '11.', 'The method of claim 7, wherein the multi-metallic pressure-controlling component comprises a shear ram, wherein the first section of the multi-metallic pressure-controlling component comprises a blade section of the shear ram, and wherein the second section of the multi-metallic pressure-controlling component comprises a body section of the shear ram.\n\n\n\n\n\n\n12.', 'The method of claim 1, wherein the method of manufacturing the multi-metallic pressure-controlling component avoids any welding-based processes.', '13.', 'The method of claim 7, wherein the method of manufacturing the multi-metallic pressure-controlling component avoids any welding-based processes.']

['FIG.', '1 is a block diagram of a drilling system for mineral extraction, in accordance with an embodiment of the present disclosure;; FIG.', '2 is a cross-sectional top view of a portion of a blowout preventer (BOP) that may be used in the drilling system of FIG.', '1, in accordance with an embodiment of the present disclosure;; FIG.', '3 is a front isometric view of a component, namely an upper ram, that may be used in the BOP of FIG.', '2, in accordance with an embodiment of the present disclosure;; FIG. 4 is a front isometric view of another component, namely a lower ram, that may be used in conjunction with the upper ram of FIG.', '3 and the BOP of FIG.', '2, in accordance with an embodiment of the present disclosure;; FIGS.', '5, 6, 7, and 8 are cross-sectional views of the components of FIGS.', '3 and 4, in accordance with various embodiments of the present disclosure;; FIG.', '9 is a block diagram of a hot isostatic pressure (HIP) manufacturing system that is configured to carry out a HIP manufacturing process to fabricate the components of FIGS.', '3 and 4, in accordance with an embodiment of the present disclosure;; FIG.', '10 is a flow diagram of the HIP manufacturing process, in accordance with an embodiment of the present disclosure; and; FIGS.', '11A, 11B, and 11C are cross-sectional views of portions of a loaded canister prior to a HIP process of the HIP manufacturing process, in accordance with an embodiment of the present disclosure.', '; FIG.', '2 is a cross-sectional top view of a portion of an embodiment of the BOP 24 that may be used in the drilling system 10 of FIG.', '1, in accordance with an embodiment of the present disclosure.', 'As shown, the BOP 24 includes opposed rams 50, including upper ram 50A and lower ram 50B, also generally referred to herein as pressure-controlling components 26 or multi-metallic pressure-controlling components 26 of the BOP 24.', 'In the illustrated embodiment, the opposed rams 50 are in an open configuration 54 of the BOP 24 in which the opposed rams 50 are withdrawn from the central bore 22, do not contact the conduit 20, and/or do not contact one another.; FIG.', '3 is a front isometric view of an embodiment of the upper ram 50A, and FIG.', '4 is a front isometric view of an embodiment of the lower ram 50B, which may be used together as pressure-controlling components 26 in the embodiment of BOP 24 of FIG.', '2.', 'As illustrated in FIGS.', '3 and 4, the pressure-controlling components 26 each include the body section 68 and a blade section 69.', 'Each blade section 69 includes the leading surface 70, while the body section 68 includes the rearward surface 72 of the rams 50.', 'Because the rams 50 of FIGS.', '3 and 4 are shear rams, each blade section 69 includes a respective edge portion 77 that is formed in the leading surface 70 and that extends along the lateral axis 34 of each of the rams 50.', 'In a closed configuration, the respective edge portions 77 of the upper ram 50A and the lower ram 50B are configured to shear the conduit 20 and/or support the seal elements that seal against the central bore 22 of the BOP illustrated in FIG.', '2.', 'However, it should be appreciated that the rams 50 may have any of a variety of other configurations (e.g., the rams 50 may be pipe rams that lack the respective edge portions 77).', 'The blade section 69 of each of the rams 50 of FIGS. 3 and 4 also includes a leading cutout 78 formed in the leading surfaces 70 (e.g., positioned above and below the respective edge portion 77 along the vertical axis 30).', 'The leading surface 70, the rearward surface 72, the lateral surfaces 76, a top surface 82 (e.g., top-most surface), and a bottom surface 84 (e.g., bottom-most surface) may be considered the respective outer surfaces of the rams 50.', 'For the illustrated rams 50, the outer surfaces include grooves or channels 86.', 'In certain embodiments, at least a portion of these grooves may be sealing grooves designed to receive or interface with a polymeric material (e.g., an elastomeric seal), while a portion of these grooves may be sliding grooves designed to receive a slide along a metallic extension during operation of the BOP.; FIG.', '5 is a cross-sectional view of an embodiment of the upper ram 50A illustrated in FIG.', '3.', 'For the illustrated embodiment, the blade section 69 of illustrated upper ram 50A is made of a first metal alloy 94.', 'The body section 68 includes a first portion 68A that is made of a second metal alloy 96 and a second portion 68B that is made of a third metal alloy 98, resulting in a substantially trimetallic upper ram 50A. In some embodiments, both portions of the body section 68 may only include a single metal alloy, resulting in a substantially bimetallic upper ram 50A, in which the blade section 69 and the body section 68 each are made entirely of a different respective metal alloy.; FIG.', '9 is a block diagram of an embodiment of a HIP manufacturing system 110 that may be used to construct the multi-metallic pressure-controlling component 26 (e.g., the upper ram 50A, the lower ram 50B, other components of the BOP 24).', 'For the illustrated embodiment, the HIP manufacturing system 110 includes a controller 112, a user interface 114, a canister 116, a heat source 118, and a pressure source 120, which, as discussed below, may be used to carry out the steps of the manufacturing process 130 of FIG.', '10 to form the pressure-controlling component 26.']

US11933129

Electrical drilling and production systems and methods

Jun 23, 2023

Vikas Rakhunde, Nathan Cooper, Justin Blair, Michael W. Berckenhoff, Michael Mancuso, Matthew Givens

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent application PCT/US2017/041367 dated Sep. 22, 2017.; International Preliminary Report on Patentability issued in International Patent application PCT/US2017/041367, dated Jan. 24, 2019.; Jernstrom, Sangesland, Hagglin; “An All-electric System for Subsea Well Control”, 1993, Offshore Technology Conference, OTC 7335, pp. 705-711 (Year: 1993).

3319923; May 1967; Haeber; 5070904; December 10, 1991; McMahon, Jr.; 5547029; August 20, 1996; Rubbo; 8789606; July 29, 2014; Lugo; 20040031940; February 19, 2004; Biester; 20070107907; May 17, 2007; Smedstad; 20080110633; May 15, 2008; Trewhella; 20090194290; August 6, 2009; Parks; 20140102712; April 17, 2014; Gutierrez; 20140102713; April 17, 2014; Gutierrez; 20150211504; July 30, 2015; Dieringer; 20150240585; August 27, 2015; Mancuso; 20160177700; June 23, 2016; Scott

3039226; February 2019; EP

['A drilling and production system is provided.', 'In one embodiment, such a system has a plurality of functions that are effectuated at least predominately without hydraulic fluid.', 'The system can be a drilling system having a rig and a subsea stack for performing various drilling functions, in which a majority of the drilling functions are effected electrically without hydraulic control fluid.', 'In another embodiment, the rig is coupled to a subsea wellhead assembly but is not connected so as to provide hydraulic control fluid from the rig to the subsea wellhead assembly to enable drilling functions of the subsea wellhead assembly.', 'Additional systems, devices, and methods are also disclosed.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE PARAGRAPH\n \nThis application is a continuation of U.S. patent application Ser.', 'No. 16/313,460, filed Dec. 26, 2018, which is a National Stage Entry of PCT/US2017/041367, filed Jul. 10, 2017, which claims the benefit and priority of U.S. Provisional Application No. 62/360,404, filed Jul. 10, 2016.', 'Each of the above applications is hereby expressly incorporated by reference in its entirety as if fully set forth below and for all applicable purposes.', 'BACKGROUND\n \nThis section is intended to introduce the reader to various aspects of art that may be related to various aspects of the presently described embodiments.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present embodiments.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'To meet consumer and industrial demand for natural resources, companies often invest significant amounts of time and money in finding and extracting oil, natural gas, and other subterranean resources from the earth.', 'Particularly, once a desired subterranean resource such as oil or natural gas is discovered, drilling and production systems are often employed to access and extract the resource.', 'These systems may be located onshore or offshore depending on the location of a desired resource.', 'Further, such systems generally include a wellhead assembly through which the resource is accessed or extracted.', 'These wellhead assemblies may include a wide variety of components, such as various casings, valves, fluid conduits, and the like, that control drilling or extraction operations, with such components arranged in a stack or subsea production tree configuration, for example.', 'Wellhead assemblies typically include control pods that, as the name suggests, control and manage the delivery of control fluid to various components.', 'For example, the control pods may direct control fluid to and from blowout preventers, actuators and valves via tubing coupled to a control-fluid source.', 'When a particular hydraulic function is to be performed (e.g., closing a ram of a blowout preventer), a control pod valve associated with that function opens to supply control fluid to the component responsible for carrying out the hydraulic function (e.g., a piston of the blowout preventer).', "To provide redundancy in subsea applications, American Petroleum Institute Specification 16D (API Spec 16D) requires a subsea wellhead assembly include two subsea control pods—designated as a “yellow” pod and a “blue” pod—for controlling the assembly's hydraulically operated components.", 'For over forty years, the industry has relied on control fluid as the primary mechanism for actuating various drilling components—like a BOP—for both onshore and offshore operations.', 'As a result, most wellhead assemblies have banks of accumulators storing pressurized control fluid, which often adds to the weight of the BOP system and, potentially, the supporting rig or vessel.', 'Control-fluid accumulators can also be difficult to recharge in an efficient manner.', 'And it is difficult to monitor the operational status of the control fluid in the accumulators, as well as the control fluid in the system as a whole.', 'SUMMARY\n \nCertain aspects of some embodiments disclosed herein are set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of certain forms the invention might take and that these aspects are not intended to limit the scope of the invention.', 'Indeed, the invention may encompass a variety of aspects that may not be set forth below.\n \nEmbodiments of the present disclosure generally relate to electrically operated drilling and production systems and components.', 'In one embodiment, most if not all of the previously hydraulically operated components within the drilling system are replaced with electrically driven and controlled ones.', 'For example, in one embodiment, the accumulator banks are replaced with devices that supply and/or store electrical current, such as batteries or a flywheel generator.', 'The supplied current then feeds into various electrically operated components, like electrical motors and actuators.', 'As another example, the hydraulic control pods may be replaced with electrical communications and distribution equipment.', 'Removing hydraulically operated components from a drilling or production system-whether it is land based or subsea-provides a number of advantages, including improved operational control, reduced rig and equipment weight, and improved data collection, to name but a few.', 'Various refinements of the features noted above may exist in relation to various aspects of the present embodiments.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'Again, the brief summary presented above is intended only to familiarize the reader with certain aspects and contexts of some embodiments without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThese and other features, aspects, and advantages of certain embodiments will become better understood when the following detailed description is read with reference to the accompanying drawings in which like characters represent like parts throughout the drawings, wherein:\n \nFIG.', '1\n schematically depicts a subsea drilling system for accessing or extracting a resource, such as oil or natural gas, via a well, in accordance with an embodiment of the present disclosure;\n \nFIGS.', '2\nA-\n2\nD\n illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure;\n \nFIGS.', '3\nA-\n3\nC\n illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure;\n \nFIGS.', '4\nA-\n4\nD\n illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure;\n \nFIGS.', '5\nA-\n5\nC\n illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure; and\n \nFIG.', '6\n illustrates schematically the topology and process for activating a function of a subsea drilling system, in accordance with one embodiment of the present disclosure.', 'DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS\n \nOne or more specific embodiments of the present disclosure will be described below.', 'In an effort to provide a concise description of these embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments, the articles “a,” “an,” “the,” and “said” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Moreover, any use of “top,” “bottom,” “above,” “below,” other directional terms, and variations of these terms is made for convenience, but does not require any particular orientation of the components.', 'Turning now the figures, \nFIG.', '1\n illustrates a system \n10\n in accordance with one embodiment.', 'Notably, the system \n10\n (e.g., a drilling system or a production system) facilitates access to or extraction of a resource, such as oil or natural gas, from a well \n12\n.', 'As depicted, the system \n10\n is a subsea drilling system designed for accessing hydrocarbons from a reservoir formation \n13\n beneath the sea floor.', 'But the concepts disclosed herein can be applied to both onshore and offshore drilling, as well as to post-drilling production operations employing production equipment like surface or subsea trees.', 'Subsea drilling and production operations are quite complex, requiring a myriad of equipment.', 'Fluid flow into and out of the well \n12\n is managed by stack equipment \n14\n connected to the sea floor.', "As shown, the stack equipment \n14\n (which may also be referred to as a subsea wellhead assembly) includes a wellhead \n16\n that's mounted to the sea floor and that provides an interface point to the well \n12\n.", 'The wellhead \n16\n also provides a support structure onto which other stack equipment, like a BOP stack \n18\n, can be mounted.', 'The primary function of the BOP (blowout preventer) stack \n18\n is to assist controlling the ingress and egress of wellbore fluid (e.g., drilling mud, formation fluids, hydrocarbons, inhibitors) with respect to the well.', 'There are numerous types of BOPs that can be assembled into the stack, but some of the most common are annular BOPs and ram BOPs.', 'Annular BOPs typically have a large rubber “doughnut” that is compressed to seal around a drillpipe that is extending into the well \n12\n through the BOP, while ram BOPs have horizontally opposed rams that are actuated toward one another to seal the well.', 'These rams may be shear rams designed to cut through drillpipe before sealing off the well; the rams may be pipe rams designed to seal against the outer surface of the drillpipe; or the rams may be blind rams designed to seal against one another when there is no drillpipe or other component extending through the BOP, for example.', "In a subsea drilling system, as is shown, the stack equipment \n14\n is connected to a rig \n20\n or vessel located at the sea's surface via a riser string \n22\n.", "In short, the riser string \n22\n creates an artificial “bore” that allows wellbore fluid to be conveyed between the rig \n20\n at the sea's surface and the stack equipment \n14\n located at the sea floor.", 'The riser string \n22\n typically comprises multiple segments of riser pipe that are coupled to one another until the desired length of riser string \n22\n is achieved.', "To facilitate the riser string's connection, the stack equipment \n14\n may include an LMRP (lower marine riser package).", 'As an example, the LMRP \n24\n may include a flex joint connection that accommodates the upper end of the riser which may be coupled to a floating vessel-moving with respect to the lower end of the riser mounted to the stack equipment fixed to the sea floor.', 'Moreover, in an emergency situation, the LMRP can be activated to release the riser string, allowing the rig to move away from the stack equipment and well.', 'Control and operation of the stack equipment \n14\n can be facilitated by surface equipment \n26\n located on the rig \n20\n.', 'For example, the surface equipment \n26\n may include a human-machine interface (HMI) that allows the operator to input various commands that are communicated to a controller \n28\n, which may be located on the subsea stack \n14\n, via a cabling system \n30\n.', 'The surface equipment \n26\n may also include a variety of devices and systems, such as pumps, power supplies, cable and hose reels, control units, a diverter, a gimbal, a spider, and the like.', 'Certain surface equipment, and their control relationship with the subsea stack equipment, are discussed in further detail below.', 'The exemplary system \n10\n may be an all-, substantially or predominately electric system, in which many of the hydraulically operated components traditionally found on drilling and production systems have been replaced or removed.', 'Advantageously, replacing the hydraulically operated components with electrically controlled ones provides a number of benefits, including improved control, weight reduction, and better data collection, to name a few.\n \nFIGS.', '2\nA-\n2\nD\n illustrate schematically the topology of certain power and communications focused equipment for an exemplary all- or predominately electric drilling system.', 'As shown, the surface equipment \n26\n is connected to the subsea stack equipment \n14\n via a data network \n32\n and a power network \n34\n.', 'In the illustrated embodiment, data and power are communicated over a combined data and power network \n32\n, \n34\n.', 'That is, data is communicated over the same conductors that communicate power, for instance.', 'However, it is also envisaged that the data and power are communicated over separate networks, or that portions of the power and data network are independent and other portions are not.', "The nerve center of the exemplary networks is the command architecture \n36\n, certain components of which may be located on the rig \n20\n in a driller's cabin or disbursed throughout the drilling system.", 'The command architecture \n36\n may include processing equipment, like a processor or programmable logic circuitry, that receives inputs from various locations and provides commands based on programming.', "Or, for manual operation, a human-machine interface (HMI) \n38\n facilitates the rig's operator providing commands to and receiving data regarding the drilling system.", "And the rig's operator need not be resident on the rig.", 'Command inputs and operating data may also be communicated via a wireless communications system \n40\n connected to the data network \n32\n, facilitating real-time monitoring and remote operation of the drilling system \n10\n.', 'Moreover, the command architecture may include one or more data ports \n41\n—similar to an OBD-II port on automobiles, for instance—to facilitate communications with and control via a portable device.', "Management of the exemplary drilling system's communication is conducted by a communication and distribution panel \n42\n, which may operate using well-known protocols like TCP/IP or Ethernet/IP, or a proprietary protocol, among others.", 'In the illustrated drilling system \n10\n, the data network \n32\n employs two general methodologies for communications between the surface equipment \n26\n and the subsea stack equipment \n14\n.', 'The first is a cabled connection, in which a cable \n44\n extends from the rig down to the subsea stack equipment \n14\n.', 'Any number of cable types may be employed, including fiber optic cables, cables designed to carry both data and power, MUX cables, or bundled cables, to name but a few.', 'As shown in \nFIGS.', '2\nA and \n2\nB\n, the drilling system \n10\n has a MUX cable \n44\n that is stored in a reel \n45\n on the rig \n20\n and that extends from the rig \n20\n to the subsea stack equipment \n14\n.', 'The MUX cable may comprise a bundle of various types of cable, in which power and data are sent over a single conductor or in which power and data are sent over different conductors.', 'For example, the power may be transmitted over a lower gauge copper wire, while data is transmitted over a fiber optic cable or higher gauge wire.', 'These cabled connections can include more than just simple cables.', 'For example, the cable connection may include magnetic elements—like rare earth magnets—that enable the cable to mechanically connect to the riser system \n22\n.', 'Moreover, the cable connection may be incorporated into the riser itself.', 'That is, some or all of the riser segments in the riser string \n22\n may include integrated cable segments that couple to one another through a wet mate connector, or connectors that inductively communicate data, or a combination of the two.', 'In another embodiment, the cables may be secured to the risers by clamps that close to secure the cable with respect to the riser string.', 'The second general communication methodology employs acoustics.', 'In the exemplary system \n10\n, the command architecture \n36\n includes an acoustic command unit \n46\n coupled to a transducer \n48\n.', 'Using the seawater as a medium, the transducer \n48\n transmits and receives acoustic signals sent to and from a transducer on the subsea equipment stack \n14\n, on a remote operated vehicle (ROV), or on an autonomous underwater vehicle (AUV).', 'But these two methodologies are just examples.', 'It is also envisaged that the rig \n20\n may communicate with the subsea stack, or other components or devices located subsea, via radio waves employing very-low frequency (VLF) and super-low frequency (SLF) signals, for instance.', 'Communications between the rig \n20\n and the subsea stack \n14\n in the illustrated drilling system are transmitted by or to one or more controllers \n28\n located on the subsea stack \n14\n.', 'For example, the illustrated drilling system includes an LMRP electronics control module \n50\n, which manages the communications and power distributions to various components on the LMRP \n24\n.', 'Put differently, this control module \n50\n controls the activation and deactivation of various “functions” on the LMRP, functions that are traditional hydraulically controlled using control fluid.', 'The illustrated LMRP control module \n50\n manages five functions—namely the operation of five actuators on the LMRP—but the module can be sized to control more or fewer functions, if desired.', 'As discussed in further detail below, a command signal may be sent to the LMRP control module \n50\n, causing the module \n50\n to provide another command signal to switching circuitry, like a relay \n51\n or a solid state switching circuit, that directs operating power to the given actuator, effecting the desired function.', 'That is, appropriately conditioned power—whether AC or DC—is routed to an electric motor to effect a function, like opening or closing a choke or activating or releasing a connector, through actuation.', 'Advantageously, data collected from sensors on the drilling system, including sensors on the LMRP and the BOPs, can communicate operational data back to the rig \n20\n via the given controller \n28\n, like the module \n50\n.', 'The illustrated BOP stack \n18\n is operated in a similar manner, employing a BOP control module \n54\n that controls the activation and deactivation of various “functions” on the BOP stack, again functions that are traditional hydraulically controlled using control fluid.', 'As shown, the BOP control module \n54\n controls ten functions on that BOP stack, such as the opening and closing of various valves, rams, annulars, and connectors (which are examples of pressure control equipment) on the BOP stack \n18\n.', 'Indeed, the subsea stack \n14\n includes an LMRP connector and a BOP wellhead connector that are energized and released via an electrically driven actuator having linear or push motor to drive collet connectors, for example.', 'While five functions are depicted as controlled by the LMRP control module \n50\n and ten functions are depicted as controlled by the BOP control module \n54\n in the present illustration as examples, it will be appreciated that these control modules \n50\n and \n54\n can control other functions (e.g., pressure control functions) in addition to, or instead of, those presently depicted.', 'Although depicted together in \nFIG.', '2\nD\n with a single actuator for simplicity, the choke and kill functions may be performed with separate actuators and considered separate functions.', 'In some embodiments, predominately all of the functions (i.e., a majority of the functions) of the stack equipment \n14\n are effected electrically without hydraulic control fluid.', 'And in some of these embodiments, substantially all of the functions (i.e., at least eight-five percent of the functions) of the stack equipment \n14\n are effected electrically without hydraulic control fluid.', 'Still further, either or both of the BOP stack \n18\n and the LMRP \n24\n can be configured to perform each of its drilling functions without hydraulic control fluid.', 'The BOP control module \n54\n may be in communication with the LMRP control module \n50\n, or it may be in direct communication with the rig \n20\n via direct cabling.', 'Moreover, each of the control modules \n50\n, \n54\n may include its own acoustic system \n46\n with a transducer \n48\n, for acoustic communications with the rig \n20\n.', 'Moreover, these control systems \n50\n, \n54\n may be in communication with and provide power to equipment related to the riser system \n22\n.', 'For example, these systems \n50\n, \n54\n may manage and control a riser recoil system that mitigates unwanted movement of the riser during disconnect operations.', "Advantageously, in an all- or predominantly electric drilling system, much of the hydraulic cabling, the accumulator banks feeding the cables, and the associated supporting equipment (e.g., reels, hydraulic power units, rig plumbing, fluid mixes, umbilicals) can be removed from the rig \n20\n, reducing the rig's complexity and weight.", 'Moreover, in a hydraulic system, adding additional functions to the control pod requires significant redesign and a significant increase in the hydraulic control fluid needed for operation, whereas adding further functions to electrical systems is significantly easier.', "If the command architecture \n36\n and data network \n32\n are the nervous system, then the power network \n34\n is the drilling system's circulatory track.", 'To provide electrical power, the rig \n20\n includes a power supply \n56\n, which may be any one of a number of devices that generate electrical current.', 'For example, the power supply may be a solar array, a hydrogen fuel cell, a generator that converts diesel, gasoline or natural gas into electric current, a turbine electric generator, or a wave energy generator that converts the kinetic energy of the sea into electrical current; and these power generation systems may output three-phase AC, single-phase AC, or DC power, for example, depending on the needs of the drilling system.', 'Indeed, the drilling system may include conditioning circuitry to condition the generated current (e.g., rectify, invert, pulse-width modulate, reduce voltage) so as to be appropriate for the given components.', 'On the rig \n20\n, the power supply \n56\n is connected to a back-up or uninterruptable power supply \n57\n, which may have a number of configurations.', "For example, the back-up may be a battery rack or capacitor bank that's trickle charged by the power supply, electricity generated through movement of a piezo-electric element, solar panels during quiescent operations, or via the power generation devices discussed above.", 'Alternatively, the back-up may be a fly-wheel based system that converts the mechanical rotation of a fly wheel-motion effected by the primary supply, for example, during normal operation-into electrical energy when the primary supply is lost.', 'Upon a loss of primary power, the back-up provides operating current to the drilling system, albeit for a limited duration as compared to the primary supply.', 'But the backup power may also be employed even if the primary power is available, if desired.', 'These power generation and back-up systems need not be only located on the rig \n20\n.', 'The subsea stack equipment \n14\n may receive power from their own power supplies.', "For example, the LMRP control module \n50\n may be coupled to a subsea power generator \n60\n, and the BOP control module \n54\n may be coupled to its own power generator \n62\n or to the LMRP's.", 'These power generators \n60\n, \n62\n may be similar to those on the rig, including a both a primary supply and a back-up supply or just one of those.', 'Moving to electrical operation of the subsea stack \n14\n yields a number of advantages.', 'It eliminates the need for large banks of hydraulic accumulators—and their associated equipment, like hydraulic power units, hoses and hose reels, and piping, to name a few—to be deployed with the subsea stack equipment.', 'This reduces the overall weight, size, and cost of the subsea stack equipment.', 'Moreover, traditional hydraulic systems do not provide the desired resolution regarding operational conditions.', "For example, depletion of hydraulic control fluid from the accumulators can be measured, but it may not be sufficiently granular so as to provide the operator with good information regarding the system's true condition.", 'In contrast, electric systems can provide more accurate representations of power levels and battery levels, for example.', 'Another advantage of electrical systems is that they provide more accurate feedback regarding the position of various components.', 'That is, in conventional hydraulic systems, it is difficult to, with a high degree of resolution, determine the amount of movement of a piston driving a BOP ram, that movement being caused by the hydraulic control fluid.', 'However, in an electrically driven system in which movement of the BOP rams is effected by an electric motor, for instance, the location information is more accurate, as fewer environmental factors affect the electrical system as compared to the hydraulic system, reducing the number of variables that must be factored to make an assessment.', 'Ultimately, having better data and operational knowledge of the system can create a feedback loop, where analysis of the data yields more accurate estimates of potential failure points and need for maintenance.', 'The surface and subsea components may include data or event loggers that, using the data network, collect and record data regarding the system.', 'In the event of a malfunction or other incident, these loggers can be used to investigate and assess conditions leading up to the undesired event.', 'Further still, electrically actuated components can provide actuation much faster than hydraulic control fluid, particularly if there is a large distance between the hydraulic fluid source and the operated function.', 'But there are embodiments in which some hydraulic fluid may still be employed to operate the subsea equipment stack \n14\n, even though it is predominately electric.', 'For example, in one embodiment, the various functions may be effected by hydraulic control fluid that is pressurized locally by an electrically driven subsea pump, for example, powered by the above-described electrical power supplies.', 'In at least some embodiments, the rig \n20\n is not connected to the subsea wellhead assembly \n14\n so as to provide hydraulic control fluid from the rig to the subsea wellhead assembly to enable drilling functions of the subsea wellhead assembly.', 'That is, even if hydraulic control fluid is used by the subsea wellhead assembly \n14\n to perform a drilling function in some embodiments, that drilling function can be performed with a local, subsea source of hydraulic control fluid rather than with hydraulic control fluid provided from the rig \n20\n (e.g., via an umbilical) at the time the drilling function is performed.', 'To operate in harsh environments, like those found when operating subsea, the drilling system has redundancy.', 'The left sides of \nFIGS.', '2\nA-\n2\nD\n show a “yellow” data and power network, and the right sides have a “blue” system.', 'Each of the “yellow” and “blue” systems is capable of providing data, control, communications and power independent of the other.', 'Thus, if a component on or the entire “yellow” system fails, the operator can immediately maintain control using the “blue” system, or vice versa.', "The exemplary system \n10\n is not limited to just two redundancies; any number of additional redundant systems—such as a third or “green” system—can be added to improve the rig's reliability and reduce its nonproductive time.", 'The exemplary system \n10\n also has a number of remote-operating vehicle (ROV) ports and access points that facilitate continuous operation of the drilling system.', 'For example, each of the functions of the subsea stack \n14\n includes one or more ROV access points \n63\n through which an ROV can effect a function, whether mechanically or electrically.', 'That is, the ROV may be operated to manually open or close valves, or the ROV may provide command signals and power to close the valve, as examples.', 'The ROV may also couple to subsea power and control components.', 'For example, in the illustrated drilling system, the subsea power generator \n62\n has an ROV charging port \n66\n that allows ROV to provide electrical power to the subsea stack equipment \n14\n, whether directly or indirectly, by charging the battery back-up, for instance.', "Moreover, the system may include an ROV interface port \n68\n that allows the ROV to communicate with the data network \n32\n and/or a data storage device located in a subsea electronic module recording the system's data, independent of the command architecture.", 'Thus, if control at the rig \n20\n is lost, the ROV can fully operate and communicate with the subsea stack equipment \n14\n.', "And command controls from the ROV can even be communicated to the subsea stack equipment \n14\n acoustically, with the ROV having a transducer that communicates with the transducer on the subsea stack's acoustic system.", "It's also envisaged that the two ROV ports \n66\n, \n68\n can be integrated into a single port that allows power and data communications over a single connection with the ROV.\n \nFIGS.", '3\nA-\n3\nC\n illustrate a data and power communications topology for a drilling system \n10\n, in accordance with an embodiment of the invention.', 'In this embodiment, power and data from the rig \n20\n are transmitted to an LMRP power and communications distribution module \n70\n and a BOP power and communications distribution module \n72\n.', 'At these modules, high voltage operating power and lower voltage signal power are bifurcated.', 'The lower voltage signal power is communicated to an LMRP and a BOP control module \n74\n and \n76\n, respectively.', 'These control modules operate relays \n51\n to control actuators.', 'Although each of \nFIGS.', '3\nB and \n3\nC\n depict a single actuator for simplicity, the control modules \n74\n and \n76\n can operate numerous drilling functions via multiple actuators, as described above.', 'Upon receiving the appropriate signal, the control module, using lower voltage signal power, trips a relay into either the open or closed state, thus providing or restricting higher voltage operating power to the given function, such a driving an electric actuator to close a shear ram.', 'Moreover, the power and communications distribution modules \n70\n, \n72\n may route high voltage power to the various back-up power sources within the drilling system.', 'Advantageously, the power and communications distribution modules \n70\n, \n72\n may include variable-frequency drive (VFD) circuitry that can provide more precise control of the electric motors within the system, for example.', 'Turning to \nFIGS.', '4\nA-\n4\nD and \n5\nA-\n5\nC\n, these figures illustrate alternate embodiments of the drilling system.', 'In these embodiments, the operating power for the functions can be provided by battery systems \n62\n and \n78\n.', 'However, these battery systems are charged by the power supply on the rig \n20\n and/or those power supplies more local to the subsea stack equipment \n14\n.', 'Put differently, the functions on the subsea stack receive current from the batteries, with the batteries being charged by one or mechanisms for charging.', "And, in situations where repeated operations of the system's functions are not expected, the batteries can be trickle charged, further reducing the number of components on, the weight, and the size of the subsea stack and drilling rig.", 'As with \nFIGS.', '2\nA-\n2\nD and \n3\nA-\n3\nC\n, the actuators and functions represented in \nFIGS.', '4\nA-\n4\nD and \n5\nA-\n5\nC\n are provided as examples, and the control modules of these systems can effect various additional or other drilling functions via actuators in a variety of embodiments.', 'Concluding with \nFIG.', '6\n, it illustrates the operation of certain functions within the drilling system.', 'In this embodiment, an operator, using the HMI interface \n38\n, triggers two functions: the closing of a BOP pipe ram \n82\n and the opening of a gate valve \n84\n.', 'The commands are sent from the HMI interface, over the data network \n32\n, and to the communication and distribution panel \n42\n.', 'There, a 230V AC power current is overlaid onto the command signal and sent to a MUX cable \n44\n disposed on a reel \n45\n, which itself may be operated by an electric motor rather than hydraulic or pneumatic systems.', 'Both the power and the command signal are sent down to the subsea stack \n14\n, specifically to the subsea communications and power distribution modules \n50\n, \n54\n.', "There, the command and power signals are bifurcated, with the command signal—a 24V DC signal—being sent to the relays' gates and the 230V AC current being transmitted through the relay \n51\n.", 'Power exiting the relay \n51\n is then sent to a conditioning circuit \n90\n, so that the current is appropriate for the given function.', 'For example, the power may be rectified to output 3000V DC to drive a high torque motor \n92\n for closing a BOP ram.', 'Or the voltage may be transformed down to 120V AC to operate a relatively small gate valve via a motor \n94\n.', 'While the aspects of the present disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein.', 'But it should be understood that the invention is not intended to be limited to the particular forms disclosed.', 'Rather, the invention is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the invention as defined by the following appended claims.']

['1.', 'A drilling system, comprising:\na rig; and\na subsea wellhead assembly configured to perform a plurality of drilling functions, the subsea wellhead assembly comprising a wellhead, a blowout preventer stack, and a lower marine riser package (LMRP), wherein: the plurality of drilling functions of the subsea wellhead assembly are effected electrically and without supply of hydraulic fluid from the rig; the blowout preventer stack includes an energy storage device and at least one remote operating vehicle (ROV) charging port coupled to the energy storage device, the ROV charging port being configured to receive power from a ROV to charge the energy storage device for the blowout preventer stack; and at least one drilling function of the plurality of drilling functions is performed using charge from the energy storage device.', '2.', 'The drilling system of claim 1, wherein electrical power supplied from the energy storage device is bifurcated at the subsea wellhead assembly to yield bifurcated power, wherein the at least one drilling function is performed using the bifurcated power.', '3.', 'The drilling system of claim 1, wherein the rig is not connected to the subsea wellhead assembly so as to supply the hydraulic fluid to the subsea wellhead assembly.', '4.', 'The drilling system of claim 1, wherein the at least one drilling function comprises actuating a valve or a connector of the blowout preventer stack of the subsea wellhead assembly.', '5.', 'The drilling system of claim 1, further comprising an electrical power supply on the rig configured to provide power to the subsea wellhead assembly via an electrical cable.', '6.', 'The drilling system of claim 1, wherein the at least one drilling function comprises actuating a shear ram blowout preventer component to shear a drillpipe.', '7.', 'A drilling system, comprising:\na rig; and\na subsea wellhead assembly configured to perform multiple drilling functions and comprising a wellhead, a blowout preventer stack, and a lower marine riser package (LMRP), wherein: the rig is coupled to the subsea wellhead assembly but is not coupled so as to provide hydraulic control fluid from the rig to the subsea wellhead assembly to enable the multiple drilling functions; the blowout preventer stack includes an energy storage device and at least one remote operating vehicle (ROV) charging port coupled to the energy storage device, the ROV charging port being configured to receive power from a ROV for charging the energy storage device; electrical power supplied from the energy storage device is converted to a plurality of different voltages by circuitry of the subsea wellhead assembly; and at least one of the multiple drilling functions is performed using at least one of the plurality of different voltages.', '8.', 'The drilling system of claim 7, further comprising an electrical power supply on the rig connected to the subsea wellhead assembly via an electrical cable to provide power from the rig to the subsea wellhead assembly.\n\n\n\n\n\n\n9.', 'The drilling system of claim 8, wherein the electrical cable also carries data signals between the subsea wellhead assembly and the rig.\n\n\n\n\n\n\n10.', 'The drilling system of claim 7, wherein the blowout preventer stack is a lower blowout preventer stack configured to perform a first subset of the multiple drilling functions, and wherein the LMRP is configured to perform a second subset of the multiple drilling functions.', '11.', 'The drilling system of claim 10, wherein the lower blowout preventer stack is configured to perform each drilling function of the first subset of the multiple drilling functions without the hydraulic control fluid.', '12.', 'The drilling system of claim 10, wherein the LMRP is configured to perform each drilling function of the second subset of the multiple drilling functions without the hydraulic control fluid.', '13.', 'The drilling system of claim 7, wherein none of the drilling functions performed by the subsea wellhead assembly are effected with the hydraulic control fluid.', '14.', 'A method of operating a subsea wellhead assembly, the method comprising:\nreceiving, at a controller of the subsea wellhead assembly, one or more command signals from a rig, the subsea wellhead assembly comprising a wellhead, a blowout preventer stack, and a lower marine riser package (LMRP);\neffecting, via the controller, drilling functions of the subsea wellhead assembly, wherein the subsea wellhead assembly is an all-electric subsea wellhead assembly configured to operate without hydraulic control fluid, and wherein effecting the drilling functions of the subsea wellhead assembly includes electrically effecting, via an energy storage device at the blowout preventer stack, the drilling functions without use of the hydraulic control fluid from the rig; and\nreceiving, via at least one remote operating vehicle (ROV) charging port at the subsea wellhead assembly, power from a ROV for charging the energy storage device.\n\n\n\n\n\n\n15.', 'The method of claim 14, further comprising supplying electrical power from a power supply on the rig to the subsea wellhead assembly via an electrical cable.', '16.', 'The method of claim 14, further comprising bifurcating, at the subsea wellhead assembly, electrical power supplied from the energy storage device to yield bifurcated power, wherein at least one of the drilling functions is performed using the bifurcated power.', '17.', 'The method of claim 14, wherein the blowout preventer stack includes a lower blowout preventer stack having the controller.', '18.', 'The method of claim 14, wherein electrically effecting the drilling functions without use of the hydraulic control fluid includes issuing control signals from the controller to switching circuitry to direct power from the energy storage device to electric actuators of the subsea wellhead assembly to effect the drilling functions.', '19.', 'The method of claim 14, wherein the one or more command signals are received at the LMRP.', '20.', 'The method of claim 14, wherein receiving the one or more command signals includes wirelessly receiving the one or more command signals from the rig.']

['FIG.', '1 schematically depicts a subsea drilling system for accessing or extracting a resource, such as oil or natural gas, via a well, in accordance with an embodiment of the present disclosure;; FIGS.', '2A-2D illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure;; FIGS.', '3A-3C illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure;; FIGS.', '4A-4D illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure;; FIGS.', '5A-5C illustrate schematically the electrical power and communications topology of a subsea drilling system, in accordance with an embodiment of the present disclosure; and; FIG.', '6 illustrates schematically the topology and process for activating a function of a subsea drilling system, in accordance with one embodiment of the present disclosure.; FIGS.', '2A-2D illustrate schematically the topology of certain power and communications focused equipment for an exemplary all- or predominately electric drilling system.', 'As shown, the surface equipment 26 is connected to the subsea stack equipment 14 via a data network 32 and a power network 34.', 'In the illustrated embodiment, data and power are communicated over a combined data and power network 32, 34.', 'That is, data is communicated over the same conductors that communicate power, for instance.', 'However, it is also envisaged that the data and power are communicated over separate networks, or that portions of the power and data network are independent and other portions are not.;', 'FIGS.', '3A-3C illustrate a data and power communications topology for a drilling system 10, in accordance with an embodiment of the invention.', 'In this embodiment, power and data from the rig 20 are transmitted to an LMRP power and communications distribution module 70 and a BOP power and communications distribution module 72.', 'At these modules, high voltage operating power and lower voltage signal power are bifurcated.', 'The lower voltage signal power is communicated to an LMRP and a BOP control module 74 and 76, respectively.', 'These control modules operate relays 51 to control actuators.', 'Although each of FIGS.', '3B and 3C depict a single actuator for simplicity, the control modules 74 and 76 can operate numerous drilling functions via multiple actuators, as described above.', 'Upon receiving the appropriate signal, the control module, using lower voltage signal power, trips a relay into either the open or closed state, thus providing or restricting higher voltage operating power to the given function, such a driving an electric actuator to close a shear ram.', 'Moreover, the power and communications distribution modules 70, 72 may route high voltage power to the various back-up power sources within the drilling system.', 'Advantageously, the power and communications distribution modules 70, 72 may include variable-frequency drive (VFD) circuitry that can provide more precise control of the electric motors within the system, for example.']

US11898432

Real time surveying while drilling in a roll-stabilized housing

Jul 22, 2020

Andrew Whitmore, Abdiwahid Alasow, Edward Richards, Darren Lee Aklestad

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion in International Patent application PCT/US2020/042998, dated Oct. 15, 2020, 14 pages.; Brooks et al., “Practical Application of a Multiple-Survey Magnetic Correction Algorithm”, SPE 49060, New Orleans, Louisiana, Sep. 17-30, 1998, 8 pages.; Chia et al., “MWD Survey Accuracy Improvements Using Multistation Analysis”, IADC/SPE 87977, Kuala Lumpur, Malaysia, Sep. 13-15, 2004, 7 pages.

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Foreign Citations not found.

['A method for drilling a subterranean wellbore includes rotating a drill string in the wellbore to drill.', 'The drill string includes a roll-stabilized housing deployed in a drill collar and survey sensors deployed in the roll-stabilized housing.', 'Sensor measurements are acquired while the drill string is rotating.', 'High bandwidth accelerometer measurements may be obtained by combining triaxial accelerometer measurements and gyroscopic sensor measurements.', 'Survey parameters, including a wellbore azimuth, may be computed from the high bandwidth accelerometer measurements.', 'Triaxial magnetometer measurements may be processed to compute an eddy current induced wellbore azimuth error which may be removed from a previously computed wellbore azimuth to obtain a corrected wellbore azimuth.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE TO RELATED APPLICATIONS', 'This application is the U.S. National Phase of International Patent Application No. PCT/US2020/042998, filed Jul. 22, 2020, and entitled “Real Time Surveying while Drilling in a Roll-Stabilized Housing”, which claims the benefit of U.S. Provisional application No. 63/010,774 entitled “Real Time Surveying While Drilling In A Roll-Stabilized Housing”, filed Apr. 16, 2020 and of U.S. Provisional application No. 62/877,907 entitled “Real Time Surveying While Drilling In A Roll-Stabilized Housing”, filed Jul. 24, 2019, the disclosure of each of which is incorporated herein by reference.', 'FIELD\n \nDisclosed embodiments relate generally to surveying while drilling methods in rotary systems employing a roll-stabilized housing and more particularly to surveying methods for obtaining wellbore azimuth while drilling.', 'BACKGROUND\n \nIn conventional drilling and measurement while drilling (MWD) operations, wellbore inclination and wellbore azimuth are determined at a discrete number of longitudinal points along the axis of the wellbore.', 'These discrete measurements may be assembled into a survey of the well and used to calculate a three-dimensional well path (e.g., using the minimum curvature or other curvature assumptions).', "Wellbore inclination is commonly derived (computed) from tri-axial accelerometer measurements of the earth's gravitational field.", "Wellbore azimuth (also commonly referred to as magnetic azimuth) is commonly derived from a combination of tri-axial accelerometer and tri-axial magnetometer measurements of the earth's gravitational and magnetic fields.", 'Static surveying measurements are made after drilling has temporarily stopped (e.g., when a new length of drill pipe is added to the drill string) and the drill bit is lifted off bottom.', 'Such static measurements are commonly made at measured depth intervals ranging from about 30 to about 90 feet.', 'While these static surveying measurements may, in certain operations, be sufficient to obtain a well path of suitable accuracy, such static surveying measurements are time consuming as they require drilling to temporarily stop and the drill string to be lifted off the bottom of the wellbore.', 'SUMMARY\n \nA method for drilling a subterranean wellbore is disclosed.', 'In some embodiments, the method includes rotating a drill string in the wellbore to drill.', 'The drill string includes a drill collar, a drill bit, a roll-stabilized housing deployed in the drill collar, and a triaxial accelerometer set, a triaxial magnetometer set, and at least one gyroscopic sensor deployed in the roll-stabilized housing.', 'Sensor measurements are acquired while the drill string is rotating (e.g., drilling) and the triaxial accelerometer measurements and the gyroscopic sensor measurements are combined to obtain high bandwidth accelerometer measurements.', 'The high bandwidth accelerometer measurements and the triaxial magnetometer measurements are then processed to compute at least a wellbore azimuth of the subterranean wellbore while drilling.', 'In another embodiment, a method for drilling a subterranean wellbore includes rotating a drill string in the wellbore to drill.', 'The drill string includes a drill collar, a drill bit, a roll-stabilized housing deployed in the drill collar, and a triaxial accelerometer set and a triaxial magnetometer set deployed in the roll-stabilized housing.', 'Sensor measurements are acquired while the drill string is rotating (e.g., drilling) and processed to compute a wellbore azimuth of the subterranean wellbore while drilling.', 'The triaxial magnetometer measurements are further processed to compute an eddy current induced wellbore azimuth error which is then removed from the previously computed wellbore azimuth to obtain a corrected wellbore azimuth.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFor a more complete understanding of the disclosed subject matter, and advantages thereof, reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:\n \nFIG.', '1\n depicts a drilling rig on which disclosed embodiments may be utilized.\n \nFIG.', '2\n depicts a lower BHA portion of the drill string shown on \nFIG.', '1\n.', 'FIGS.', '3\nA and \n3\nB\n (collectively \nFIG.', '3\n) depict a schematic representation of a roll-stabilized housing deployed in a downhole tool.\n \nFIG.', '4\n depicts a flow chart of a method for drilling a subterranean wellbore.\n \nFIG.', '5\n depicts a combination of the gyroscopic sensor measurements and the accelerometer measurements to obtain high bandwidth accelerometer measurements.\n \nFIG.', '6\n depicts a flow chart of a method for drilling a subterranean wellbore.\n \nFIG.', '7\n depicts a flow chart of a method for drilling a subterranean wellbore.\n \nFIG.', '8\n depicts a flow chart of a method for computing an eddy current induced azimuth error in \nFIG.', '7\n.', 'FIG.', '9\n depicts a flow chart of a method for drilling a subterranean wellbore.', 'DETAILED DESCRIPTION', 'A method for drilling a subterranean wellbore is disclosed.', 'In some embodiments, the method includes rotating a drill string in the subterranean wellbore to drill the wellbore.', 'The drill string includes a drill collar, a drill bit, and survey sensors (e.g., a triaxial accelerometer set and a triaxial magnetometer set) deployed therein.', 'In the disclosed embodiments, the triaxial accelerometer set and the triaxial magnetometer set are deployed in a substantially geo-stationary roll-stabilized housing in the drill collar and are configured to make corresponding accelerometer and magnetometer measurements while drilling (while the drill string is rotating in the wellbore).', 'These measurements may be synchronized, for example via combining the accelerometer measurements with gyroscopic sensor measurements, to obtain accelerometer and magnetometer measurements having a common bandwidth and then further processed to compute at least an azimuth of the subterranean wellbore while drilling.', 'Some embodiments as disclosed herein may provide various technical advantages and improvements over the prior art.', 'For example, in some embodiments, an improved method and system for drilling a subterranean wellbore includes computing survey parameters such as wellbore inclination and wellbore azimuth (and optionally further including dip angle and magnetic toolface) in real time while drilling the well (e.g., several measurements per minute or several measurements per foot of measured depth of the wellbore).', 'Some embodiments may therefore provide a much higher density of survey measurements along the wellbore profile than are available via conventional static surveying methods.', 'This higher measurement density may then enable a more accurate wellbore path to be determined.', 'Improving the timeliness and density of wellbore surveys may further advantageously improve the speed and effectiveness of wellbore steering activities, such as anti-collision decision making.', 'Moreover, some embodiments provide accelerometer and magnetometer measurements having a common bandwidth and thereby advantageously improve the accuracy of the computed survey parameters as compared to prior art dynamic surveying methods.', 'In some embodiments, the accuracy of the computed survey parameters may be sufficiently high that there is no longer a need to make conventional static surveying measurements (or such that the number of required static surveys may be reduced).', 'This can greatly simplify wellbore drilling operations and significantly reduce the time and expense required to drill the well.', 'Moreover, eliminating or reducing the number of required static surveys may improve steerability, for example, via reducing wellbore washout in soft formations.', 'Such washout can be caused by drilling fluid circulation when the drill string is stationary and is known to cause subsequent steering problems.\n \nFIG.', '1\n depicts a drilling rig \n10\n suitable for implementing various method embodiments disclosed herein.', 'A semisubmersible drilling platform \n12\n is positioned over an oil or gas formation disposed below the sea floor \n16\n.', 'A subsea conduit \n18\n extends from deck \n20\n of platform \n12\n to a wellhead installation \n22\n.', 'The platform may include a derrick and a hoisting apparatus for raising and lowering a drill string \n30\n, which, as shown, extends into wellbore \n40\n and includes a drill bit \n32\n and a rotary steerable tool \n60\n.', 'Drill string \n30\n may further include a downhole drilling motor, a downhole telemetry system, and one or more MWD or LWD tools including various sensors for sensing downhole characteristics of the wellbore and the surrounding formation.', 'The disclosed embodiments are not limited in these regards.', 'It will be understood by those of ordinary skill in the art that the deployment illustrated on \nFIG.', '1\n is merely an example.', 'It will be further understood that disclosed embodiments are not limited to use with a semisubmersible platform \n12\n as illustrated on \nFIG.', '1\n.', 'The disclosed embodiments are equally well suited for use with any kind of subterranean drilling operation, either offshore or onshore.\n \nFIG.', '2\n depicts the lower BHA portion of drill string \n30\n, including drill bit \n32\n and rotary steerable tool \n60\n.', 'The rotary steerable tool may include substantially any suitable steering tool including a roll-stabilized controller (or control unit) deployed in a roll-stabilized housing or an otherwise substantially non-rotating housing.', 'By roll-stabilized it is meant that the sensor housing rotates independently from the drill string, and in some embodiments, it may be substantially non-rotating with the respect to the wellbore in certain operations (or may rotate very slowly in comparison to the drill string).', 'For example, various PowerDrive rotary steerable systems (available from Schlumberger) include a drill collar that is intended to fully rotate with the drill string and an internal roll-stabilized control unit that is intended (at certain times) to remain substantially rotationally geostationary (i.e., rotationally stable with respect to the tool axis, the tool axis attitude being defined with respect to the wellbore reference frame).', 'It will be understood that such rotary steerable systems may employ alternating active steering (or bias) and neutral phases to drill curved sections of a wellbore and primarily utilized the neutral phase to drill straight ahead.', 'During the active phase the roll-stabilized housing \n70\n tends to be rotationally geostationary (or rotate very slowly).', 'During the neutral phase the roll-stabilized housing \n70\n tends to rotate with respect to the wellbore (while remaining rotationally independent from the drill string) and can rotate at speeds near the drill string rotation rate.', 'The disclosed embodiments advantageously enable dynamic surveying measurements to be made and corrected while the roll-stabilized housing is rotating or non-rotating (e.g., while drilling in both the active (bias) and neutral phases).', 'It will of course be understood that control of the roll-stabilized housing is not limited to active steering and neutral phases and the roll-stabilized housing may rotate at any desired speed during active phases, neutral phases, or at any time.', 'Other rotary steerable systems, e.g., including the PathMaker rotary steerable system (available from PathFinder a Schlumberger Company), the AutoTrak rotary steerable system (available from Baker Hughes), and the GeoPilot rotary steerable system (available from Sperry Drilling Services), include a substantially non-rotating (or very slowly rotating) outer housing employing blades that engage the borehole wall.', 'While \nFIG.', '2\n depicts a rotary steerable tool \n60\n, it will be understood that the disclosed embodiments are not limited to the use of a rotary steerable tool.', 'Moreover, while navigation sensors \n65\n, \n67\n, and \n69\n (e.g., accelerometers, magnetometers, and gyroscopic sensors) may be deployed and the corresponding sensor measurements processed in a rotary steerable tool (e.g., as depicted on \nFIG.', '2\n)', ', they may also be located in a roll-stabilized housing (e.g., a housing that rotates independently of the drill string as described above) located substantially anywhere in the drill string.', 'For example, with reference again to \nFIG. \n1\n, drill string \n30\n may include a measurement while drilling tool \n50\n including corresponding sensors \n65\n, \n67\n, and \n69\n deployed in a roll-stabilized housing.', 'The MWD tool may include, for example, a PowerDrive Control Unit or other suitable device, employing substantially any suitable rotational control scheme (depending on particular operational demands) and having a rotation rate with respect to the wellbore in a range from about 0 (geostationary) to about the rotation rate of the drill string.', 'As is known to those of ordinary skill in the art, such MWD tools \n50\n may further include a mud pulse telemetry transmitter or other telemetry system, an alternator for generating electrical power, and an electronic controller.', 'It will thus be appreciated that the disclosed embodiments are not limited to any specific deployment location of the navigational sensors in the drill string.', 'With continued reference to \nFIGS. \n1\n and \n2\n, the depicted rotary steerable tool \n60\n and/or MWD tool \n50\n include(s) tri-axial accelerometer \n65\n and tri-axial magnetometer \n67\n navigation sensor sets and an inertial sensor \n69\n (such as a gyroscopic sensor).', 'These navigation sensors may include substantially any suitable available devices.', 'Suitable accelerometers for use in sensor set \n65\n may include, for example, conventional Q-flex types accelerometers or micro-electro-mechanical systems (MEMS) solid-state accelerometers.', 'Suitable magnetic field sensors for use in sensor set \n67\n may include, for example, conventional ring core flux gate magnetometers or magnetoresistive sensors.', 'Suitable gyroscopic sensors may include any of the variety of types of gyros used downhole, for example, including a rate gyro configured and deployed to measure a rotational velocity about a longitudinal axis of the drill string (a rate of change of toolface angle with time).', 'MEMS type gyros may be advantageous in that they are inexpensive and have no moving parts.\n \nFIG.', '2\n further includes a diagrammatic representation of the tri-axial accelerometer and magnetometer sensor sets \n65\n and \n67\n.', 'By tri-axial it is meant that each sensor set includes three mutually perpendicular sensors, the accelerometers being designated as A\nx\n, A\ny\n, and A\nz \nand the magnetometers being designated as B\nx\n, B\ny\n, and B\nz\n.', 'By convention, a right handed system is designated in which the z-axis accelerometer and magnetometer (A\nz \nand B\nz\n) are oriented substantially parallel with the tool axis (and therefore the wellbore axis) as indicated (although disclosed embodiments are not limited by such conventions).', 'Each of the accelerometer and magnetometer sets may therefore be considered as determining a plane (the x and y-axes) and a pole (the z-axis along the axis of the BHA).', 'FIG.', '2\n still further includes a diagrammatic representation of the gyroscopic sensor \n69\n.', 'The gyroscopic sensor \n69\n includes at least one gyroscope configured to measure a rotation rate about the z-axis (i.e., about the longitudinal axis of the drill string) and is therefore designated as R\nz\n.', 'Substantially any suitable gyroscopic sensor configured to measure a rotation rate about an axis may be utilized.', 'Such sensors may include, for example, single axis integrating gyros, dual axis rate gyros, optical gyros including fiber optic gyros, and MEMS gyros.', 'One example of a suitable gyroscopic sensor is disclosed in U.S. Pat.', 'No. 9,593,949.', 'Moreover, it will be understood that the disclosed embodiments are not limited to sensors including only a single gyroscopic sensor.', 'Any suitable number of gyroscopic sensors may be employed, for example, including one, two, three, or more (e.g., including a cross-axial gyroscope or a triaxial gyroscopic sensor set).', 'By convention, the gravitational field is taken to be positive pointing downward (i.e., toward the center of the earth) while the magnetic field is taken to be positive pointing towards magnetic north.', 'Moreover, also by convention, the y-axis is taken to be the toolface reference axis (i.e., gravity toolface GTF equals zero when the y-axis is uppermost and magnetic toolface MTF equals zero when the y-axis is pointing towards the projection of magnetic north in the xy plane).', 'The disclosed method embodiments are of course not limited to the above described conventions for defining wellbore coordinates.', 'These conventions can affect the form of certain of the mathematical equations that follow in this disclosure.', 'Those of ordinary skill in the art will be readily able to utilize other conventions and derive equivalent mathematical equations.', 'FIGS.', '3\nA and \n3\nB\n (collectively \nFIG.', '3\n) depict a schematic representation of one example of a roll-stabilized housing \n70\n deployed in a rotary steerable tool \n60\n (\nFIG. \n2\n).', 'It will be understood that this is merely an example and that the disclosed method embodiments are not limited to any particular roll-stabilizing mechanism or configuration.', 'In the depicted example, the roll-stabilized housing \n70\n is mounted on bearings \n72\n such that it is rotationally decoupled from (able to rotate independently with respect to) tool collar \n84\n.', 'In the depicted embodiment, first and second alternators \n80\n, \n85\n (e.g., of the permanent magnet synchronous motor type) are separately mounted on opposing axial ends of the roll-stabilized housing \n70\n.', 'The corresponding stator windings \n81\n, \n86\n are mechanically continuous with the roll-stabilized housing \n70\n (and are therefore rotationally coupled with the roll-stabilized housing).', 'Corresponding rotors including permanent magnets \n82\n, \n87\n are configured to rotate independently of both the roll-stabilized housing \n70\n and the tool collar \n84\n.', 'Impeller blades \n83\n, \n88\n are mechanically contiguous with the corresponding rotors and span the annular clearance between the housing \n70\n and the tool collar \n84\n such that they rotate, for example, in opposite directions with the flow of drilling fluid \n45\n through the tool.', 'In the depicted example, the rotational orientation of the housing \n70\n may be controlled by the co-action of the alternators \n80\n and \n85\n in combination with feedback provided by the sensors (e.g., accelerometers and/or magnetometers) deployed in the housing.', 'The impellers \n83\n and \n88\n being configured to rotate in opposite directions apply corresponding opposite torques to the housing \n70\n.', 'The amount of electrical load on the torque generators \n80\n and \n85\n may be changed in response to feedback from the at least one of the sensors \n65\n and \n67\n to vary the applied torques and thereby control the orientation of the housing.', 'When used in a rotary steerable system, the control unit may have an output shaft that is rigidly connected to a rotary valve.', 'The rotary valve directs fluid from the flow to an actuator in a steering bias unit, which then acts to steer the tool (e.g., by acting on the borehole wall or by acting on a bit shaft).', 'Thus by controlling the orientation of the control unit, the orientation of the rotary valve is controlled, thereby providing steering control.', 'FIG.', '4\n depicts a flow chart of embodiments \n100\n for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on \nFIGS.', '1\n and \n2\n) is rotated in the wellbore at \n102\n to drill the well.', 'The bottom hole assembly includes triaxial accelerometers, triaxial magnetometers, and at least one gyroscopic sensor deployed in a roll-stabilized housing.', 'Triaxial accelerometer and triaxial magnetometer measurements are made at \n104\n while drilling in \n102\n (i.e., while rotating the bottom hole assembly in the wellbore to drill the well).', 'Gyroscopic sensor measurements are also made while drilling the well at \n106\n.', 'The gyroscopic sensor measurements and the cross-axial components of the triaxial accelerometer measurements are combined at \n108\n to obtain high bandwidth cross-axial accelerometer measurements.', 'For example, the gyroscopic sensor measurement R\nz \n(the rotation rate about the z-axis) is combined with the cross-axial accelerometer measurements A\nx \nand A\ny \nto obtain high bandwidth cross-axial accelerometer measurements A\nx\n′ and A\ny\n′.', 'The triaxial magnetometer measurements B\nx\n, B\ny\n, and B\nz\n, the axial component of the triaxial accelerometer measurements A\nz\n, and the high bandwidth cross-axial accelerometer measurements A\nx\n′ and A\ny\n′ may then be processed at \n110\n to compute various survey parameters including the wellbore azimuth.', 'These parameters may then optionally be used for wellbore position and trajectory control at \n112\n while drilling continues in \n102\n.', 'For example, the direction of drilling in \n102\n may be adjusted in response to the survey parameters (e.g., by adjusting the position of blades or other actuating components in a rotary steerable tool) to continue drilling along a predetermined path.', 'In some embodiments, there may a phase delay between the accelerometer and magnetometer data streams that can result in significant errors in computed survey parameters.', 'Wellbore azimuth and dip angle are particularly susceptible to this phase delay since they are computed using a combination of accelerometer and magnetometer measurements.', 'The phase delay may be caused (at least in part) by bandwidth mismatch between the magnetometer and accelerometer measurements.', 'As disclosed herein, gyroscopic sensor measurements may be processed in combination with the accelerometer measurements to provide high bandwidth accelerometer measurements that may be bandwidth matched with the magnetometer measurements and thereby significantly reduce or eliminate the phase delay.', 'Accelerometer measurements are highly susceptible to external forces (e.g., vibration and shocks) and therefore tend to be heavily low pass filtered (or averaged).', 'This filtering severely limits the bandwidth of the corresponding accelerometer measurements.', 'Gyroscopic sensor measurements are not generally susceptible to external forces and can be used to make high bandwidth (frequency) toolface measurements by integrating the angular velocity (the rotation rate) over time.', 'However, owing to such mathematical integration, gyroscopic toolface measurements have a tendency to drift over time.', 'Combining the gyroscopic measurements with the accelerometer measurements may result in a combined measurement having attributes of both measurements (e.g., the best attributes of both measurements).', 'At high frequencies (short times), gyroscopic data may be favored since the gyroscopes are not susceptible to external forces while at low frequencies (longer times) the accelerometer data is favored since it does not drift.', 'FIG.', '5\n depicts one example of the combination (or fusion) of the gyroscopic sensor measurements and the accelerometer measurements.', 'The accelerometer measurements are processed to obtain an accelerometer based toolface angle measurement {circumflex over (θ)}', 'A \n(designated as {circumflex over (θ)}\nA\n=θ+{tilde over (θ)}n) at \n122\n in which θ represents the actual toolface angle and {tilde over (θ)}n represents the high frequency noise.', 'For example, a gravity toolface angle GTF may be computed using the equation {circumflex over (θ)}\nA\n=GTF=arctan (A\nx\n/A\ny\n).', 'The gyroscopic measurements are processed (e.g., via numerical integration as noted above) to obtain a gyroscope based toolface angle measurement {circumflex over (θ)}\ng \n(designated as {circumflex over (θ)}\ng\n=θ+θd) at \n124\n in which θ represents the actual toolface angle and θd represents the low frequency drift due to the integration.', 'The toolface angle measurement obtained at \n122\n is low pass filtered at \n126\n while the toolface angle measurement obtained at \n124\n is high pass filtered at \n128\n.', 'These filtered measurements are combined (e.g., summed) at \n130\n to obtain a high bandwidth (or substantially full spectrum) combined (or fused) toolface angle measurement {circumflex over (θ)} as indicated at \n132\n.', 'Based on the depiction in \nFIG.', '5\n, the high bandwidth combined toolface angle measurement {circumflex over (θ)} may be expressed as a mathematical sum of the accelerometer based toolface angle and the gyroscope based toolface angle, for example, as follows: \n {circumflex over (θ)}={circumflex over (θ)}\nA\n+{circumflex over (θ)}\ny\n\u2003\u2003(1a) \n \nCombining the low pass filtered accelerometer based toolface angle measurements and the high pass filtered gyroscope based toolface angle measurements gives a high bandwidth (full spectrum) toolface angle measurement in which the high frequency noise {tilde over (θ)}n and the drift θ′d are e.g., reduced or substantially eliminated.', 'This may be expressed mathematically, for example, as follows:\n \n \n \n \n \n \n \n \n \nθ\n \nˆ\n \n \n=\n \n \n \n \n \ns\n \n \nk\n \n+\n \ns\n \n \n \n·\n \nθ\n \n \n+\n \n \n \nk\n \n \nk\n \n+\n \ns\n \n \n \n·\n \nθ\n \n \n+\n \n \n \n \ns\n \n \nk\n \n+\n \ns\n \n \n \n·\n \nθ\n \n \n\u2062\n \nd\n \n \n+\n \n \n \n \nk\n \n \nk\n \n+\n \ns\n \n \n \n·\n \n \nθ\n \n˜\n \n \n \n\u2062\n \nn\n \n \n \n=\n \n \nθ\n \n+\n \n \n \n \nθ\n \n′\n \n \n\u2062\n \nd\n \n \n \nk\n \n+\n \ns\n \n \n \n+\n \n \n \n \nk\n \n \nk\n \n+\n \ns\n \n \n \n·\n \n \nθ\n \n˜\n \n \n \n\u2062\n \nn\n \n \n \n \n \n \n \n \n(\n \n \n1\n \n\u2062\n \nb\n \n \n)\n \n \n \n \n \n \n \n where the drift θ′d is bounded and in the steady state and settles to θ′d/k and the high frequency noise {tilde over (θ)}n is low pass filtered and attenuated.', 'High bandwidth accelerometer measurements A\nx\n′, A\ny\n′, and A\nz\n′ may be computed from the high bandwidth combined toolface angle measurement {circumflex over (θ)}, for example, as follows:', 'A\nx\n′=−sin(Inc)·cos({circumflex over (θ)})', 'A\ny\n′=sin(Inc)·sin({circumflex over (θ)})', 'A\nz\n′=cos(Inc)\u2003\u2003(2) \n where Inc represents the wellbore inclination.', 'The wellbore inclination may be obtained, for example, from a prior static survey or from the triaxial accelerometer measurements made in \n104\n.', 'The high bandwidth accelerometer measurements A\nx\n′, A\ny\n′, and A\nz\n′ may be advantageously bandwidth matched with the magnetometer measurements such that an improved wellbore azimuth may be computed from the high bandwidth accelerometer measurements and the magnetometer measurements.', 'The wellbore azimuth Azi may be computed from the high bandwidth accelerometer measurements A\nx\n′, A\ny\n′, and A\nz\n′ and the magnetometer measurements B\nx\n, B\ny\n, and B\nz\n, for example, as follows:\n \n \n \n \n \n \n \n \nAzi\n \n=\n \n \narctan\n \n\u2062\n \n \n(\n \n \n \n \n(\n \n \n \n \nA\n \nx\n \n′\n \n \n\u2062\n \n \nB\n \ny\n \n \n \n-\n \n \n \nA\n \ny\n \n′\n \n \n\u2062\n \n \nB\n \nx\n \n \n \n \n)\n \n \n·\n \n \n \n \nA\n \nx\n \n′2\n \n \n+\n \n \nA\n \ny\n \n′2\n \n \n+\n \n \nA\n \nz\n \n′2\n \n \n \n \n \n \n \n \nB\n \nz\n \n \n(\n \n \n \nA\n \nx\n \n′2\n \n \n+\n \n \nA\n \ny\n \n′2\n \n \n \n)\n \n \n-\n \n \n \nA\n \nz\n \n′\n \n \n(\n \n \n \n \nA\n \nx\n \n′\n \n \n\u2062\n \n \nB\n \nx\n \n \n \n-\n \n \n \nA\n \ny\n \n′\n \n \n\u2062\n \n \nB\n \ny\n \n \n \n \n)\n \n \n \n \n)\n \n \n \n \n \n \n \n(\n \n3\n \n)\n \n \n \n \n \n \n \n \nFIG.', '6\n depicts a flow chart of embodiments \n150\n for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on \nFIGS.', '1\n and \n2\n) is rotated in the wellbore at \n152\n to drill the well.', 'The bottom hole assembly includes accelerometers, magnetometers, and at least one gyroscopic sensor deployed in a roll-stabilized housing as described above with respect to method \n100\n (\nFIG. \n4\n).', 'At least one gyroscopic sensor measurement is made at \n154\n.', 'Triaxial accelerometer and triaxial magnetometer measurements are made at \n156\n and \n158\n while drilling in \n152\n (i.e., while rotating the bottom hole assembly in the wellbore to drill the well).', 'It will be understood that the magnetometer measurements can be corrupted by magnetic interference emanating from various elements in the drill string, e.g., including the drill bit, drill collar, mud motors, stabilizers, rotary steerable steering units, and the like.', 'The triaxial magnetometer measurements (or certain components thereof) may be processed at \n160\n to remove or reduce such magnetic interference.', 'For example, axial magnetic interference may optionally be removed from the axial magnetic field measurement B\nz \nusing multi-station analysis (MSA) at \n162\n to obtain a corrected axial magnetic field measurement B\nz\n′. Cross-axial magnetic interference may optionally be removed from the cross-axial magnetic field measurements B\nx \nand B\ny\n, for example, via filtering at \n164\n.', 'Rotation of the drill collar with respect to the roll-stabilized housing during drilling results in a time varying magnetic interference having a characteristic frequency (e.g., in a range from about 1 to about 4 Hz) that can be removed via filtering.', 'With continued reference to \nFIG.', "6\n, rotation of an electrically conductive drill collar in the Earth's magnetic field can induce eddy currents in the drill collar which in turn may generate appreciable magnetic interference.", 'The filtered cross-axial magnetic field measurements B\nx \nand B\ny \nmay therefore optionally be further processed at \n166\n to remove (or reduce) eddy current induced magnetic interference to obtain corrected cross-axial magnetic field measurements B\nx\n′ and B\ny\n′.\n \nAs described above with respect to \nFIGS.', '4\n and \n5\n, the gyroscopic sensor measurements and at least the cross-axial components of the triaxial accelerometer measurements may be combined at \n170\n to obtain high bandwidth cross-axial accelerometer measurements.', 'The high bandwidth accelerometer measurements and the corrected magnetometer measurements may be processed at \n172\n to compute various survey parameters including the wellbore azimuth.', 'These parameters may then optionally be used and further processed for wellbore position and trajectory control at \n174\n while drilling continues in \n152\n.', 'For example, as described above, the direction of drilling in \n152\n may be adjusted in response to the computed survey parameters (e.g., by adjusting the position of blades or other actuating components in a rotary steerable tool) to continue drilling along a predetermined path.', 'As noted above, axial magnetic interference may be removed from the axial magnetic field measurement, for example, using multi-station analysis at \n164\n.', 'Such multi-station analysis involves processing accelerometer and magnetometer measurements taken at \n156\n and \n158\n at a plurality of locations along the length of the wellbore (e.g., at multiple static survey stations) to determine axial magnetic interference (or axial and cross-axial interference).', 'The magnetic interference may then be subtracted from the axial (or axial and cross-axial) magnetometer measurements to obtain corrected axial magnetometer measurements.', 'Suitable multi-station analysis techniques are disclosed, for example, in U.S. Pat.', 'No. 8,280,638 as well as in \nBrooks et al, Practical Application of a Multiple\n-\nSurvey Magnetic Correction Algorithm, SPE \n49060, 1998 and \nChia and Lima, MWD Survey Accuracy Improvements Using Multistation Analysis, IADC/SPE \n87977, 2004, all of which are incorporated herein by reference in their entireties.', "As noted above, rotation of an electrically conductive drill collar in the Earth's magnetic field can induce eddy currents in the drill collar which in turn may generate appreciable magnetic interference.", 'This magnetic interference can in turn impart errors into survey parameters computed from the magnetometer measurements (e.g., wellbore azimuth and magnetic dip).', 'The error may be compensated at \n166\n by removing eddy current induced interference from the cross-axial magnetometer measurements.', 'For example, the eddy current induced interference may be determined based upon the rotation rate of the drill collar and the attitude (inclination and azimuth) of the wellbore and then subtracted from the filtered cross-axial magnetometer measurements.', 'FIG.', '7\n depicts embodiments \n150\n′ in which the magnetic interference is removed from the magnetometer measurements at \n160', '′', '(e.g., at \n162\n and \n164\n as described above with respect to \nFIG.', '6\n).', 'The high bandwidth accelerometer measurements and the corrected magnetometer measurements are used to compute survey parameters at \n172\n while drilling in \n152\n as also described above in \nFIG.', '6\n.', 'An eddy current induced azimuth error is computed at \n180\n.', 'Corrected survey parameters may be computed at \n174\n, for example, via removing (subtracting) the azimuth error from the wellbore azimuth computed in \n172\n.', 'In the depicted embodiment, the collar rotation rate is measured at \n182\n (e.g., using collar deployed radial magnetometers or other known methods) and processed to compute the eddy current induced azimuth error at \n184\n.\n \nFIG.', '8\n depicts embodiments \n180\n for computing the eddy current induced azimuth error.', 'A relationship is determined between eddy current induced toolface offset and drill collar rotation rate at \n181\n.', 'The drill collar rotation rate may be measured at \n182\n and processed in combination with the relationship determined in \n181\n to compute an eddy current induced toolface offset at \n183\n.', 'The eddy current induced toolface offset may be processed at \n184\n to compute an eddy current induced azimuth error.', 'The relationship between eddy current induced toolface offset and drill collar rotation rate may be determined, for example, by measuring the toolface offset at first and second drill collar rotation rates while drilling in \n152\n.', 'The eddy current induced toolface offset may be assumed to be substantially proportional to the drill collar rotation rate, for example, as in the following equation: \n α\nECI\n=k\n·RPM\u2003\u2003(4) \n where α\nECI \nrepresents the eddy current induced toolface offset, RPM represents the drill collar rotation rate, and k represents a proportionality constant.', 'The proportionality constant k may be determined based on toolface offset measurements made at first and second rotation rates, for example, as indicated in the following equation \n \n \n \n \n \n \n \n \nk\n \n=\n \n \n \n \nα\n \n2\n \n \n-\n \n \nα\n \n1\n \n \n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \n \nM\n \n2\n \n \n \n-\n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \n \nM\n \n1\n \n \n \n \n \n \n \n \n \n(\n \n5\n \n)\n \n \n \n \n \n \n \n where α\n1 \nand α\n2 \nrepresent toolface offset measurements made at the corresponding first and second drill collar rotation rates RPM\n1 \nand RPM\n2\n.', 'In one example embodiment, the first drill collar rotation rate RPM\n1 \nmay be essentially zero and the corresponding toolface offset α\n1 \nmay be computed, for example, based on static surveying measurements (although the disclosed embodiments are not limited in this regard).', 'The drill collar may then be rotated after completion of the static survey (at RPM\n2\n).', 'Accelerometer and magnetometer measurements may be made while rotating and a corresponding toolface offset α\n2 \ncomputed.', 'Subtraction of the static toolface offset from the rotating toolface offset yields the eddy current toolface offset at the collar rotation rate.', 'Toolface offset is the angular offset between the gravity (accelerometer based) toolface angle and the magnetic (magnetometer based) toolface angle and may be computed from the accelerometer and magnetometer measurements made in \n156\n and \n158\n and/or the corrected quantities obtained at \n160\n, \n160\n′ and \n170\n, for example as follows:\n \n \n \n \n \n \n \n \nα\n \n=\n \n \n \narctan\n \n\u2062\n \n \n(\n \n \n \n-\n \n \nA\n \nx\n \n′\n \n \n \n \n-\n \n \nA\n \ny\n \n′\n \n \n \n \n)\n \n \n \n-\n \n \narctan\n \n\u2062\n \n \n \n \n(\n \n \n \nB\n \nx\n \n′\n \n \n \nB\n \ny\n \n′\n \n \n \n)\n \n \n \n \n \n \n \n \n(\n \n6\n \n)', 'The toolface offset α may also be computed from the following equation:\n \n \n \n \n \n \n \n \nα\n \n=\n \n \narctan\n \n\u2061\n \n(\n \n \n \nsin\n \n\u2062\n \n \n \nA\n \n \n \n \nsin\n \n\u2062', 'I\n \n\u2062\n \n \n \ntan\n \n\u2062\n \n \n \nD\n \n \n-\n \n \ncos\n \n\u2062\n \n \n \nI\n \n\u2062\n \ncos\n \n\u2062\n \n \n \nA\n \n \n \n \n)\n \n \n \n \n \n \n(\n \n7\n \n)\n \n \n \n \n \n \n \n where A represents the wellbore azimuth, I represents the wellbore inclination, and D represents the dip angle of the wellbore.', 'Differentiating Equation 7 with respect to wellbore azimuth (A) and taking the reciprocal yields the following equation which relates a change in azimuth (dA) to a corresponding change in toolface offset angle (dα): \n \n \n \n \n \n \n \n \n \n \nd\n \n\u2062\n \nA\n \n \n \nd\n \n\u2062\n \nα\n \n \n \n=\n \n \n \n \n \n \n \n \n \ntan\n \n\u2061\n \n(\n \nD\n \n)\n \n \n2\n \n \n\u2062\n \n \n \nsin\n \n\u2061\n \n(\n \nI\n \n)\n \n \n2\n \n \n \n-\n \n \n \n \n \n \n \n \n2\n \n\u2062\n \ncos\n \n\u2062\n \n \n(\n \nA\n \n)', '\u2062\n \ntan\n \n\u2062\n \n \n(\n \nD\n \n)', '\u2062\n \ncos\n \n\u2062\n \n \n(\n \nI\n \n)\n \n \n\u2062\n \nsin\n \n\u2062\n \n \n(\n \nI\n \n)\n \n \n \n+\n \n \n \n \ncos\n \n\u2061\n \n(\n \nA\n \n)\n \n \n2\n \n \n\u2062\n \n \n \ncos\n \n\u2061\n \n(\n \nI\n \n)\n \n \n2\n \n \n \n+\n \n \n \nsin\n \n\u2061\n \n(\n \nA\n \n)', '2\n \n \n \n \n \n \n \n \n \ncos\n \n\u2061\n \n(\n \nA\n \n)\n \n \n\u2062\n \n \ntan\n \n\u2061\n \n(\n \nD\n \n)\n \n \n\u2062\n \n \nsin\n \n\u2061\n \n(\n \nI\n \n)\n \n \n \n-\n \n \ncos\n \n\u2061\n \n(\n \nI\n \n)\n \n \n \n \n \n \n \n \n(\n \n8\n \n)', 'The eddy current induced azimuth error may be computed at \n184\n, for example, via substituting α\nECI \nfrom Equation 4 into Equation 8 in place of dα and solving for the corresponding change in azimuth dA. This corresponding change in azimuth (the eddy current induced azimuth error) may then be added (or subtracted) to the wellbore azimuth computed at \n172\n to compute a corrected wellbore azimuth as described above with respect to \nFIG.', '7\n.', 'FIG.', '9\n depicts a flow chart of another example method embodiment \n190\n for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on \nFIGS.', '1\n and \n2\n) is rotated in the wellbore at \n191\n to drill the well.', 'The bottom hole assembly includes triaxial accelerometers and triaxial magnetometers deployed in a roll-stabilized housing.', 'Triaxial accelerometer and triaxial magnetometer measurements are made at \n192\n while drilling in \n191\n (i.e., while rotating the bottom hole assembly in the wellbore to drill the well).', 'The triaxial accelerometer and triaxial magnetometer measurements are processed in \n193\n to compute wellbore survey parameters including at least the wellbore azimuth.', 'The triaxial magnetometer measurements are further processed in \n194\n to compute an eddy current induced azimuth error, for example, as described above with respect to \nFIGS.', '7\n and \n8\n.', 'This eddy current induced azimuth error is then removed (e.g., via subtraction) from the wellbore azimuth computed in \n193\n to obtain corrected survey parameters (including a corrected wellbore azimuth) at \n195\n.', 'The corrected survey parameters may then optionally be used for wellbore position and trajectory control at \n196\n while drilling continues in \n191\n.', 'For example, the direction of drilling in \n191\n may be adjusted in response to the corrected survey parameters (e.g., by adjusting the position of blades or other actuating components in a rotary steerable tool) to continue drilling along a predetermined path.', 'With further reference to \nFIGS.', '4\n-\n9\n, various survey parameters may be computed as described above.', 'The computed survey parameters may include, for example, wellbore inclination, wellbore azimuth, gravity toolface, magnetic toolface, and magnetic dip angle.', 'These parameters may be computed using substantially any suitable known mathematical relationships and the corrected accelerometer A\nx\n′, A\ny\n′, and A\nz\n′ and/or magnetometer measurements B\nx\n′, B\ny\n′, and B\nz\n′.\n \nThe computed survey parameters may be stored in downhole memory and/or transmitted to the surface, for example, via mud pulse telemetry, electromagnetic telemetry, wired drill pipe, or other telemetry techniques.', 'In some embodiments, the accuracy of the computed parameters may be sufficient such that the drilling operation may forego the use of conventional static surveying techniques.', 'In such embodiments, the wellbore survey may be constructed at the surface based upon the transmitted measurements.', 'With still further reference to \nFIGS.', '4\n-\n9\n, the computed and/or corrected survey parameters may be used to control and/or change the direction of drilling.', 'For example, in many drilling operations the wellbore (or a portion of the wellbore) is drilled along a drill plan, such as a predetermined direction (e.g., as defined by the wellbore inclination and the wellbore azimuth) or a predetermined curvature.', 'In some embodiments, the computed wellbore inclination and wellbore azimuth may be compared with a desired inclination and azimuth.', 'The drilling direction may be changed, for example, in order to meet the drill plan, or when the difference between the computed and desired direction or curvature exceeds a predetermined threshold.', 'Such a change in drilling direction may be implemented, for example, via actuating steering elements in a rotary steerable tool deployed above the bit.', 'In some embodiments, the survey parameters may be sent directly to an RSS, which processes the survey parameters compared to the drill plan, (e.g., predetermined direction or predetermined curve) and changes drilling direction in order to meet the plan.', 'In some embodiments the survey parameters may be sent to the surface using telemetry so that the survey parameters may be analysed.', 'In view of the survey parameters, drilling parameters (e.g., weight on bit, rotation rate, mud pump rate, etc.) may be modified and/or a downlink may be sent to the RSS to change the drilling direction.', 'In some embodiments both downhole and surface control may be used.', 'It will be appreciated that the methods described herein may be configured for implementation via one or more controllers deployed downhole (e.g., in a rotary steerable tool or in an MWD tool).', 'A suitable controller may include, for example, a programmable processor, such as a digital signal processor or other microprocessor or microcontroller and processor-readable or computer-readable program code embodying logic.', 'A suitable processor may be utilized, for example, to execute the method embodiments (or various steps in the method embodiments) described above with respect to \nFIGS.', '4\n-\n9\n.', 'A suitable controller may also optionally include other controllable components, such as sensors (e.g., a temperature sensor), data storage devices, power supplies, timers, and the like.', 'The controller may also be disposed to be in electronic communication with the accelerometers and magnetometers.', 'A suitable controller may also optionally communicate with other instruments in the drill string, such as, for example, telemetry systems that communicate with the surface.', 'A suitable controller may further optionally include volatile or non-volatile memory or a data storage device.', 'Although a surveying while drilling method and certain advantages thereof have been described in detail, it should be understood that various changes, substitutions and alterations may be made herein without departing from the spirit and scope of the disclosure.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element or feature described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that is within standard manufacturing or process tolerances, or which still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.']

['1.', 'A method for drilling a subterranean wellbore, the method comprising:\n(a) rotating a drill string in the subterranean wellbore to drill, the drill string including a drill collar, a drill bit, a roll-stabilized housing deployed in the drill collar, and a triaxial accelerometer set, a triaxial magnetometer set, and at least one gyroscopic sensor deployed in the roll-stabilized housing;\n(b) causing the triaxial accelerometer set, the triaxial magnetometer set, and the gyroscopic sensor to make corresponding triaxial accelerometer measurements, triaxial magnetometer measurements, and gyroscopic sensor measurements while the drill string is rotating in (a);\n(c) combining the triaxial accelerometer measurements and the gyroscopic sensor measurements made in (b) to obtain accelerometer measurements wherein the combining in (c) comprises:\n(i) low pass filtering the triaxial accelerometer measurements to obtain filtered accelerometer measurements;\n(ii) high pass filtering the gyroscopic sensor measurements to obtain filtered gyroscopic sensor measurements; and\n(iii) combining the filtered accelerometer measurements and the filtered gyroscopic sensor measurements to obtain accelerometer measurements; and\n(d) processing the accelerometer measurements obtained in (c) and the triaxial magnetometer measurements made in (b) to compute survey parameters of the subterranean wellbore while drilling in (a), the survey parameters including at least a wellbore azimuth.', '2.', 'The method of claim 1, further comprising:\n(e) changing a direction of drilling the subterranean wellbore in response to the survey parameters computed in (d).', '3.', 'The method of claim 2, wherein:\nthe drill string further comprises a rotary steerable drilling tool deployed uphole from the drill bit, the roll-stabilized housing being deployed in the rotary steerable drilling tool; and\n(e) further comprises actuating a steering element on the rotary steerable drilling tool to change the direction of drilling.', '4.', 'The method of claim 1, wherein the accelerometer measurements are bandwidth matched with the triaxial magnetometer measurements.', '5.', 'The method of claim 1, wherein the combining in (c) comprises summing.', '6.', 'The method of claim 1, wherein the combining in (c) comprises:\nprocessing the triaxial accelerometer measurements to obtain accelerometer based toolface angle measurements;\n(ii) processing the gyroscopic sensor measurements to obtain gyroscope based toolface angle measurements;\n(iii) low pass filtering the accelerometer based toolface angle measurements to obtain filtered accelerometer based toolface angle measurements;\n(iv) high pass filtering the gyroscope based toolface angle measurements to obtain filtered gyroscope based toolface angle measurements; and\n(v) combining the filtered accelerometer based toolface angle measurements and the filtered gyroscope based toolface angle measurements to obtain toolface angle measurements.', '7.', 'The method of claim 6, wherein (c) further comprises:\n(vi) processing the toolface angle measurements to obtain the accelerometer measurements.', '8.', 'The method of claim 7, wherein the accelerometer measurements are computed according to the following equations:\nAx′=−sin(Inc)·cos({circumflex over (θ)})\nAy′=sin(Inc)·sin({circumflex over (θ)})\nAz′=cos(Inc)', 'wherein Ax′, Ay′, and Az′, represent the accelerometer measurements and Inc represents a wellbore inclination.', '9.', 'A method for drilling a subterranean wellbore, the method comprising:\n(a) rotating a drill string in the subterranean wellbore to drill, the drill string including a drill collar, a drill bit, a roll-stabilized housing deployed in the drill collar, and a triaxial accelerometer set and a triaxial magnetometer set deployed in the roll-stabilized housing;\n(b) causing the triaxial accelerometer set and the triaxial magnetometer set to make corresponding triaxial accelerometer measurements and triaxial magnetometer measurements while the drill string is rotating in (a);\n(c) processing the triaxial accelerometer measurements and the triaxial magnetometer measurements made in (b) to compute survey parameters of the subterranean wellbore while drilling in (a), the survey parameters including at least a wellbore azimuth;\n(d) processing the triaxial magnetometer measurements made in (b) to compute an eddy current induced wellbore azimuth error; and\n(e) removing the eddy current induced azimuth error computed in (d) from the wellbore azimuth computed in (c) to obtain a corrected wellbore azimuth.\n\n\n\n\n\n\n10.', 'The method of claim 9, wherein (d) comprises:\nprocessing accelerometer measurements and magnetometer measurements made during a previous static survey to compute a first toolface offset;\n(ii) processing the triaxial accelerometer measurements and the triaxial magnetometer measurements made in (b) to compute a second toolface offset;\n(iii) processing a difference between the second toolface offset and the first toolface offset to compute an eddy current induced toolface offset; and\n(iv) processing the eddy current induced toolface offset to compute the eddy current induced wellbore azimuth error.', '11.', 'The method of claim 9, wherein (d) comprises:\nprocessing the triaxial magnetometer measurements made in (b) to determine a relationship between an eddy current induced toolface offset and a rotation rate of the drill collar in (a);\n(ii) measuring the rotation rate of the drill collar;\n(iii) processing the rotation rate of the drill collar and the relationship determined in (i) to compute an eddy current induced toolface offset; and\n(iv) processing the eddy current induced toolface offset to compute the eddy current induced wellbore azimuth error.', '12.', 'A method for drilling a subterranean wellbore, the method comprising:\n(a) rotating a drill string in the subterranean wellbore to drill, the drill string including a drill collar, a drill bit, a roll-stabilized housing deployed in the drill collar, and a triaxial accelerometer set, a triaxial magnetometer set, and at least one gyroscopic sensor deployed in the roll-stabilized housing;\n(b) causing the triaxial accelerometer set, the triaxial magnetometer set, and the gyroscopic sensor to make corresponding triaxial accelerometer measurements, triaxial magnetometer measurements, and gyroscopic sensor measurements while the drill string is rotating in (a);\n(c) combining the triaxial accelerometer measurements and the gyroscopic sensor measurements made in (b) to obtain accelerometer measurements;\n(d) processing the triaxial magnetometer measurements to remove magnetic interference from the magnetometer measurements and to obtain corrected magnetometer measurements wherein the processing comprises:\ni) filtering cross-axial components of the triaxial magnetometer measurements to remove cross-axial magnetic interference and obtain filtered cross-axial magnetic field measurements; and\n(ii) processing the filtered cross-axial magnetic field measurements to remove magnetic interference induced by eddy currents flowing in the rotating drill collar to obtain corrected cross-axial magnetic field measurements; and\n(e) processing the accelerometer measurements obtained in (c) and the corrected magnetometer measurements obtained in (d) to compute survey parameters of the subterranean wellbore while drilling in (a), the survey parameters including at least a wellbore azimuth.', '13.', 'The method of claim 12, further comprising:\nchanging a direction of drilling the subterranean wellbore in response to the survey parameters computed in (e).', '14.', 'The method of claim 13, wherein:\nthe drill string further comprises a rotary steerable drilling tool deployed uphole from the drill bit, the roll-stabilized housing being deployed in the rotary steerable drilling tool; and\n(f) further comprises actuating a steering element on the rotary steerable drilling tool to change the direction of drilling.', '15.', 'The method of claim 12, wherein the processing in (d) comprises:\nprocessing an axial component of the triaxial magnetometer measurements using multi-station analysis to remove axial magnetic interference and obtain a corrected axial magnetic field measurement.', '16.', 'The method of claim 12, wherein the processing in (e) comprises:\nprocessing the accelerometer measurements obtained in (c) and the corrected magnetometer measurements obtained in (d) to compute survey parameters of the subterranean wellbore while drilling in (a), the survey parameters including at least a wellbore azimuth;\n(ii) processing the corrected magnetometer measurements obtained in (d) to compute an eddy current induced wellbore azimuth error; and\n(iii) removing the eddy current induced azimuth error computed in (ii) from the wellbore azimuth computed in (i) to obtain a corrected wellbore azimuth.', '17.', 'The method of claim 16, wherein (ii) further comprises processing a rotation rate of the drill collar in (a) to compute the eddy current induced wellbore azimuth error.', '18.', 'The method of claim 16, wherein (ii) comprises:\n(iia) processing the corrected magnetometer measurements obtained in (d) to determine a relationship between an eddy current induced toolface offset and a rotation rate of the drill collar in (a);\n(iib) measuring the rotation rate of the drill collar;\n(iic) processing the rotation rate of the drill collar and the relationship determined in (iia) to compute an eddy current induced toolface offset; and\n(iid) processing the eddy current induced toolface offset to compute the eddy current induced wellbore azimuth error.', '19.', 'The method of claim 16, wherein (ii) comprises:\n(iia) processing accelerometer and magnetometer measurements made during a previous static survey to compute a first toolface offset;\n(iib) processing the accelerometer measurements and the corrected magnetometer measurements to compute a second toolface offset;\n(iic) processing a difference between the second toolface offset and the first toolface offset to compute an eddy current induced toolface offset; and\n(iid) processing the eddy current induced toolface offset to compute the eddy current induced wellbore azimuth error.', '20.', 'The method of claim 12, wherein the combining in (c) comprises:\nprocessing the triaxial accelerometer measurements to obtain accelerometer based toolface angle measurements;\n(ii) processing the gyroscopic sensor measurements to obtain gyroscope based toolface angle measurements;\n(iii) low pass filtering the accelerometer based toolface angle measurements to obtain filtered accelerometer based toolface angle measurements;\n(iv) high pass filtering the gyroscope based toolface angle measurements to obtain filtered gyroscope based toolface angle measurements;\n(v) combining the filtered accelerometer based toolface angle measurements and the filtered gyroscope based toolface angle measurements to obtain toolface angle measurements; and\n(vi) processing the toolface angle measurements to obtain the accelerometer measurements.']

['FIG.', '1 depicts a drilling rig on which disclosed embodiments may be utilized.; FIG.', '2 depicts a lower BHA portion of the drill string shown on FIG.', '1.; FIGS.', '3A and 3B (collectively FIG.', '3) depict a schematic representation of a roll-stabilized housing deployed in a downhole tool.; FIG.', '4 depicts a flow chart of a method for drilling a subterranean wellbore.; FIG.', '5 depicts a combination of the gyroscopic sensor measurements and the accelerometer measurements to obtain high bandwidth accelerometer measurements.; FIG.', '6 depicts a flow chart of a method for drilling a subterranean wellbore.; FIG.', '7 depicts a flow chart of a method for drilling a subterranean wellbore.; FIG.', '8 depicts a flow chart of a method for computing an eddy current induced azimuth error in FIG.', '7.; FIG.', '9 depicts a flow chart of a method for drilling a subterranean wellbore.; FIG.', '1 depicts a drilling rig 10 suitable for implementing various method embodiments disclosed herein.', 'A semisubmersible drilling platform 12 is positioned over an oil or gas formation disposed below the sea floor 16.', 'A subsea conduit 18 extends from deck 20 of platform 12 to a wellhead installation 22.', 'The platform may include a derrick and a hoisting apparatus for raising and lowering a drill string 30, which, as shown, extends into wellbore 40 and includes a drill bit 32 and a rotary steerable tool 60.', 'Drill string 30 may further include a downhole drilling motor, a downhole telemetry system, and one or more MWD or LWD tools including various sensors for sensing downhole characteristics of the wellbore and the surrounding formation.', 'The disclosed embodiments are not limited in these regards.; FIG.', '2 depicts the lower BHA portion of drill string 30, including drill bit 32 and rotary steerable tool 60.', 'The rotary steerable tool may include substantially any suitable steering tool including a roll-stabilized controller (or control unit) deployed in a roll-stabilized housing or an otherwise substantially non-rotating housing.', 'By roll-stabilized it is meant that the sensor housing rotates independently from the drill string, and in some embodiments, it may be substantially non-rotating with the respect to the wellbore in certain operations (or may rotate very slowly in comparison to the drill string).', 'For example, various PowerDrive rotary steerable systems (available from Schlumberger) include a drill collar that is intended to fully rotate with the drill string and an internal roll-stabilized control unit that is intended (at certain times) to remain substantially rotationally geostationary (i.e., rotationally stable with respect to the tool axis, the tool axis attitude being defined with respect to the wellbore reference frame).', 'It will be understood that such rotary steerable systems may employ alternating active steering (or bias) and neutral phases to drill curved sections of a wellbore and primarily utilized the neutral phase to drill straight ahead.', 'During the active phase the roll-stabilized housing 70 tends to be rotationally geostationary (or rotate very slowly).', 'During the neutral phase the roll-stabilized housing 70 tends to rotate with respect to the wellbore (while remaining rotationally independent from the drill string) and can rotate at speeds near the drill string rotation rate.', 'The disclosed embodiments advantageously enable dynamic surveying measurements to be made and corrected while the roll-stabilized housing is rotating or non-rotating (e.g., while drilling in both the active (bias) and neutral phases).', 'It will of course be understood that control of the roll-stabilized housing is not limited to active steering and neutral phases and the roll-stabilized housing may rotate at any desired speed during active phases, neutral phases, or at any time.', '; FIG.', '2 further includes a diagrammatic representation of the tri-axial accelerometer and magnetometer sensor sets 65 and 67.', 'By tri-axial it is meant that each sensor set includes three mutually perpendicular sensors, the accelerometers being designated as Ax, Ay, and Az and the magnetometers being designated as Bx, By, and Bz.', 'By convention, a right handed system is designated in which the z-axis accelerometer and magnetometer (Az and Bz) are oriented substantially parallel with the tool axis (and therefore the wellbore axis) as indicated (although disclosed embodiments are not limited by such conventions).', 'Each of the accelerometer and magnetometer sets may therefore be considered as determining a plane (the x and y-axes) and a pole (the z-axis along the axis of the BHA).; FIG.', '2 still further includes a diagrammatic representation of the gyroscopic sensor 69.', 'The gyroscopic sensor 69 includes at least one gyroscope configured to measure a rotation rate about the z-axis (i.e., about the longitudinal axis of the drill string) and is therefore designated as Rz.', 'Substantially any suitable gyroscopic sensor configured to measure a rotation rate about an axis may be utilized.', 'Such sensors may include, for example, single axis integrating gyros, dual axis rate gyros, optical gyros including fiber optic gyros, and MEMS gyros.', 'One example of a suitable gyroscopic sensor is disclosed in U.S. Pat.', 'No. 9,593,949.', 'Moreover, it will be understood that the disclosed embodiments are not limited to sensors including only a single gyroscopic sensor.', 'Any suitable number of gyroscopic sensors may be employed, for example, including one, two, three, or more (e.g., including a cross-axial gyroscope or a triaxial gyroscopic sensor set).', '; FIGS.', '3A and 3B (collectively FIG.', '3) depict a schematic representation of one example of a roll-stabilized housing 70 deployed in a rotary steerable tool 60 (FIG. 2).', 'It will be understood that this is merely an example and that the disclosed method embodiments are not limited to any particular roll-stabilizing mechanism or configuration.', 'In the depicted example, the roll-stabilized housing 70 is mounted on bearings 72 such that it is rotationally decoupled from (able to rotate independently with respect to) tool collar 84.', 'In the depicted embodiment, first and second alternators 80, 85 (e.g., of the permanent magnet synchronous motor type) are separately mounted on opposing axial ends of the roll-stabilized housing 70.', 'The corresponding stator windings 81, 86 are mechanically continuous with the roll-stabilized housing 70 (and are therefore rotationally coupled with the roll-stabilized housing).', 'Corresponding rotors including permanent magnets 82, 87 are configured to rotate independently of both the roll-stabilized housing 70 and the tool collar 84.', 'Impeller blades 83, 88 are mechanically contiguous with the corresponding rotors and span the annular clearance between the housing 70 and the tool collar 84 such that they rotate, for example, in opposite directions with the flow of drilling fluid 45 through the tool.', '; FIG.', '4 depicts a flow chart of embodiments 100 for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on FIGS.', '1 and 2) is rotated in the wellbore at 102 to drill the well.', 'The bottom hole assembly includes triaxial accelerometers, triaxial magnetometers, and at least one gyroscopic sensor deployed in a roll-stabilized housing.', 'Triaxial accelerometer and triaxial magnetometer measurements are made at 104 while drilling in 102 (i.e., while rotating the bottom hole assembly in the wellbore to drill the well).', 'Gyroscopic sensor measurements are also made while drilling the well at 106.', 'The gyroscopic sensor measurements and the cross-axial components of the triaxial accelerometer measurements are combined at 108 to obtain high bandwidth cross-axial accelerometer measurements.', 'For example, the gyroscopic sensor measurement Rz (the rotation rate about the z-axis) is combined with the cross-axial accelerometer measurements Ax and Ay to obtain high bandwidth cross-axial accelerometer measurements Ax′', 'and', 'Ay′. The triaxial magnetometer measurements Bx, By, and Bz, the axial component of the triaxial accelerometer measurements Az, and the high bandwidth cross-axial accelerometer measurements Ax′ and Ay′ may then be processed at 110 to compute various survey parameters including the wellbore azimuth.', 'These parameters may then optionally be used for wellbore position and trajectory control at 112 while drilling continues in 102.', 'For example, the direction of drilling in 102 may be adjusted in response to the survey parameters (e.g., by adjusting the position of blades or other actuating components in a rotary steerable tool) to continue drilling along a predetermined path.', '; FIG.', '5 depicts one example of the combination (or fusion) of the gyroscopic sensor measurements and the accelerometer measurements.', 'The accelerometer measurements are processed to obtain an accelerometer based toolface angle measurement {circumflex over (θ)}A (designated as {circumflex over (θ)}A=θ+{tilde over (θ)}n) at 122 in which θ represents the actual toolface angle and {tilde over (θ)}n represents the high frequency noise.', 'For example, a gravity toolface angle GTF may be computed using the equation {circumflex over (θ)}A=GTF=arctan (Ax/Ay).', 'The gyroscopic measurements are processed (e.g., via numerical integration as noted above) to obtain a gyroscope based toolface angle measurement {circumflex over (θ)}g (designated as {circumflex over (θ)}g=θ+θd) at 124 in which θ represents the actual toolface angle and θd represents the low frequency drift due to the integration.', 'The toolface angle measurement obtained at 122 is low pass filtered at 126 while the toolface angle measurement obtained at 124 is high pass filtered at 128.', 'These filtered measurements are combined (e.g., summed) at 130 to obtain a high bandwidth (or substantially full spectrum) combined (or fused) toolface angle measurement {circumflex over (θ)} as indicated at 132.; FIG.', '6 depicts a flow chart of embodiments 150 for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on FIGS.', '1 and 2) is rotated in the wellbore at 152 to drill the well.', 'The bottom hole assembly includes accelerometers, magnetometers, and at least one gyroscopic sensor deployed in a roll-stabilized housing as described above with respect to method 100 (FIG. 4).', 'At least one gyroscopic sensor measurement is made at 154.', 'Triaxial accelerometer and triaxial magnetometer measurements are made at 156 and 158 while drilling in 152 (i.e., while rotating the bottom hole assembly in the wellbore to drill the well).', '; FIG.', '7 depicts embodiments 150′ in which the magnetic interference is removed from the magnetometer measurements at 160′ (e.g., at 162 and 164 as described above with respect to FIG. 6).', 'The high bandwidth accelerometer measurements and the corrected magnetometer measurements are used to compute survey parameters at 172 while drilling in 152 as also described above in FIG.', '6.', 'An eddy current induced azimuth error is computed at 180.', 'Corrected survey parameters may be computed at 174, for example, via removing (subtracting) the azimuth error from the wellbore azimuth computed in 172.', 'In the depicted embodiment, the collar rotation rate is measured at 182 (e.g., using collar deployed radial magnetometers or other known methods) and processed to compute the eddy current induced azimuth error at 184.; FIG.', '8 depicts embodiments 180 for computing the eddy current induced azimuth error.', 'A relationship is determined between eddy current induced toolface offset and drill collar rotation rate at 181.', 'The drill collar rotation rate may be measured at 182 and processed in combination with the relationship determined in 181 to compute an eddy current induced toolface offset at 183.', 'The eddy current induced toolface offset may be processed at 184 to compute an eddy current induced azimuth error.; FIG.', '9 depicts a flow chart of another example method embodiment 190 for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on FIGS.', '1 and 2) is rotated in the wellbore at 191 to drill the well.', 'The bottom hole assembly includes triaxial accelerometers and triaxial magnetometers deployed in a roll-stabilized housing.', 'Triaxial accelerometer and triaxial magnetometer measurements are made at 192 while drilling in 191 (i.e., while rotating the bottom hole assembly in the wellbore to drill the well).', 'The triaxial accelerometer and triaxial magnetometer measurements are processed in 193 to compute wellbore survey parameters including at least the wellbore azimuth.', 'The triaxial magnetometer measurements are further processed in 194 to compute an eddy current induced azimuth error, for example, as described above with respect to FIGS.', '7 and 8.', 'This eddy current induced azimuth error is then removed (e.g., via subtraction) from the wellbore azimuth computed in 193 to obtain corrected survey parameters (including a corrected wellbore azimuth) at 195.', 'The corrected survey parameters may then optionally be used for wellbore position and trajectory control at 196 while drilling continues in 191.', 'For example, the direction of drilling in 191 may be adjusted in response to the corrected survey parameters (e.g., by adjusting the position of blades or other actuating components in a rotary steerable tool) to continue drilling along a predetermined path.']

USD1009070

Electronic device with display screen and graphical user interface

Jul 10, 2020

Zhen Li, Adelle Knight, Sacha Brants-Menard

Schlumberger Technology Corporation

Notice of Allowance issued in U.S. Appl. No. 29/652,292 dated Mar. 1, 2023; 6 pages.; Office Action issued in U.S. Appl. No. 29/652,296 dated Jan. 20, 2023, 18 pages.; Color changing sreensaver 4:3(10mins), by Computer World, dated Sep. 12, 2013, youtube.com [online]. Retrieved Feb. 25, 3033 from internet <URL: https://www.youtube.com/watch?v=kjlGhhhVp0c> (Year: 2013).; Working with Bootstrap and WCAG Color Contrast Ratios, by Dan Cox, dated Jan. 24, 2017, videlais.com [online]. Retrieved Feb. 25, 2022 from internet <URL:https://videlais.com/2017/01/24/working-with-bootstrap-and-wcag-color-contrast-ratios/> (Year: 2017).; Charts—palette extension modes, by dxbykov, dated Mar. 6, 2018, github.com [online]. Retrieved Jun. 21, 2022 from Internet <URL:https://github.com/DevExpress/DevExtreme/issues/3211> (Year: 2018).; Making a roulete style Poly Wheel in Java, edited Dec. 26, 2017, stackoverflow.com [online]. Retrieved Jun. 21, 2022 from internet <URL:http://github.com/DevExpress/DevExtreme/issues/3211> (Year: 2017).

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Foreign Citations not found.

['No Abstract Available']

['Description\n\n\n\n\n\n\n \nThe patent or application file contains at least one drawing executed in color.', 'Copies of this patent or patent application publication with color drawing(s) will be provided by the Office upon request and payment of the necessary fee.', 'The FIGURE shows a view of an electronic device with display screen and graphical user interface.', 'The even-dashed broken lines showing the electronic device with display screen and portions of the graphical user interface, including all icons shown and all text shown outside of the dot-dashed boundary lines, illustrate portions of the article of manufacture that form no part of the claimed design.', 'The white dot-dashed broken line rectangle on the left side of the display screen, and the two black dot-dashed rectangles on the right side of the display screen, illustrate the bounds of the claimed design and form no part thereof.', 'The lighter grey ghosted areas appearing outside of the dot-dash broken lines illustrate portions of the graphical user interface that form no part of the claimed design.']

['The ornamental design for an electronic device with display screen and graphical user interface, as shown and described.']

['No Captions Available']

US11920599

Thrust handling for electric submersible pumps

Sep 18, 2020

Raju Ekambaram, Teng Fei Wang, Pradeep Mahadevan, Kean Wee Cheah, David Milton Eslinger

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in the PCT Application PCT/US2020/051408, dated Dec. 23, 2020 (10 pages).

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2016032439; March 2016; WO

['An electric submersible pump includes a plurality of centrifugal pump stages, each stage including a rotating impeller and a stationary diffuser mounted on a shaft coupled to a motor.', 'An upthrust washer can be disposed axially between an impeller and its associated diffuser at or near a tip of the impeller, and the gap between the impeller tip and diffuser can define the end play or axial clearance for the pump.', 'If the upthrust washer wears away, upthrust rubbing occurs at the impeller tip instead of proximate the pump shaft to advantageously help protect the shaft from damage or failure related to heat.', 'In some ESPs, an upthrust bearing assembly can be located at the pump head.', 'A downthrust washer can be disposed in an upstream facing groove of the impeller.', 'The downthrust washer can have a thickness greater than 0.10 in.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nAny and all applications for which a foreign or domestic priority claim is identified in the Application Data Sheet as filed with the present application are hereby incorporated by reference under 37 CFR 1.57.', 'The present application claims priority benefit of Singapore Application No. SG 10201908737X, filed Sep. 19, 2019, and Provisional U.S. Patent Application No. 62/912,397, filed Oct. 8, 2019, the entirety of each of which is incorporated by reference herein and should be considered part of this specification.', 'BACKGROUND\n \nField\n \nThe present disclosure generally relates to systems and methods for artificial lift in oil and gas wells, and more particularly to thrust handling systems and methods for use in electric submersible pumps.', 'Description of the Related Art\n \nVarious types of artificial lift equipment and methods are available, for example, electric submersible pumps (ESPs).', 'An ESP includes multiple centrifugal pump stages mounted in series, each stage including a rotating impeller and a stationary diffuser mounted on a shaft, which is coupled to a motor.', 'In use, the motor rotates the shaft, which in turn rotates the impellers within the diffusers.', 'Well fluid flows into the lowest stage and passes through the first impeller, which centrifuges the fluid radially outward such that the fluid gains energy in the form of velocity.', 'Upon exiting the impeller, the fluid flows into the associated diffuser, where fluid velocity is converted to pressure.', 'As the fluid moves through the pump stages, the fluid incrementally gains pressure until the fluid has sufficient energy to travel to the well surface.', 'One or more thrust assemblies, for example, upthrust assemblies and/or downthrust assemblies, can be disposed axially between a portion of the impeller and a portion of the associated diffuser, and/or operatively connect the impeller and diffuser.', 'The thrust assemblies can help absorb or accommodate thrust in use.', 'SUMMARY', 'In some configurations, an electric submersible pump (ESP) includes a plurality of stages, at least one stage comprising a rotating impeller rotationally fixed to a shaft of the ESP, a stationary diffuser rotationally fixed to a housing of the ESP, and an upthrust washer disposed axially between a portion of the impeller and a portion of the diffuser.', 'The upthrust washer is disposed radially outside of the balance ring.', 'The ESP can include a second upthrust washer disposed adjacent a leading edge shoulder of the diffuser.', 'The second upthrust washer can include one or more lubrication grooves.', 'A balance ring of the impeller can include one or more lubrication grooves.', 'The diffuser can include one or more lubrication grooves.', 'A central hub of the diffuser can include one or more lubrication grooves in a leading or upstream edge of the central hub.', 'A ring surrounding a central hub of the diffuser can include one or more lubrication grooves in a leading edge shoulder of the ring.', 'The upthrust washer can be made of or include phenolic material, tungsten carbide, silicon carbide, and/or any other suitable material, such as a wear resistant material and/or coating.', 'An axial gap between the portion of the impeller and the portion of the diffuser can be smaller than an axial gap between a downstream edge of a balance ring of the impeller and the diffuser.', 'An axial gap between the portion of the impeller and the portion of the diffuser can be smaller than an axial gap between the diffuser and an upwardly facing surface of the impeller disposed radially between a central hub of the impeller and a balance ring of the impeller.', 'In some configurations, the ESP includes a bearing assembly disposed radially between the shaft and the diffuser.', 'An axial gap between the portion of the impeller and the portion of the diffuser can be smaller than an axial gap between the bearing assembly and an upwardly facing surface of the impeller disposed radially between a central hub of the impeller and a balance ring of the impeller.', 'In some configurations, an electric submersible pump (ESP) includes a plurality of centrifugal stages, each stage comprising a rotating impeller and a stationary diffuser disposed about a rotating shaft, and an upthrust bearing assembly.', 'The upthrust bearing assembly includes a bearing sleeve disposed about the shaft and rotationally keyed to the shaft, a stationary bushing disposed about the bearing sleeve, the bushing having a generally T-shaped longitudinal cross-section shape and a bore extending longitudinally therethrough, the bushing having a base portion and a thrust pad at an upstream end of the base portion, and an upthrust bearing runner disposed about the shaft upstream of the bushing, the upthrust bearing runner configured to move toward an upthrust surface of the thrust pad of the bushing when the ESP operates in an upthrust condition.', 'The upthrust bearing can be disposed proximate a top or downstream end of the plurality of centrifugal stages.', 'The upthrust bearing can be disposed in a pump head section.', 'The upthrust surface can include one or more grooves configured to allow fluid flow.', 'The ESP can include a compliance between the upthrust bearing and the head section to prevent or inhibit impact loading on the bearing.', 'The bushing can include an anti-rotation feature configured to rotationally fix the bushing.', 'The anti-rotation feature can include notches in a downstream end of the base portion and/or a downstream surface of the thrust pad.', 'The anti-rotation feature can include a groove in an outer surface of the base portion extending axially along at least a portion of a length of the base portion.', 'In some configurations, an electric submersible pump (ESP) includes a plurality of centrifugal stages, each stage comprising a rotating impeller and a stationary diffuser disposed about a rotating shaft; and at least one impeller comprising a downthrust washer disposed in an upstream facing groove of the impeller, the downthrust washer having an axial thickness such that the downthrust washer extends upstream and out of the groove.', 'The downthrust washer can have a thickness greater than 0.10 in.', 'BRIEF DESCRIPTION OF THE FIGURES\n \nCertain embodiments, features, aspects, and advantages of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein.\n \nFIG.', '1\n shows a schematic of an electric submersible pump (ESP) system.\n \nFIG.', '2\nA\n shows a cross-section of a portion of a pump section of the ESP system of \nFIG.', '1\n.', 'FIG.', '2\nB\n shows a cross-section of a portion of a pump section of another embodiment of an ESP pump.\n \nFIG.', '3\n shows the cross-section of \nFIG.', '2\nA\n showing gaps between various components.\n \nFIG.', '4\n shows a perspective view of an example embodiment of an impeller including an upthrust washer.\n \nFIG.', '5\nA\n shows a cross-section of an example embodiment of a bearing housing including lubrication grooves.\n \nFIG.', '5\nB\n shows a perspective view of an example embodiment of a diffuser including lubrication grooves.\n \nFIG.', '6\n shows a cross-section of a portion of an example embodiment of a pump section of an ESP including the impeller of \nFIG.', '4\n, the bearing housing of \nFIG.', '5\nA\n, and the diffuser of \nFIG.', '5\nB\n.\n \nFIG.', '7\nA\n shows a cross-section of an example embodiment of a bearing housing including an upthrust washer and lubrication grooves.\n \nFIG.', '7\nB\n shows a perspective of an example embodiment of a diffuser including an upthrust washer and lubrication grooves.\n \nFIG.', '8\n shows a cross-section of a portion of an example embodiment of a pump section of an ESP including the impeller of \nFIG.', '4\n, the bearing housing of \nFIG.', '7\nA\n, and the diffuser of \nFIG.', '7\nB\n.\n \nFIG.', '9\n shows a cross-section of a portion of a pump section of an ESP including an example embodiment of an upthrust bearing.\n \nFIG.', '10\n shows a close-up cross-section of a portion of \nFIG.', '9\n.', 'FIGS.', '11\nA-\n11\nB\n show views of the upthrust bearing of \nFIG.', '10\n.\n \nFIG.', '12\n shows a cross-section of a pump section of an ESP including another example embodiment of an upthrust bearing.', 'FIGS.', '13\nA-\n13\nB\n show views of the upthrust bearing of \nFIG.', '12\n.', 'FIGS.', '14\nA-\n14\nB\n show views of another example embodiment of an upthrust bearing.\n \nFIG.', '15\n shows a perspective view of an example embodiment of an upthrust runner.\n \nFIG.', '16\nA\n shows an impeller including a traditional downthrust washer.\n \nFIG.', '16\nB\n shows an impeller including an example embodiment of a thicker downthrust washer according to the present disclosure.\n \nFIG.', '17\n shows a cross-section of an example embodiment of a pump section of an ESP including the thicker downthrust washer of \nFIG.', '16\nB\n.\n \nFIG.', '18\n shows a partial cross-section of another example embodiment of a pump section of an ESP including the thicker downthrust washer of \nFIG.', '16\nB\n.\n \nFIG.', '19\n shows a partial cross-section of a pump section of an ESP including the thicker downthrust washer of \nFIG.', '16\nB\n.\n \nFIG.', '20\nA\n shows an impeller that included the traditional downthrust washer of \nFIG.', '16\nA\n after a mini sand loop test.', 'FIG.', '20\nB\n shows an impeller that included the thicker downthrust washer of \nFIG.', '16\nB\n after a mini sand loop test.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments.', 'Specific examples of components and arrangements are described below to simplify the disclosure.', 'These are, of course, merely examples and are not intended to be limiting.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments are possible.', 'This description is not to be taken in a limiting sense, but rather made merely for the purpose of describing general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.', 'As used herein, the terms “connect”, “connection”, “connected”, “in connection with”, and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element”.', 'Further, the terms “couple”, “coupling”, “coupled”, “coupled together”, and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements”.', 'As used herein, the terms “up” and “down”; “upper” and “lower”; “top” and “bottom”; and other like terms indicating relative positions to a given point or element are utilized to more clearly describe some elements.', 'Commonly, these terms relate to a reference point at the surface from which drilling operations are initiated as being the top point and the total depth being the lowest point, wherein the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.', 'Various types of artificial lift equipment and methods are available, for example, electric submersible pumps (ESP).', 'As shown in the example embodiment of \nFIG.', '1\n, an ESP \n110\n typically includes a motor \n116\n, a protector \n115\n, a pump \n112\n, a pump intake \n114\n, and one or more cables \n111\n, which can include an electric power cable.', 'The motor \n116\n can be powered and controlled by a surface power supply and controller, respectively, via the cables \n111\n.', 'In some configurations, the ESP \n110\n also includes gas handling features \n113\n and/or one or more sensors \n117\n (e.g., for temperature, pressure, current leakage, vibration, etc.).', 'As shown, the well may include one or more well sensors \n120\n.', 'The pump \n112\n includes multiple centrifugal pump stages mounted in series within a housing \n230\n, as shown in \nFIG.', '2\nA\n.', 'FIG.', '2\nB\n illustrates another example embodiment of a pump section including multiple pump stages mounted in series within a housing \n230\n.', 'Each stage includes a rotating impeller \n210\n and a stationary diffuser \n220\n.', 'One or more spacers \n204\n can be disposed axially between sequential impellers \n210\n.', 'A shaft \n202\n extends through the pump \n112\n (e.g., through central hubs or bores or the impellers \n210\n and diffusers \n220\n) and is coupled to the motor \n116\n.', 'The impellers \n210\n are rotationally coupled, e.g., keyed, to the shaft \n202\n.', 'The diffusers \n220\n are coupled, e.g., rotationally fixed, to the housing \n230\n.', 'In use, the motor \n116\n rotates the shaft \n202\n, which in turn rotates the impellers \n210\n relative to and within the stationary diffusers \n220\n.', 'In use, well fluid flows into the first (lowest) stage of the pump \n112\n and passes through an impeller \n210\n, which centrifuges the fluid radially outward such that the fluid gains energy in the form of velocity.', "Upon exiting the impeller \n210\n, the fluid makes a sharp turn to enter a diffuser \n220\n, where the fluid's velocity is converted to pressure.", 'The fluid then enters the next impeller \n210\n and diffuser \n220\n stage to repeat the process.', 'As the fluid passes through the pump stages, the fluid incrementally gains pressure until the fluid has sufficient energy to travel to the well surface.', 'As shown in \nFIGS.', '2\nA-\n2\nB\n, a bearing assembly can be disposed between, e.g., at least partially radially between, the shaft \n202\n and a diffuser \n220\n and/or between, e.g., at least partially axially between, an impeller \n210\n and its associated diffuser \n220\n.', 'A portion of the diffuser \n220\n can act as a bearing housing \n260\n.', 'In the illustrated embodiment, the bearing assembly includes a bearing sleeve \n252\n disposed about the shaft \n202\n and a bushing \n254\n disposed about the bearing sleeve \n252\n and radially between the bearing sleeve \n252\n and a portion of the diffuser \n220\n.', 'One or more o-rings \n258\n can be disposed about the bushing \n254\n, for example, radially between the bushing \n254\n and the diffuser \n220\n or bearing housing \n260\n.', 'The illustrated bearing assembly also includes an anti-rotation upthrust ring \n256\n disposed about the bearing sleeve \n252\n.', 'As shown, the anti-rotation upthrust ring \n256\n can be disposed adjacent an upstream end of the bushing \n254\n.', 'The bearing sleeve \n252\n is keyed or rotationally coupled to the shaft \n202\n such that the bearing sleeve \n252\n rotates with the shaft in use \n202\n.', 'The anti-rotation upthrust ring \n256\n prevents or inhibits the bushing \n254\n from rotating such that the bushing \n254\n is stationary or rotationally fixed relative to the diffuser \n220\n.', 'The anti-rotation upthrust ring \n256\n can also help prevent or inhibit axial movement of the bushing \n254\n and/or the bushing \n254\n from dropping out of place from the bearing housing \n260\n.', 'In use, the bearing assembly can help absorb thrust and/or accommodate the rotation of the shaft relative to the diffuser.', 'The pump \n112\n can also include one or more thrust assemblies, for example, upthrust assemblies and/or downthrust assemblies, disposed axially between portions of and/or operatively connecting an impeller \n210\n and its associated diffuser \n220\n.', 'A thrust assembly can include a thrust washer and a thrust pad, which may be a portion of the impeller \n210\n or diffuser \n220\n.', 'In the configuration of \nFIG.', '2\nA\n, an upthrust washer \n270\n is disposed on, adjacent, or proximate an upper surface, or upwardly facing surface, of the impeller \n210\n.', 'In the illustrated configuration, the upthrust washer \n270\n is positioned adjacent a central hub \n214\n or portion of the impeller \n210\n having a bore through which the shaft \n202\n extends and radially between the hub \n214\n and a balance ring \n212\n of the impeller \n210\n.', 'In use, the illustrated upthrust washer \n270\n contacts the anti-rotation upthrust ring \n256\n when the pump \n112\n is operating in an upthrust condition, for example, during HPTS testing at a wide open condition, improper or over shimming at a well site, and/or operating beyond maximum operating range in the field.', 'In some configurations, the pump \n112\n also includes one or more downthrust assemblies.', 'In the configurations of \nFIGS.', '2\nA and \n2\nB\n, a downthrust washer \n280\n is disposed on or adjacent a lower, or downwardly facing surface, of the impeller \n210\n, and is disposed axially between a portion of the impeller \n210\n and a portion of the associated diffuser \n220\n.', 'Typically, the end play of the pump \n112\n is defined as the minimum free axial movement, or axial clearance, between the impeller \n210\n and associated diffuser \n220\n.', 'FIG.', '3\n illustrates the upthrust gap between the impeller \n210\n and diffuser \n220\n at various locations in the pump \n112\n.', 'A first gap (a) exists between a tip of the impeller \n210\n and the diffuser \n220\n or bearing housing \n260\n.', 'A second gap (b) exists between a tip, end, or free edge of the balance ring \n212\n of the impeller \n210\n and the diffuser \n220\n.', 'A third gap (c) exists between the upper surface adjacent the hub \n214\n of the impeller \n210\n and an upthrust pad of the diffuser \n220\n.', 'The end play is the amount of pre-lift plus the smallest of the three gaps.', 'In the configuration of \nFIG.', '2\nA\n, the upthrust washer \n270\n is located in gap (c).', 'In some cases, thrust washers, such as upthrust washer \n270\n and/or downthrust washer \n280\n, become worn and/or fail during use.', 'Upthrust wear and/or damaged or missing upthrust washers \n270\n can occur sooner when operating in unfavorable upthrust conditions, like HPTS testing in wide open conditions, improper or over shimming, operating at high flow outside ROR at a well site.', 'If the upthrust washer \n270\n is damaged or wears off, for example, in a sandy or unconventional well, there could be metal-to-metal upthrust wear (for example, between the impeller \n210\n and upthrust ring \n256\n and/or upthrust pad of the diffuser \n220\n), which can significantly increase the horsepower of the ESP.', 'In some cases, extreme heat could be generated, which could eventually lead to shaft \n202\n damage, due to, for example, lack of lubrication (due to vaporization of liquid in the area due to the heat), heat, and/or shaft \n202\n seizure (for example, due to expansion of metal components).', 'FIG.', '2\nB\n illustrates an alternative configuration in which the upthrust washer \n270\n is located in gap (b).', 'In some configurations according to the present disclosure, the upthrust washer \n270\n is instead located in gap (a), for example as shown in \nFIGS.', '4\n and \n6\n.', 'As shown, the upthrust washer \n270\n is located at, adjacent, or proximate the impeller \n210\n tip and adjacent the balance ring \n212\n.', 'In other words, the upthrust washer \n270\n is located at, adjacent, or proximate the hub \n214\n side (radial side) of the impeller \n210\n tip.', 'As shown in \nFIGS.', '2\nA and \n4\n, blades \n213\n of the impeller \n210\n can extend between a lower plate or disc \n215\n and an upper plate or disc \n217\n.', 'As shown in \nFIG.', '4\n, the upthrust washer \n270\n can be disposed on or adjacent an upward or downstream facing surface of the upper plate \n217\n.', 'In other words, the upthrust washer \n270\n can be disposed at a base of the balance ring \n212\n.', 'As shown, the upthrust washer \n270\n can be disposed radially outward of and/or adjacent a radially outer surface of the balance ring \n212\n.', 'Locating the upthrust washer \n270\n at or on the impeller \n210\n tip separates the washer \n270\n away from the shaft \n202\n, which can help prevent, inhibit, or reduce the likelihood of shaft \n202\n damage due to heat generated by upthrust rubbing, should the washer \n270\n become damaged or wear away.', 'The pump \n112\n can therefore continue to operate in upthrust conditions with a lower likelihood of a broken shaft \n202\n.', 'The upthrust washer \n270\n can be made of or include phenolic material, tungsten carbide, silicon carbide, and/or any other suitable material(s), for example, any wear resistant material and/or coating.', 'In some configurations, the balance ring tip \n212\n includes lubrication grooves \n290\n.', 'The lubrication grooves \n290\n can be machined into or cast in the balance ring \n212\n tip, edge, or end surface.', 'As shown in \nFIG.', '5\nB\n, the diffuser \n220\n, or diffuser in the form of a bearing housing \n260\n as shown in \nFIG.', '5\nA\n, can include lubrication grooves \n290\n, for example, in a leading edge shoulder \n222\n of diffuser ring \n226\n (i.e., recessed or cut into the ring \n226\n from the leading edge shoulder \n222\n) and/or an edge or end surface of the hub \n224\n.', 'The lubrication grooves \n290\n can be machined into or cast in the diffuser \n220\n or bearing housing \n260\n.', 'The lubrication grooves \n290\n (of the impeller \n210\n and/or diffuser \n220\n) can have various shapes or profiles, for example, squared, rounded, semi-rounded, V-shaped, W-shaped, and/or spiraled in a clockwise or counter-clockwise direction.', 'In the configuration of \nFIG.', '3\n, gaps (a), (b), and (c), are the same, or have equal or about equal axial lengths.', 'In contrast, in a configuration in which the upthrust washer \n270\n is disposed in gap (a), for example as shown in \nFIG.', '6\n, gap (a) is smaller than gaps (b) and (c).', 'In some such configurations, gap (b) is smaller than gap (c).', 'In use, when the pump \n112\n is operating in an upthrust condition, gap (a) closes first, before gap (b) and gap (c).', 'As gap (a) is closer to the impeller \n210\n fluid exit (for example, compared to gap (c)), the fluid flow in the vicinity of gap (a) has a higher velocity, thereby allowing for faster heat convection and faster cooling of components in that vicinity in the event of upthrust rubbing.', 'Lubrication grooves \n290\n on the impeller \n210\n and/or diffuser \n220\n allow fluid to still flow into the balance chamber \n211\n so that the bearing assembly does not become lubrication starved.', 'The improved cooling and/or lubrication can help reduce the risk of shaft \n202\n damage or failure.', 'In some configurations, an upthrust washer \n270\nb \nis disposed on, adjacent, or proximate the leading edge shoulder \n222\n of the diffuser \n220\n and/or bearing housing \n260\n, for example as shown in \nFIGS.', '7\nA-\n7\nB\n.', 'The upthrust washer \n270\nb \ncan be made of or include phenolic material, tungsten carbide, silicon carbide, and/or any other suitable material(s), for example, any wear resistant material and/or coating.', 'In the embodiments of \nFIGS.', '7\nA-\n8\n, the upthrust washer \n270\nb \nis disposed in a recessed portion of the ring \n226\n (e.g., recessed into the ring \n226\n in a downstream direction from the leading edge shoulder \n222\n).', 'As shown, the upthrust washer \n270\nb \ncan have a radial width less than a radial thickness of the ring \n226\n such that the upthrust washer \n270\nb \ndoes not cover the entire radial width of the ring \n226\n, and the upthrust washer \n270\nb \nsits flush with the leading edge shoulder \n22\n.', 'In some configurations, the pump \n112\n includes both an upthrust washer \n270\n at, adjacent, or proximate the impeller tip and an upthrust washer \n270\nb \non, adjacent, or proximate the leading edge shoulder \n222\n of the diffuser \n220\n and/or bearing housing \n260\n, for example as shown in \nFIG. \n8\n.', 'Any one or more of the upthrust washer \n270\n, upthrust washer \n270\nb\n, impeller (e.g., balance ring tip \n212\n), diffuser \n220\n/bearing housing \n260\n (e.g., leading edge shoulder \n222\n and/or hub \n214\n), and upthrust ring \n256\n can include lubrication grooves \n290\n as shown.', 'The lubrication grooves \n290\n can have various shapes or profiles, for example, squared, rounded, semi-rounded, V-shaped, W-shaped, and/or spiraled in a clockwise or counter-clockwise direction.', 'In some configurations according to the present disclosure, upthrust of the pump \n112\n can be handled by an upthrust bearing \n300\n located in the pump \n112\n.', 'The upthrust bearing \n300\n can be made of or include ceramic.', 'In use, because the impellers \n210\n are fixed to or locked onto the shaft \n202\n, a sub-assembly of the shaft \n202\n and stack of impellers \n210\n move up and/or down as one body.', 'Therefore, upthrust could be handled and/or restricted at a single location with a single upthrust bearing \n300\n.', 'FIG.', '9\n illustrates a configuration in which the upthrust bearing \n300\n is located at least partially at or on a top of the pump \n112\n, for example, at least partially at or in a head section \n118\n of the pump \n112\n.', 'However, the upthrust bearing \n300\n could be located elsewhere within the pump \n112\n.', 'The upthrust bearing \n300\n can include a bearing sleeve \n302\n disposed about the shaft \n202\n and a bushing \n304\n disposed about the bearing sleeve \n302\n and radially at least partially between the bearing sleeve \n302\n and the head section \n118\n.', 'One or more o-rings \n306\n can optionally be disposed about the bushing \n304\n, for example, radially between the bushing \n304\n and the head section \n118\n, to help secure or mount the bushing \n304\n in the head section \n118\n.', 'Additionally or alternatively, the bushing \n304\n can be secured in the head section \n118\n via an interference fit.', 'An axial retention ring \n308\n can be disposed at least partially radially between the bushing \n304\n and the head section \n118\n.', 'In the illustrated configurations, the axial retention ring \n308\n is at least partially disposed in a recess or groove \n314\n (shown in \nFIG.', '11\nB\n) in an outer surface of the bushing \n304\n.', 'The axial retention ring \n308\n helps axially locate the bushing \n304\n and/or helps prevent or inhibit the bushing \n304\n from moving axially relative to the head \n118\n.', 'A compliance can be introduced between the upthrust bearing \n300\n (or components thereof) and the head section \n118\n to prevent or inhibit impact loading onto the bearing system.', 'The bearing sleeve \n302\n can be keyed or rotationally coupled to the shaft \n202\n such that the bearing sleeve \n302\n rotates with the shaft \n202\n in use.', 'For example, in the illustrated configuration, the bearing sleeve \n302\n is keyed to the shaft \n202\n via an elongated key \n310\n extending axially along the bearing sleeve \n302\n and a portion of the shaft \n202\n.', 'In some configurations, a spacer \n350\n is disposed about the shaft \n202\n above or downstream of the bearing sleeve \n302\n and bushing \n304\n.', 'The spacer \n350\n can be secured to or relative to the shaft \n202\n via a retaining ring \n352\n disposed above or downstream of the spacer \n350\n and at least partially disposed in a groove in the outer surface of the shaft \n202\n.', 'The spacer \n350\n can help located the bearing sleeve \n302\n on the shaft \n202\n.', 'The bushing \n304\n can have a generally T-shaped longitudinal cross-sectional shape, for example as shown in \nFIG.', '10\n and \nFIGS.', '11\nA-\n11\nB\n.', 'The head section \n118\n can have an internal profile designed to accommodate the T-shaped bushing \n304\n.', 'As shown in \nFIGS.', '11\nA-\n11\nB\n, an outer surface of a stem or base portion \n303\n of the bushing \n304\n can include one or more circumferential grooves \n312\n designed to house the o-rings \n306\n.', 'The outer surface of the stem or base portion \n303\n can include a circumferential groove \n314\n designed to house the axial retention ring \n308\n.', 'The stem or base portion \n303\n can include a pin hole \n316\n extending therethrough to prevent or inhibit trapped pressure.', 'An inner journal bearing surface \n320\n of the base portion \n303\n surrounding the bore of the bushing \n304\n can act as a radial bearing surface.', 'The bushing \n304\n can be made of or include a hard allow or ceramic material.', 'A crossbar portion of the bushing \n304\n forms a thrust pad \n305\n.', 'The thrust pad \n304\n, for example, an upstream end or surface (disposed opposite or away from the base portion \n303\n) of the thrust pad \n304\n, can include one or more grooves \n318\n.', 'In the illustrated configuration, the grooves \n318\n extend radially outwardly from a central bore or journal bearing surface \n320\n of the bushing \n304\n to a radial outer edge of the thrust pad \n305\n.', 'The grooves \n318\n can allow for the flow of fluid, for example, for lubrication, in use.', 'The bushing \n304\n can include one or more anti-rotation features that act to prevent or inhibit the bushing \n304\n from rotating in use.', 'The anti-rotation feature(s) can rotationally fix the bushing \n304\n to, for example, the head section \n118\n.', 'The anti-rotation features can be or include one or more notches \n322\n, for example as shown in \nFIGS.', '11\nA-\n11\nB and \n13\nA-\n13\nB\n.', 'The notches \n322\n can receive a corresponding feature, such as a protrusion, for example, on the head section \n118\n, to rotationally fix the bushing \n304\n.', 'In the embodiment of \nFIGS.', '11\nA-\n11\nB\n, the notches \n322\n disposed at the end, e.g., the top, downstream end, or end opposite the thrust pad \n304\n, of the bushing \n304\n.', 'In the embodiment of \nFIGS.', '13\nA-\n13\nB\n, the notches \n322\n are disposed in a surface, e.g., a downstream surface or surface adjacent the base portion \n303\n, of the thrust pad \n305\n.', 'In some configurations, for example as shown in \nFIGS.', '14\nA-\n14\nB\n, the anti-rotation feature can be or include a keyway \n324\n extending along the base portion \n303\n.', 'In the illustrated configuration, the keyway \n324\n is recessed into the outer surface of the base portion \n303\n and extends axially along at least a portion of the base portion \n303\n.', 'The keyway \n324\n can receive a corresponding key, such as a protrusion, for example, on the head section \n118\n.', 'An upthrust bearing runner \n321\n, also shown in \nFIG.', '15\n, is disposed about the shaft \n202\n below or upstream of the bushing \n304\n.', 'The runner \n321\n can be made of or include one or more hard alloys and/or a ceramic material.', 'The runner \n321\n can be rotationally fixed to the shaft \n202\n.', 'In the illustrated configuration, an inner surface, or surface surrounding the bore, of the runner \n321\n includes a notch, keyway, groove, or recess \n326\n that receives the key \n310\n.', 'In use, when the sub-assembly of the shaft \n202\n and impellers \n210\n operate in upthrust conditions, the runner \n321\n is shifted upward toward the thrust pad \n305\n and may contact the thrust pad \n305\n.', 'The upstream surface of the thrust pad \n305\n therefore can accommodate or handle upthrust.', 'In some configurations, for example as shown in \nFIG. \n12\n, the thrust pad \n305\n is preloaded into contact or engagement with the runner \n321\n.', 'In the illustrated configuration, the thrust pad \n305\n is preloaded via a spring \n340\n disposed axially between the downstream surface (or surface opposite the thrust surface and adjacent the base portion \n303\n) of the thrust pad \n305\n and the head section \n118\n.', 'The runner \n321\n is axially located along the shaft \n202\n and/or relative to the bushing \n304\n to achieve a required or desired setting and upthrust gap.', 'The runner \n321\n can be appropriately axially located using a spacer \n330\n.', 'The spacer \n330\n is disposed about the shaft \n202\n upstream of the runner \n321\n.', 'The runner \n321\n is therefore disposed axially between the bushing \n304\n and the spacer \n330\n.', 'The spacer \n330\n can be secured in place on the shaft \n202\n with a retaining ring \n332\n.', 'In the illustrated configuration, the retaining ring \n332\n is disposed below or upstream of the spacer \n330\n and/or adjacent a bottom or upstream surface of the spacer \n330\n.', 'The retaining ring \n332\n can be at least partially disposed in a groove formed in an outer surface of the shaft \n202\n.', 'In some configurations, the pump \n112\n includes one or more downthrust assemblies, each of which can include a downthrust washer \n280\n.', 'The downthrust washer \n280\n can be disposed on an impeller \n210\n downthrust pad or in an impeller \n210\n groove.', 'In the configurations of \nFIGS.', '2\nA and \n2\nB\n, the downthrust washer \n280\n is disposed in a recess or downthrust groove \n216\n in a downwardly or upstream facing surface of the impeller \n210\n.', 'The recess or groove \n216\n can be disposed in a projection extending from a downward facing or bottom surface of the lower plate \n215\n of the impeller \n210\n.', 'In use, the downthrust washer \n280\n contacts the adjacent upstream diffuser \n220\n when the pump \n112\n is operating in downthrust conditions, for example, at or near the minimum operating range or near the shut in point in the field.', 'As described herein, in some cases, thrust washers, such as upthrust washer \n270\n and/or downthrust washer \n280\n, become worn and/or fail during use.', 'Downthrust wear and/or damaged or missing downthrust washers \n280\n can occur sooner when operating in unfavorable downthrust conditions.', 'If the downthrust washer \n280\n is damaged or wears off, for example, in a sandy or unconventional well, there could be metal-to-metal downthrust wear (for example, on the thrust pad), which can significantly increase the horsepower of the ESP.', 'In some cases, extreme heat could be generated, which could eventually lead to shaft \n202\n damage, due to, for example, lack of lubrication (due to vaporization of liquid in the area due to the heat), heat, and/or shaft \n202\n seizure (for example, due to expansion of metal components).', 'In some configurations according to the present disclosure, the downthrust washer \n280\n is thicker than traditional washers.', 'The thicker downthrust washer \n280\n can be disposed on the impeller \n210\n.', 'The thicker downthrust washer \n280\n can advantageously share the load among the plurality of stages in a compression pump.', 'In use, when the impeller \n210\n operates in downthrust conditions, each washer \n280\n contacts the adjacent upstream diffuser \n220\n.', 'This allows the compression pump to act like a floater pump.', 'The downthrust washer \n280\n of the current disclosure can be made of or include an elastic material, phenolic CE, CFE material, and/or another suitable material.', 'The material(s) can be selected such that the stiffness of the downthrust washer \n280\n is not too low, but can be sufficiently deformed to share the axial thrust load of the pump in use.', 'Whereas traditional downthrust washers typically have thicknesses in the range of about 0.015 in.', 'to about 0.062 in., the thickness of downthrust washers \n280\n according to the present disclosure can be greater than about 0.10 in, for example, about 0.125 in.', 'Traditionally, such an increase in thickness would have been considered undesirable, as an increase in the downthrust washer thickness in a traditional pump would have increased the pump length and therefore the cost.', 'However, in pumps \n112\n according to the present disclosure including the thicker downthrust washer \n280\n, the thrust load is advantageously shared among the stages throughout the pump \n112\n.', 'The benefits of the load distribution and sharing can outweigh potential increases in cost.\n \nFIG.', '16\nA\n shows a traditional downthrust washer \n280\n compared to \nFIG.', '16\nB\n, which shows a thicker downthrust washer \n280\n according to the present disclosure.', 'As shown in \nFIG.', '16\nA\n, the traditional downthrust washer may be flush with the surface of the impeller \n210\n defining the groove \n216\n.', 'In contrast, the thicker downthrust washer \n280\n of the present disclosure may extend past or beyond, e.g., upstream of, that surface or extend out of, e.g., upstream of, the groove \n216\n, as shown in \nFIG.', '16\nB\n.', 'FIGS.', '17\n-\n19\n show the thicker downthrust washer \n280\n disposed in example configurations of the pump \n112\n.', 'During field installation and operation, the pump \n112\n is shimmed to or by a certain amount.', 'In the illustrated configurations, the pump \n112\n can be shimmed about 0.122 in.', 'In use, when the pump \n112\n is running at minimum OR, or at any flow rate that results in a downthrust condition, deflection of the shaft \n202\n causes the pre-lift gap PL (shown in \nFIGS.', '17\n-\n19\n) to close and the downthrust washer \n280\n to contact the adjacent upstream diffuser \n220\n.', 'The smallest pre-lift gap PL in the pump \n112\n is unknown.', 'For example, the smallest pre-lift gap PL could be at the top stage N or any subsequent stage from N-\n1\n to the bottom stage N-M. As an example, if the top stage N has the smallest pre-lift gap PL, the downthrust washer \n280\n of the top stage N will start wearing away first in use.', 'As washer \n280\n N wears down, the N-\n1\n pre-lift gap closes and the washer \n280\n of stage N-\n1\n contacts the adjacent diffuser \n220\n, followed by stage and washer N-\n2\n, and so on.', 'At the beginning, the top washer \n280\n N is subjected to the maximum axial thrust load of the entire pump \n112\n.', 'When the N-\n1\n, N-\n2\n, and subsequent washers \n280\n come into contact with their adjacent diffusers \n220\n, the axial load becomes shared among the washers \n280\n.', 'The pump \n112\n can therefore then act like a floater pump, and the wear rate of individual washers \n280\n slows significantly.', 'FIGS.', '20\nA and \n20\nB\n show a mini sand loop wear rate comparison between a standard 0.062″ washer and a thicker downthrust washer \n280\n, respectively.', 'As shown, the thicker washer \n280\n delays metal-to-metal wear due to the increased washer \n280\n thickness and its cushioning effect.', 'Language of degree used herein, such as the terms “approximately,” “about,” “generally,” and “substantially” as used herein represent a value, amount, or characteristic close to the stated value, amount, or characteristic that still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” “generally,” and “substantially” may refer to an amount that is within less than 10% of, within less than 5% of, within less than 1% of, within less than 0.1% of, and/or within less than 0.01% of the stated amount.', 'As another example, in certain embodiments, the terms “generally parallel” and “substantially parallel” or “generally perpendicular” and “substantially perpendicular” refer to a value, amount, or characteristic that departs from exactly parallel or perpendicular, respectively, by less than or equal to 15 degrees, 10 degrees, 5 degrees, 3 degrees, 1 degree, or 0.1 degree.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'It is also contemplated that various combinations or sub-combinations of the specific features and aspects of the embodiments described may be made and still fall within the scope of the disclosure.', 'It should be understood that various features and aspects of the disclosed embodiments can be combined with, or substituted for, one another in order to form varying modes of the embodiments of the disclosure.', 'Thus, it is intended that the scope of the disclosure herein should not be limited by the particular embodiments described above.']

['1.', 'An electric submersible pump (ESP) comprising a plurality of stages, at least one stage comprising:\na rotating impeller rotationally fixed to a shaft of the ESP, the impeller comprising a balance ring;\na stationary diffuser rotationally fixed to a housing of the ESP;\nan upthrust washer disposed axially between a portion of the impeller and a portion of the diffuser, the upthrust washer disposed radially outside of the balance ring; and\na bearing assembly disposed radially between the shaft and the diffuser, wherein an axial gap between the portion of the impeller and the portion of the diffuser is smaller than an axial gap between the bearing assembly and an upwardly facing surface of the impeller disposed radially between a central hub of the impeller and the balance ring of the impeller.', '2.', 'The ESP of claim 1, further comprising a second upthrust washer disposed adjacent a leading edge shoulder of the diffuser.', '3.', 'The ESP of claim 2, wherein the second upthrust washer comprises one or more lubrication grooves.', '4.', 'The ESP of claim 1, wherein the balance ring of the impeller comprises one or more lubrication grooves.', '5.', 'The ESP of claim 1, wherein the diffuser comprises one or more lubrication grooves.', '6.', 'The ESP of claim 5, wherein a central hub of the diffuser comprises one or more lubrication grooves in a leading or upstream edge of the central hub.', '7.', 'The ESP of claim 5, wherein a ring surrounding a central hub of the diffuser comprises one or more lubrication grooves in a leading edge shoulder of the ring.', '8.', 'The ESP of claim 1, wherein the upthrust washer comprises phenolic material, tungsten carbide, or silicon carbide.', '9.', 'The ESP of claim 1, wherein an axial gap between the portion of the impeller and the portion of the diffuser is smaller than an axial gap between a downstream edge of the balance ring of the impeller and the diffuser.', '10.', 'The ESP of claim 1, wherein an axial gap between the portion of the impeller and the portion of the diffuser is smaller than an axial gap between the diffuser and an upwardly facing surface of the impeller disposed radially between a central hub of the impeller and the balance ring of the impeller.', '11.', 'An electric submersible pump (ESP) comprising:\na plurality of centrifugal stages, each stage comprising a rotating impeller coupled to a rotating shaft and a stationary diffuser disposed about the rotating impeller; and\nan upthrust bearing assembly disposed radially between the shaft and the diffuser, wherein an axial gap between a portion of the impeller and a portion of the diffuser is smaller than an axial gap between the upthrust bearing assembly and an upwardly facing surface of the impeller disposed radially between a central hub of the impeller and the balance ring of the impeller and comprising: a bearing sleeve disposed about the shaft and rotationally keyed to the shaft; a stationary bushing disposed about the bearing sleeve, the bushing having a generally T-shaped longitudinal cross-section shape and a bore extending longitudinally therethrough, the bushing having a base portion and a thrust pad at an upstream end of the base portion; and an upthrust bearing runner disposed about the shaft upstream of the bushing, the upthrust bearing runner configured to move toward an upthrust surface of the thrust pad of the bushing when the ESP operates in an upthrust condition.', '12.', 'The ESP of claim 11, wherein the upthrust bearing assembly is disposed proximate a top or downstream end of the plurality of centrifugal stages.', '13.', 'The ESP of claim 11, wherein the upthrust bearing assembly is disposed in a pump head section.', '14.', 'The ESP of claim 11, wherein the upthrust surface comprises one or more grooves configured to allow fluid flow.', '15.', 'The ESP of claim 11, the bushing comprising an anti-rotation feature configured to rotationally fix the bushing.', '16.', 'The ESP of claim 15, wherein the anti-rotation feature comprises notches in a downstream end of the base portion and/or a downstream surface of the thrust pad.\n\n\n\n\n\n\n17.', 'The ESP of claim 15, wherein the anti-rotation feature comprises a groove in an outer surface of the base portion extending axially along at least a portion of a length of the base portion.']

['FIG.', '1 shows a schematic of an electric submersible pump (ESP) system.; FIG.', '2A shows a cross-section of a portion of a pump section of the ESP system of FIG.', '1.; FIG.', '2B shows a cross-section of a portion of a pump section of another embodiment of an ESP pump.; FIG.', '3 shows the cross-section of FIG.', '2A showing gaps between various components.; FIG.', '4 shows a perspective view of an example embodiment of an impeller including an upthrust washer.; FIG.', '5A shows a cross-section of an example embodiment of a bearing housing including lubrication grooves.', '; FIG.', '5B shows a perspective view of an example embodiment of a diffuser including lubrication grooves.; FIG.', '6 shows a cross-section of a portion of an example embodiment of a pump section of an ESP including the impeller of FIG.', '4, the bearing housing of FIG.', '5A, and the diffuser of FIG.', '5B.; FIG.', '7A shows a cross-section of an example embodiment of a bearing housing including an upthrust washer and lubrication grooves.', '; FIG.', '7B shows a perspective of an example embodiment of a diffuser including an upthrust washer and lubrication grooves.; FIG.', '8 shows a cross-section of a portion of an example embodiment of a pump section of an ESP including the impeller of FIG.', '4, the bearing housing of FIG.', '7A, and the diffuser of FIG.', '7B.; FIG.', '9 shows a cross-section of a portion of a pump section of an ESP including an example embodiment of an upthrust bearing.; FIG.', '10 shows a close-up cross-section of a portion of FIG.', '9.; FIGS.', '11A-11B show views of the upthrust bearing of FIG.', '10.; FIG. 12 shows a cross-section of a pump section of an ESP including another example embodiment of an upthrust bearing.; FIGS.', '13A-13B show views of the upthrust bearing of FIG.', '12.; FIGS.', '14A-14B show views of another example embodiment of an upthrust bearing.; FIG.', '15 shows a perspective view of an example embodiment of an upthrust runner.; FIG.', '16A shows an impeller including a traditional downthrust washer.; FIG.', '16B shows an impeller including an example embodiment of a thicker downthrust washer according to the present disclosure.', '; FIG.', '17 shows a cross-section of an example embodiment of a pump section of an ESP including the thicker downthrust washer of FIG.', '16B.; FIG.', '18 shows a partial cross-section of another example embodiment of a pump section of an ESP including the thicker downthrust washer of FIG.', '16B.; FIG.', '19 shows a partial cross-section of a pump section of an ESP including the thicker downthrust washer of FIG.', '16B.; FIG.', '20A shows an impeller that included the traditional downthrust washer of FIG.', '16A after a mini sand loop test.', '; FIG.', '20B shows an impeller that included the thicker downthrust washer of FIG.', '16B after a mini sand loop test.', '; FIG.', '16A shows a traditional downthrust washer 280 compared to FIG.', '16B, which shows a thicker downthrust washer 280 according to the present disclosure.', 'As shown in FIG.', '16A, the traditional downthrust washer may be flush with the surface of the impeller 210 defining the groove 216.', 'In contrast, the thicker downthrust washer 280 of the present disclosure may extend past or beyond, e.g., upstream of, that surface or extend out of, e.g., upstream of, the groove 216, as shown in FIG.', '16B. FIGS.', '17-19 show the thicker downthrust washer 280 disposed in example configurations of the pump 112.']

US11941128

Indirect diagnosis of multiple fluid mixer unit performance

Mar 28, 2018

Simon Ivar Andersen, Sharath Chandra Mahavadi, Salim Taoutaou, Alexander Nebesnyy, Jonathan Wun Shiung Chong

SCHLUMBERGER TECHNOLOGY CORPORATION

Cob, “Improved Analysis Techniques Quantitatively Determine Critical Organic Additives Simultaneously in Cement Blends”, Petroleum Society of CIM, Paper No. 86-37-48, 1986, pp. 95-100.

5590958; January 7, 1997; Dearing, Sr. et al.; 5653533; August 5, 1997; Green; 7677786; March 16, 2010; Uno; 20100246312; September 30, 2010; Welker; 20110127034; June 2, 2011; Vidick et al.; 20150114837; April 30, 2015; Mahavadi et al.; 20170045476; February 16, 2017; Mahavadi

3051057; August 2016; EP; 2018081506; May 2018; WO

['A liquid additive mixing apparatus is provided that has a plurality of chambers containing additives, as well as a system for mixing the additives.', 'One or more additives are mixed with water to form a mixing fluid.', 'The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit.', 'A cementing operation is executed during which the mixing fluid from the first tank is mixed with a cement to form a slurry.', 'A capillary electrophoresis (CE) instrument is employed to monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application is a Nonprovisional application that is the National Stage Entry of International Application No. PCT/US2018/024920, filed on Mar. 28, 2018, which claims the benefit of U.S. Provisional Application No. 62/477,818, filed on Mar. 28, 2017, entitled “Indirect Diagnosis of Multiple Fluid Mixer Unit Performance.”', 'BACKGROUND', 'In the oilfield industry, different fluids may be injected in subterranean zones.', 'For example, drilling a well requires the use of a mud.', 'Well cementing or plugging may require pumping chemical washes, spacer fluids and settable compositions (e.g., cement slurry, resin, and geopolymer) to ensure proper hydraulic isolation of the annulus between the casing and the formation, or to repair or plug the well.', 'Once a well is able to produce, completion fluids may be required.', 'Production may be improved during acidizing or fracturing operations.', 'Sand control may also be achieved by injecting optimized fluids containing sand.', 'These examples are illustrative and do not limit the types of fluids that may be pumped into subterranean wells.', 'For each of the examples listed above, fluid property optimization takes place based on well configuration (temperature, pressure, deviation, etc.) and client requirements.', 'For example, in a cement slurry, a retarder concentration may be adjusted to allow fluid placement in the annulus, yet minimize waiting on cement time.', 'When a cement slurry is placed across a permeable formation under pressure, a filtration process occurs.', 'The aqueous phase of the slurry may escape into the formation, leaving the cement particles behind.', 'Such a process is commonly known as fluid loss.', 'If fluid loss is not controlled, several serious consequences may result that can lead to cement-job failure.', 'The concentration of the fluid loss additive is dictated by not only the well configuration (temperature, slurry density, slurry volume fraction, etc.), but also the fluid-loss rate that is tolerable given the nature of the formations with which the cement slurry comes into contact (e.g., porosity and permeability).', "Other additives include gelling agents to control the fluid's rheological properties, retarders and accelerators to control the setting properties of cement, anti-settling agents, extenders, etc.", 'Prior to a cementing operation, these fluids are optimized in a laboratory following API recommended practices or standards and with all chemicals (including water) used for the job.', 'At a laboratory scale, it is easy to prepare accurately the mixed fluid by weighing each liquid additive and blending them with water.', 'Good quality assurance is desirable to achieve proper placement, avoid premature setting or misplacement of the cement.', 'Such techniques include Capillary Electrophoresis (CE) and other techniques, as will be appreciated by those skilled in the art.', 'SUMMARY\n \nThe present disclosure is directed to methods and processes for real-time performance monitoring of additive mixing equipment employed in well-service operations.', 'The blend composition is analyzed in real time at constant mixing settings.', 'This technique provides auto fault detection and, suggests or predicts specific subunit failures.', 'Little to no human intervention is required.', 'In an aspect, methods are disclosed for performing a cementing operation at a wellsite.', 'A liquid additive mixing apparatus is provided that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives.', 'At least one additive is mixed with water to form a mixing fluid.', 'The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit.', 'A cementing operation is executed during which the mixing fluid from the first tank is mixed with the cement to form a slurry.', 'A capillary electrophoresis (CE) instrument is used to monitor the at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.', 'If deviations are detected, corrective action is taken to return the at least one additive parameter to the predetermined tolerance.', 'In a further aspect, methods are disclosed for monitoring at least one parameter pertaining to a cementing operation.', 'A liquid additive mixing apparatus is provided that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives.', 'The at least one additive is mixed with water to form a mixing fluid.', 'The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit.', 'A cementing operation is executed during which the mixing fluid from the first tank is mixed with the cement to form a slurry.', 'As the A capillary electrophoresis (CE) instrument is used to monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.', 'In yet a further aspect, systems for performing a cementing operation are disclosed.', 'The system comprises a liquid additive system that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives and forming a mixing fluid.', 'The system further comprises first and second tanks that are fluidly connected to a cement mixing unit, and a capillary electrophoresis (CE) instrument.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a schematic diagram of the liquid additive mixing system of the disclosure.\n \nFIG.', '2\n is a capillary electrophoresis trace showing the analysis of three additives.', 'The figure also includes a calibration plot showing that the concentration determination is a linear function.\n \nFIG.', '3\n is a flowchart that illustrates the sequence of events that takes place during the disclosed cementing operations.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of the present disclosure.', 'However, it may be understood by those skilled in the art that the methods of the present disclosure may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', "At the outset, it should be noted that in the development of any such actual embodiment, numerous implementation—specific decisions are made to achieve the developer's specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort might be complex and time consuming but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'In addition, the composition used/disclosed herein can also comprise some components other than those cited.', 'In the summary of the disclosure and this detailed description, each numerical value should be read once as modified by the term “about” (unless already expressly so modified), and then read again as not so modified unless otherwise indicated in context.', 'The term about should be understood as any amount or range within 10% of the recited amount or range (for example, a range from about 1 to about 10 encompasses a range from 0.9 to 11).', 'Also, in the summary and this detailed description, it should be understood that a concentration range listed or described as being useful, suitable, or the like, is intended that any concentration within the range, including the end points, is to be considered as having been stated.', 'For example, “a range of from 1 to 10” is to be read as indicating each possible number along the continuum between about 1 and about 10.', 'Furthermore, one or more of the data points in the present examples may be combined together, or may be combined with one of the data points in the specification to create a range, and thus include each possible value or number within this range.', 'Thus, even if specific data points within the range, or even no data points within the range, are explicitly identified or refer to a few specific, it is to be understood that inventors appreciate and understand that any data points within the range are to be considered to have been specified, and that inventors possessed knowledge of the entire range and the points within the range.', 'The present disclosure is directed to using the previously discussed capillary electrophoresis (CE) methodology for in-situ and quasi real-time analysis of a fluid while it is being pumped into subterranean zones.', 'Embodiments of the present disclosure are directed to uses of CE techniques to monitor the cementing process.', 'CE is highly sensitive and easy to operate.', 'A CE unit can be miniaturized and accommodated into a well site laboratory or onto field equipment.', 'CE has major advantages which are not limited to the following: 1) one single technique for the analysis of different types of additives; 2) potentially one single method can be used to analyze all types of ions; 3) use of specific components in individual additives to monitor concentration; 4) minimal to no sample preparation.', 'Samples can be injected straight without pre-treatment; 5) easy to operate; 6) the proposed technology can be deployed to field to perform onsite analyses.', 'A liquid additive mixing apparatus is provided that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives.', 'The additives are mixed with water to form a mixing fluid.', 'The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit.', 'A cementing operation is executed during which the mixing fluid from the first tank is mixed with the cement to form a slurry.', 'A capillary electrophoresis (CE) instrument is used to monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.', 'If deviations are detected, corrective action is taken to return the at least one additive parameter to the predetermined tolerance.', 'CE units may be positioned at various locations.', 'This procedure may be performed continuously.', 'Mixing fluid may be prepared continuously during mixing using the liquid additive mixing apparatus, and the entire cementing operation may be continuous.', 'Or, the mixing fluid preparation may be performed in separate batches.', 'For example, as mixing fluid from the first tank is being used to mix the cement slurry, newly prepared mixing fluid may be added to a second tank that is fluidly connected to the cement mixing unit.', 'When the mixing fluid in the first tank is exhausted, mixing fluid from the second tank is then pumped to the cement mixing unit.', 'While the mixing fluid from the second tank is being used to mix the cement slurry, newly prepared mixing fluid may be added to the first tank.', 'This alternating procedure may proceed until the cementing operation is complete.', 'In an embodiment, the additives may be injected automatically in a water stream that is then used promptly to prepare the cement slurry or another type of fluid.', 'The cement slurries may be employed in either primary or remedial cementing operations.', 'Other types of fluids may be prepared by this system include chemical washes, spacer fluids, gravel packing fluids, acidizing fluids, fracturing fluids and pills.', 'Based on the significance of each additive on the well fluid properties, it may be decided to determine the concentration of all additives or only one or a limited number of the additives present in the fluid, and the concentrations can be adjusted as needed to reach the desired target concentration(s).', 'Though CE offers simple measurements or technique to analyze different chemistries of cement additives, some time may be required for the operator to determine the quality of the individual additives, final mix-fluid and slurry quality.', 'Additives which can be analyzed by the CE technique may contain at least one component soluble in the solvent of interest.', 'This automated QA/QC of additives can be used in various fluids, which are not limited to drilling fluids, spacer, settable composition (including cement and resins), completion fluid, acidification fluids, fracturing fluid, sand control fluids, or any other fluids which needs to be pumped in subterranean zones.', 'They can act as anti-foamer, defoamer, dispersant, accelerator, retarder, fluid loss additives, gas migration additives, corrosion inhibitors, acids, gelling agent, cross-linkers, breakers, surfactants, ions, etc.', 'Other additives not listed here but that are within the understanding of one of ordinary skill in the art are considered part of this disclosure.', 'FIG.', '1\n is a non-limiting schematic illustration of a slurry mixing system \n10\n including a water line \n12\n, a first additive chamber \n14\n, a second additive chamber \n16\n, and a third additive chamber \n18\n.', 'When the water and the additives are mixed together the result is a mixing fluid or slurry \n20\n.', 'Along the path at a convenient location, a Capillary Electrophoresis (CE) unit \n22\n is positioned.', 'The CE unit is configured to apply CE techniques to analyze characteristics of the mix \n20\n.', 'The CE unit can be configured to determine the presence and quantity of the various additives being introduced to the mix \n20\n from the tanks \n14\n, \n16\n and \n18\n.', 'The CE unit \n22\n may also monitor the quality of water in the line \n12\n by determining different ions present in water, which could ultimately determine the performance of different additives from the additive tanks \n14\n, \n16\n and \n18\n.', 'The mixing fluid may be then transferred to Tank \n1\n \n23\n or Tank \n2\n \n24\n.', 'CE units may be positioned inside Tank \n1\n and Tank \n2\n.', 'Both Tank \n1\n and Tank \n2\n are fluidly connected to a cement mixing unit \n25\n.', 'Another CE unit may be installed in the line between Tank \n1\n and Tank \n2\n and the cement mixing unit.', 'FIG.', '1\n also shows a graph \n26\n of the detected presence of the additives over time.', 'There are three lines representing additives A, B, and C.', 'In this instance, the line representing additive B begins a sharp decline at which point the line slopes downward suggesting a problem with the second tank \n16\n providing additive B to the mix \n20\n.\n \nFIG.', '2\n shows a typical CE analysis trace of a blend of additives.', 'In this instance the data present in \nFIG.', '2\n were obtained with the same CE protocol.', 'It highlights that different cement additives (single-component or multi-components) can be detected very accurately.', 'Furthermore, for each of them, retention time is different.', 'It is therefore possible to determine the concentration of each additive in the mix-fluid prepared on the rig.\n \nFIG.', '2\n also presents the calibration plot for one common additive.', 'This not only indicates that the concentration can be monitored but also that deviations outside the “delivery” tolerance will be effectively indicated by examination of the blend composition when all set points are constant.', 'The embodiments disclosed herein highlight the advantages and applicability of analytical techniques such as CE for analysis of different types of additives for key components.', 'By selecting appropriate constituents this is the first disclosed method that can monitor a cementing operation by concentrating solely on the composition of the species present in the mix and using one single method.\n \nFIG.', '3\n is a flow chart showing methods according to the present disclosure.', 'A method \n30\n for monitoring, diagnosing, and correcting a parameter in a cementing operation is shown.', 'First the cementing operation begins at \n32\n.', 'During the cementing operation, one or more parameters is monitored at \n33\n using the Capillary Electrophoresis (CE) technique.', 'The monitoring can be performed using another equivalent technique within the scope of this disclosure.', 'The parameters being monitored may be any number of additives or components of the cement or any other material added to the cement during the cementing operation added to the cement before the operation begins.', 'The method also includes determining periodically or continuously at \n34\n whether or not one or more parameters are outside the range of tolerance.', 'Once a parameter falls outside the tolerance range, the method continues at \n36\n by taking corrective action.', 'If a pump failure occurs, the correcting operation may comprise stopping the operation, repairing or replacing the pump, and resuming the operation.', 'Or, if for example the pump failure occurs in the first tank, mixing fluid can be drawn from the second tank and the operation may be continued while repairing or replacing the pump in the first tank.', 'The corrective operation may comprise changing from the first tank to the second tank, or vice versa.', 'The corrective action may comprise adjusting a pump rate at which the mixing fluid is mixed with the cement.', 'The nature of the corrective action depends upon the cementing operation and the character of the additive.', 'The method continues by bringing Tank \n2\n online at \n38\n.', 'In some embodiments, this is done by ceasing use of Tank \n1\n and instead using Tank \n2\n which includes the corrected materials.', 'Tank \n2\n then becomes the source of the material or additive as the situation demands.', 'At \n40\n, Tank \n1\n becomes Tank \n2\n and can be emptied, altered, or otherwise addressed so this tank is now the standby tank.', 'If another deviation from tolerance is detected at \n34\n, the process can repeat and what was first Tank \n1\n is now Tank \n2\n for a second round of remedial action.', 'The method can continue until the process is complete as checked at \n42\n.', 'If complete, the process ends at \n44\n.', 'It is envisioned that more than two tanks may be present in the mixing system.', 'Embodiments of the present disclosure can be ported directly onto a cement pumping unit or on a rig where pumping units are available for cement operation.', 'Automatic detection, analysis and mitigation of the problems are based on an easy-human interface.', 'One advantage of this approach is that it uses the analytical signal to further perform diagnostics on the mixing and pumping rig while performing the cementing job.', 'The deviation of the measured signal from the desired value for a given pump unit/tank can be used to regulate the dosage while the job is performed.', 'However, the recorded deviation also indicates that this unit will need maintenance.', 'Other pumps with constant dosage throughout the job may require minimal maintenance after the job.', 'Embodiments of the present disclosure may also build on these techniques by using the individual signals to monitor the performance of the individual parts of the mixer system.', 'Repeated signal deviations may indicate that hardware is worn or calibration is off.', 'This will reduce maintenance cost by reducing the need for unnecessary work-over on units between cementing jobs.', 'Embodiments of the present disclosure are directed to quality control of cement additives, mix-fluid and cement slurries.', 'The output from the compositional analysis of the mix and the individual additives is used to monitor the performance of individual mechanical parts of the mixer systems such as pumps, controls etc.', 'Deviation from set point can indicate if parts need to be replaced or recalibrated.', 'Embodiments of the present disclosure are directed to an automated quality control system providing fault detection and remedial action by sampling the mix fluid, and analyze the additive and/or cement slurry concentration through a CE laboratory device or any other portable analytical device and using the information for diagnostics on the individual parts of the mixing process used.\n \nPreviously disclosed CE methods are aimed at both additive mix quality control and pump control.', 'Embodiments of the present disclosure are directed to applying the CE information to observe set-point deviations caused by mechanical or sensor failure leading to changes in flow from individual tanks to the mixing unit.', 'It applies all the previous points of initiating the CE and optimization and calibration procedures mentioned.', 'Embodiments of the present disclosure are directed to methods for using an automated diagnostic tool on the cementing additive blending unit based on the use of analytical data obtained from while monitoring the blend composition.', 'This can significantly reduce the need and cost of off-site maintenance and workover and allows for use of back-up dispensing tank units if problem occur during a job.', 'The present methods based on CE may ideally be performed without the use of tracers.', 'CE detects signal deviations derived from the additives themselves.', 'However, if an additive does not contain a substance detectable by CE, a UV-vis absorbing tracer may be added.', 'During maintenance work over the operation and performance (calibration etc.) of pumps and other crucial part of the mixer unit can also be monitored by using tracer mixtures added to the individual tanks and pumped through the system to monitor.', 'Deviation outside given tolerances indicates which parts should be recalibrated, renovated or replaced.', 'Based on the significance of each additive on the well fluid properties, the operator may choose to determine the concentrations of all additives or only one or a limited number of the additives present in the fluid, and the concentrations can be adjusted as needed to reach the desired target concentration(s).', 'Though CE offers simple measurements or technique to analyze different chemistries of cement additives, some time may be required for the operator to determine the quality of the individual additives, final mix-fluid and slurry quality.', 'As is well known in the art, the cement may be Portland cement, high alumina cement, lime/silica mixtures, pozzolans, cement kiln dust, geopolymers, Sorel cement or chemically bonded phosphate ceramics.', 'A method for performing a cementing operation at a well site comprises providing a liquid additive mixing apparatus that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives.', 'At least one additive is mixed with water to form a mixing fluid.', 'The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit.', 'A cementing operation is executed by mixing the mixing fluid with a cement to form a slurry at the cement mixing unit.', 'A capillary electrophoresis instrument is used to monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.', 'If deviations are detected, corrective action is taken to return the at least one additive parameter to the predetermined tolerance.', 'The corrective action may comprise ceasing to draw mixing fluid from the first tank, placing the mixing fluid in a second tank that is fluidly connected to the cement mixing unit, and continuing the cementing operation while drawing mixing fluid from the second tank.', 'If a pump failure occurs, the corrective action may comprise stopping the operation, repairing and replacing the pump, and resuming the operation; or, if the pump failure occurs in the first tank, one may change from the first tank to the second tank.', 'The operation may continue while repairing or replacing the pump in the first tank.', 'The corrective action may comprise changing from the first tank to the second tank, or vice versa.', 'The corrective action may comprise adjusting a pump rate at which the mixing fluid is mixed with the cement.', 'The corrective action may comprise adjusting one or more additive concentrations in the mixing fluid.', 'A water line may be present in the mixing apparatus, thereby allowing a concentration adjustment of the one or more additives.', 'The method may further comprise filling the second tank with mixing fluid while mixing fluid from the first tank is being mixed with the cement.', 'When the first tank is exhausted, fluid from the second tank is then mixed with the cement.', 'The first tank is then filled with mixing fluid while the second tank is in use.', 'When the second tank is exhausted, fluid from the first tank is then mixed with the cement.', 'This alternating procedure may continue until the cementing operation is complete.', 'At least one of the additives may be soluble in the mixing fluid.', 'The at least one additive may comprise an anti-foamer, a defoamer, a dispersant, an accelerator, a retarder, a fluid-loss additive, a gas migration additive, a corrosion inhibitor, an acid, a gelling agent, a crosslinker, a breaker, or a surfactant or combinations thereof.', 'A method for monitoring at least one parameter pertaining to a cementing operation comprises providing a liquid additive mixing apparatus that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives.', 'At least one additive is mixed with water to form a mixing fluid.', 'The mixing fluid is placed in a first tank that is fluidly connected to a cement mixing unit.', 'A cementing operation is executed by continuously mixing the mixing fluid with a cement to form a slurry at the cement mixing unit.', 'A capillary electrophoresis instrument is used to monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one additive parameter.', 'At least one of the additives may be soluble in the mixing fluid, and the cementing operation may be continuous.', 'The at least one additive may comprise an anti-foamer, a defoamer, a dispersant, an accelerator, a retarder, a fluid-loss additive, a gas migration additive, a corrosion inhibitor, an acid, a gelling agent, a crosslinker, a breaker, or a surfactant or combinations thereof.', 'A system for performing a cementing operation may comprise a liquid additive mixing apparatus that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives to form a mixing fluid.', 'The system further comprises a first tank and a second tank that are fluidly connected to the liquid additive mixing apparatus and a cement mixing unit.', 'The system also comprises a capillary electrophoresis (CE) instrument.', 'The mixing fluid is mixed with the cement to form a slurry.', 'A CE instrument may monitor at least one additive parameter and detect deviations from a predetermined tolerance for the at least one parameter.', 'The first tank may be replenished with mixing fluid while the second tank is being used, and vice versa.', 'The system may further comprise a water line, and at least one of the additives may be soluble in the mixing fluid.', 'The at least one additive may comprise an anti-foamer, a defoamer, a dispersant, an accelerator, a retarder, a fluid-loss additive, a gas migration additive, a corrosion inhibitor, an acid, a gelling agent, a crosslinker, a breaker, or a surfactant or combinations thereof.', 'The preceding description has been presented with reference to present embodiments.', 'Persons skilled in the art and technology to which this disclosure pertains will appreciate that alterations and changes in the described structures and methods of operation can be practiced without meaningfully departing from the principle, and scope of this present disclosure.', 'Accordingly, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.']

['1.', 'A method for performing a cementing operation at a well site, comprising:\nproviding a liquid additive mixing apparatus that comprises a plurality of chambers containing additives, and further comprises a system for mixing the additives;\nusing the system for mixing the additives, mixing at least one additive with water to form a mixing fluid;\nplacing the mixing fluid in a tank;\nexecuting the cementing operation by mixing the mixing fluid with a cement to form a slurry using a cement mixing unit;\nusing a capillary electrophoresis (CE) instrument to monitor at least one additive parameter in the tank, wherein the tank is fluidly connected to the liquid additive mixing apparatus and the cement mixing unit, and wherein the CE instrument is disposed in the tank;\ndetecting at least one deviation from a predetermined tolerance for the at least one additive parameter using the CE instrument; and\ntaking corrective action to return the at least one additive parameter to the predetermined tolerance.', '2.', 'The method of claim 1, wherein:\nthe tank is a first tank,\nplacing the mixing fluid in the first tank comprises placing a first quantity of the mixing fluid in the first tank, and\nthe corrective action comprises: ceasing to draw the mixing fluid from the first tank, placing a second quantity of the mixing fluid in a second tank that is fluidly connected to the cement mixing unit, and continuing the cementing operation while drawing the mixing fluid from the second tank.', '3.', 'The method of claim 1, wherein the tank is a first tank, and if a pump failure occurs, the corrective action comprises:\nstopping the cementing operation, repairing or replacing the pump, and resuming the operation; or\nif the pump failure occurs in the first tank, changing from the first tank to a second tank and continuing the cementing operation while repairing or replacing the pump in the first tank, or vice versa.', '4.', 'The method of claim 1, wherein the tank is a first tank, and the corrective action comprises changing from the first tank to a second tank, or vice versa.', '5.', 'The method of claim 1, wherein the corrective action comprises adjusting a pump rate at which the mixing fluid is mixed with the cement.', '6.', 'The method of claim 1, wherein the corrective action comprises adjusting one or more additive concentrations in the mixing fluid.', '7.', 'The method of claim 6, wherein the system for mixing the additives comprises a water line for forming the mixing fluid.', '8.', 'The method of claim 1, wherein the tank is a first tank, and further comprising:\nfilling a second tank with the mixing fluid while the mixing fluid from the first tank is being mixed with the cement, wherein the second tank is fluidly connected to the cement mixing unit;\ndrawing the mixing fluid from the second tank when the first tank is exhausted;\nfilling the first tank with the mixing fluid while the mixing fluid from the second tank is being mixed with the cement;\ndrawing the mixing fluid from the first tank when the second tank is exhausted; and\ncontinuing to alternate between the first and second tanks until the cementing operation is complete.\n\n\n\n\n\n\n9.', 'The method of claim 1, wherein the at least one additive is soluble in the mixing fluid.', '10.', 'The method of claim 1, wherein the at least one additive comprises an anti-foamer, a defoamer, a dispersant, an accelerator, a retarder, a fluid-loss additive, a gas migration additive, a corrosion inhibitor, an acid, a gelling agent, a crosslinker, a breaker, or a surfactant or combinations thereof.', '11.', 'A method for monitoring at least one parameter pertaining to a cementing operation, comprising:\nproviding a liquid additive mixing apparatus that comprises a plurality of chambers containing additives and a system for mixing the additives;\nusing the system for mixing the additives, mixing at least one additive with water to form a mixing fluid;\nplacing the mixing fluid in a tank that is fluidly connected to a cement mixing unit;\nexecuting the cementing operation by continuously mixing the mixing fluid with a cement to form a slurry using the cement mixing unit; and\nusing a capillary electrophoresis (CE) instrument to monitor at least one additive parameter in the mixing fluid and detect deviations from a predetermined tolerance for the at least one additive parameter, and wherein the CE instrument is disposed in the tank.', '12.', 'The method of claim 11, wherein the at least one additive is soluble in the mixing fluid.', '13.', 'The method of claim 11, wherein the at least one additive comprises an anti-foamer, a defoamer, a dispersant, an accelerator, a retarder, a fluid-loss additive, a gas migration additive, a corrosion inhibitor, an acid, a gelling agent, a crosslinker, a breaker, or a surfactant or combinations thereof.', '14.', 'A system for performing a cementing operation, comprising:\na liquid additive mixing apparatus that comprises a plurality of chambers containing additives, and further comprises a system operable to mix at least one additive with water to form a mixing fluid;\na first tank that is fluidly connected to the liquid additive mixing apparatus and a cement mixing unit;\na second tank that is fluidly connected to the liquid additive mixing apparatus and the cement mixing unit; and\na capillary electrophoresis (CE) instrument operable to monitor at least one additive parameter and to detect at least one deviation from a predetermined tolerance for the at least one additive parameter, wherein the CE instrument is disposed in the first tank, and wherein the CE instrument is fluidly connected to the first tank, the second tank, or both.\n\n\n\n\n\n\n15.', 'The system of claim 14, further comprising the cement mixing unit, wherein the cement mixing unit is operable to mix the mixing fluid with cement to form a slurry.', '16.', 'The system of claim 14, further comprising a water line fluidly connected to the liquid additive mixing apparatus, the first tank, and the second tank.', '17.', 'The system of claim 14, wherein the at least one additive is soluble in the mixing fluid.', '18.', 'The system of claim 14, wherein the at least one additive comprises an anti-foamer, a defoamer, a dispersant, an accelerator, a retarder, a fluid-loss additive, a gas migration additive, a corrosion inhibitor, an acid, a gelling agent, a crosslinker, a breaker, or a surfactant or combinations thereof.']

['FIG.', '1 is a schematic diagram of the liquid additive mixing system of the disclosure.', '; FIG.', '2 is a capillary electrophoresis trace showing the analysis of three additives.', 'The figure also includes a calibration plot showing that the concentration determination is a linear function.', '; FIG.', '3 is a flowchart that illustrates the sequence of events that takes place during the disclosed cementing operations.; FIG. 1 is a non-limiting schematic illustration of a slurry mixing system 10 including a water line 12, a first additive chamber 14, a second additive chamber 16, and a third additive chamber 18.', 'When the water and the additives are mixed together the result is a mixing fluid or slurry 20.', 'Along the path at a convenient location, a Capillary Electrophoresis (CE) unit 22 is positioned.', 'The CE unit is configured to apply CE techniques to analyze characteristics of the mix 20.', 'The CE unit can be configured to determine the presence and quantity of the various additives being introduced to the mix 20 from the tanks 14, 16 and 18.', 'The CE unit 22 may also monitor the quality of water in the line 12 by determining different ions present in water, which could ultimately determine the performance of different additives from the additive tanks 14, 16 and 18.', 'The mixing fluid may be then transferred to Tank 1 23 or Tank 2 24.', 'CE units may be positioned inside Tank 1 and Tank 2.', 'Both Tank 1 and Tank 2 are fluidly connected to a cement mixing unit 25.', 'Another CE unit may be installed in the line between Tank 1 and Tank 2 and the cement mixing unit.; FIG. 1 also shows a graph 26 of the detected presence of the additives over time.', 'There are three lines representing additives A, B, and C.', 'In this instance, the line representing additive B begins a sharp decline at which point the line slopes downward suggesting a problem with the second tank 16 providing additive B to the mix 20.; FIG.', '2 shows a typical CE analysis trace of a blend of additives.', 'In this instance the data present in FIG.', '2 were obtained with the same CE protocol.', 'It highlights that different cement additives (single-component or multi-components) can be detected very accurately.', 'Furthermore, for each of them, retention time is different.', 'It is therefore possible to determine the concentration of each additive in the mix-fluid prepared on the rig.; FIG.', '2 also presents the calibration plot for one common additive.', 'This not only indicates that the concentration can be monitored but also that deviations outside the “delivery” tolerance will be effectively indicated by examination of the blend composition when all set points are constant.', 'The embodiments disclosed herein highlight the advantages and applicability of analytical techniques such as CE for analysis of different types of additives for key components.', 'By selecting appropriate constituents this is the first disclosed method that can monitor a cementing operation by concentrating solely on the composition of the species present in the mix and using one single method.; FIG.', '3 is a flow chart showing methods according to the present disclosure.', 'A method 30 for monitoring, diagnosing, and correcting a parameter in a cementing operation is shown.', 'First the cementing operation begins at 32.', 'During the cementing operation, one or more parameters is monitored at 33 using the Capillary Electrophoresis (CE) technique.', 'The monitoring can be performed using another equivalent technique within the scope of this disclosure.', 'The parameters being monitored may be any number of additives or components of the cement or any other material added to the cement during the cementing operation added to the cement before the operation begins.', 'The method also includes determining periodically or continuously at 34 whether or not one or more parameters are outside the range of tolerance.']

US11901785

Polymeric materials

May 28, 2021

Samy A. Madbouly, Jason Holzmueller, William Goertzen, Gregory Howard Manke

SCHLUMBERGER TECHNOLOGY CORPORATION

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['A submersible component can include a conductor; and a polymeric material disposed about at least a portion of the conductor where the polymeric material includes at least approximately 50 percent by weight polyether ether ketone (PEEK) and at least 5 percent by weight perfluoroalkoxy alkanes (PFA).', 'A submersible electrical unit can include an electrically conductive winding; and a polymeric composite material disposed about at least a portion of the electrically conductive winding where the polymeric composite material includes polymeric material at at least approximately 40 percent by volume and one or more fillers at at least approximately 10 percent by volume.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is a continuation application of U.S. application Ser.', 'No. 16/585,678, filed Sep. 27, 2019, which is a divisional application of U.S. application Ser.', 'No. 15/227,737, filed Aug. 3, 2016, the entirety of each of which is hereby incorporated by reference herein.', 'BACKGROUND\n \nA conductor can conduct electricity or, for example, electromagnetic energy (e.g., consider an optical fiber).', 'A conductor can be coated with a material that acts to insulate the conductor.', 'As an example, such a material may be a dielectric material, which may be, for example, a polymeric material.', 'As an example, a polymeric material may be suitable for use as a varnish and/or an encapsulant.', 'For example, consider a magnet wire varnish and an electric motor stator encapsulant.', 'SUMMARY\n \nA submersible component can include a conductor; and a polymeric material disposed about at least a portion of the conductor where the polymeric material includes at least approximately 50 percent by weight polyether ether ketone (PEEK) and at least 5 percent by weight perfluoroalkoxy alkanes (PFA).', 'A submersible electrical unit can include an electrically conductive winding; and a polymeric composite material disposed about at least a portion of the electrically conductive winding where the polymeric composite material includes polymeric material at at least approximately 40 percent by volume and one or more fillers at at least approximately 10 percent by volume.', 'Various other apparatuses, systems, methods, etc., are also disclosed.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFeatures and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.\n \nFIG.', '1\n illustrates examples of equipment in geologic environments;\n \nFIG.', '2\n illustrates an example of an electric submersible pump system;\n \nFIG.', '3\n illustrates examples of equipment;\n \nFIG.', '4\n illustrates an example of a system that includes a motor;\n \nFIG.', '5\n illustrates examples of equipment;\n \nFIG.', '6\n illustrates examples of equipment;\n \nFIG.', '7\n illustrates examples of equipment;\n \nFIG.', '8\n illustrates an example of an insulated conductor;\n \nFIG.', '9\n illustrates examples of methods;\n \nFIG.', '10\n illustrates an example of a plot of data;\n \nFIG.', '11\n illustrates an example of a plot of data;\n \nFIG.', '12\n illustrates an example of a plot of data;\n \nFIG.', '13\n illustrates an example of a plot of data;\n \nFIG.', '14\n illustrates an example of a plot of data;\n \nFIG.', '15\n illustrates an example of a plot of data;\n \nFIG.', '16\n illustrates an example of a plot of data;\n \nFIG.', '17\n illustrates an example of a plot of data;\n \nFIG.', '18\n illustrates an example of a plot of data;\n \nFIG.', '19\n illustrates an example of a plot of data;\n \nFIG.', '20\n illustrates an example of a plot of data;\n \nFIG.', '21\n illustrates an example of a plot of data;\n \nFIG.', '22\n illustrates an example of a plot of data;\n \nFIG.', '23\n illustrates an example of a plot of data;\n \nFIG.', '24\n illustrates an example of a plot of data; and\n \nFIG.', '25\n illustrates example components of a system and a networked system.', 'DETAILED DESCRIPTION', 'The following description includes the best mode presently contemplated for practicing the described implementations.', 'This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.\n \nFIG.', '1\n shows an example of a geologic environment \n120\n and examples of equipment \n150\n and \n170\n.', 'In \nFIG.', '1\n, the geologic environment \n120\n may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir \n121\n and that may be, for example, intersected by a fault \n123\n (e.g., or faults).', 'As an example, the geologic environment \n120\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n122\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n125\n.', 'Such information may include information associated with downhole equipment \n124\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n126\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n125\n that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n120\n as optionally including equipment \n127\n and \n128\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n129\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n127\n and/or \n128\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As to the equipment \n150\n, an electric motor \n160\n can include bundles \n162\n of wires \n164\n.', 'For example, the wires \n164\n can be magnet wires.', 'Magnet wire can include electrically conductive material such as an electrically conductive metal or alloy material.', 'For example, consider copper or aluminum as electrically conductive material.', 'As an example, magnet wire can be insulated with a layer or layers of insulation or insulations.', 'As an example, magnet wire may be used to construct various types of equipment such as, for example, transformers, inductors, motors, speakers, hard disk head actuators, electromagnets, and other applications that can include coils of insulated wire.', 'As an example, magnet wire may be electrically insulated with material that is extruded, taped, etc.', 'As an example, magnet wire can be wound to form a winding such as, for example, a phase winding of a stator, which may be, for example, vacuum impregnated with an insulating varnish to improve insulation strength and long-term reliability of the winding.', 'As an example, materials can include an electrically insulating material, a varnish material and/or an encapsulating material.', 'As an example, magnet wire may have a round cross section, a rectangular cross section, a hexagonal cross section (e.g., with rounded corners) or one or more types of cross sections, which may provide for one or more of packing efficiency, structural stability, thermal conductivity, etc.', 'As shown in the example of \nFIG.', '1\n, the electric motor \n160\n may be a multiphase electric motor (e.g., a polyphase electric motor).', 'For example, polyphase power may be delivered via one or more power cables to drive an induction motor where the polyphaser power generates a rotating magnetic field.', 'As an example, where a three-or-more-phase supply completes one full cycle, a magnetic field of a two-poles-per-phase motor can be rotated through 360 degrees in physical space.', 'As an example, a motor may be a single-phase motor.', 'As an example, a motor may be an AC motor.', 'As an example, a motor may be a DC motor.', 'As to the equipment \n170\n, it can include one or more conductors \n180\n that may be operatively coupled to one or more actuators \n182\n, one or more sensors \n184\n and/or one or more other types of electrical components \n186\n (e.g., electrical, electro-mechanical, electro-chemical, electro-fluidic, etc.).', 'As an example, one or more polymeric materials, optionally one or more polymeric composite materials, may be utilized in the equipment \n170\n and/or in one or more components (e.g., cables, sensors, etc.) operatively coupled to the equipment \n170\n.', 'As an example, equipment can include wireline equipment.', 'For example, consider equipment that is operatively coupled to an electrical cable that can lower the equipment into a borehole where the equipment may also include transmission circuitry that can transmit and/or receive information via the electrical cable.', 'As an example, a wireline operation can include using single-strand and/or multi-strand wire or cable for intervention in a borehole (e.g., consider oil and/or gas wells).', 'As an example, a wireline operation can include electric logging via one or more cables that include electrical conductors.', 'As an example, the equipment \n150\n may be or include artificial lift equipment.', 'For example, the electric motor \n160\n may be an electric motor of an electric submersible pump (e.g., an ESP).', 'In such an example, a cable or cables may extend from surface equipment to the equipment \n150\n, for example, to provide power, to carry information, to sense information, etc.', 'As an example, equipment can include an electric downhole motor, an electric downhole wireline tool (e.g., or slickline tool), a cable, etc.\n \nConditions in a geologic environment may be transient and/or persistent.', 'Where equipment is placed within a geologic environment, longevity of the equipment can depend on characteristics of the environment and, for example, duration of use of the equipment as well as function of the equipment.', 'Where equipment is to endure in an environment over an extended period of time, uncertainty may arise in one or more factors that could impact integrity or expected lifetime of the equipment.', 'As an example, where a period of time may be of the order of decades, equipment that is intended to last for such a period of time may be constructed to endure conditions imposed thereon, whether imposed by an environment or environments and/or one or more functions of the equipment itself.', 'As an example, an environment may be a harsh environment, for example, an environment that may be classified as being a high-pressure and high-temperature environment (HPHT).', 'A so-called HPHT environment may include pressures up to about 138 MPa (e.g., about 20,000 psi) and temperatures up to about 205 degrees C. (e.g., about 400 degrees F. and about 480 K), a so-called ultra-HPHT environment may include pressures up to about 241 MPa (e.g., about 35,000 psi) and temperatures up to about 260 degrees C. (e.g., about 500 degrees F. and about 530 K) and a so-called HPHT-hc environment may include pressures greater than about 241 MPa (e.g., about 35,000 psi) and temperatures greater than about 260 degrees C. (e.g., about 500 degrees F. and about 530 K).', 'As an example, an environment may be classified based in one of the aforementioned classes based on pressure or temperature alone.', 'As an example, an environment may have its pressure and/or temperature elevated, for example, through use of equipment, techniques, etc.', 'For example, a SAGD operation may elevate temperature of an environment (e.g., by 100 degrees C. or more; about 370 K or more).', 'As mentioned, magnet wire may be part of equipment and/or operatively coupled to equipment.', 'As to motorized equipment, various examples of electric submersible pump (ESP) equipment are described; noting that magnet wire or other relatively small gauge wire can be utilized in and/or in association with one or more types of equipment.\n \nFIG.', '2\n shows an example of an ESP system \n200\n that includes an ESP \n210\n as an example of equipment that may be placed in a geologic environment.', 'As an example, an ESP may be expected to function in an environment over an extended period of time (e.g., optionally of the order of years).', 'In the example of \nFIG.', '2\n, the ESP system \n200\n includes a network \n201\n, a well \n203\n disposed in a geologic environment (e.g., with surface equipment, etc.), a power supply \n205\n, the ESP \n210\n, a controller \n230\n, a motor controller \n250\n and a VSD unit \n270\n.', 'The power supply \n205\n may receive power from a power grid, an onsite generator (e.g., natural gas driven turbine), or other source.', 'The power supply \n205\n may supply a voltage, for example, of about 4.16 kV.\n \nAs shown, the well \n203\n includes a wellhead that can include a choke (e.g., a choke valve).', 'For example, the well \n203\n can include a choke valve to control various operations such as to reduce pressure of a fluid from high pressure in a closed wellbore to atmospheric pressure.', 'A wellhead may include one or more sensors such as a temperature sensor, a pressure sensor, a solids sensor, etc.', 'As to the ESP \n210\n, it is shown as including cables \n211\n (e.g., or a cable), a pump \n212\n, gas handling features \n213\n, a pump intake \n214\n, a motor \n215\n, one or more sensors \n216\n (e.g., temperature, pressure, strain, current leakage, vibration, etc.) and a protector \n217\n.', 'As an example, an ESP may include a REDA™ HOTLINE™ high-temperature ESP motor.', 'Such a motor may be suitable for implementation in a thermal recovery heavy oil production system, such as, for example, SAGD system or other steam-flooding system.', 'As an example, an ESP motor can include a three-phase squirrel cage with two-pole induction.', 'As an example, an ESP motor may include steel stator laminations that can help focus magnetic forces on rotors, for example, to help reduce energy loss.', 'As an example, stator windings can include copper and insulation.', 'As an example, the one or more sensors \n216\n of the ESP \n210\n may be part of a digital downhole monitoring system.', 'For example, consider the commercially available PHOENIX™ MULTISENSOR XT150 system marketed by Schlumberger Limited (Houston, Tex.).', 'A monitoring system may include a base unit that operatively couples to an ESP motor (see, e.g., the motor \n215\n), for example, directly, via a motor-base crossover, etc.', 'As an example, such a base unit (e.g., base gauge) may measure intake pressure, intake temperature, motor oil temperature, motor winding temperature, vibration, currently leakage, etc.', 'As explained with respect to \nFIG.', '4\n, a base unit may transmit information via a power cable that provides power to an ESP motor and may receive power via such a cable as well.', 'As an example, a remote unit may be provided that may be located at a pump discharge (e.g., located at an end opposite the pump intake \n214\n).', 'As an example, a base unit and a remote unit may, in combination, measure intake and discharge pressures across a pump (see, e.g., the pump \n212\n), for example, for analysis of a pump curve.', 'As an example, alarms may be set for one or more parameters (e.g., measurements, parameters based on measurements, etc.).', 'Where a system includes a base unit and a remote unit, such as those of the PHOENIX™ MULTISENSOR XT150 system, the units may be linked via wires.', 'Such an arrangement provide power from the base unit to the remote unit and allows for communication between the base unit and the remote unit (e.g., at least transmission of information from the remote unit to the base unit).', 'As an example, a remote unit is powered via a wired interface to a base unit such that one or more sensors of the remote unit can sense physical phenomena.', 'In such an example, the remote unit can then transmit sensed information to the base unit, which, in turn, may transmit such information to a surface unit via a power cable configured to provide power to an ESP motor.', 'In the example of \nFIG.', '2\n, the well \n203\n may include one or more well sensors \n220\n, for example, such as the commercially available OPTICLINE™ sensors or WELLWATCHER BRITEBLUE™ sensors marketed by Schlumberger Limited (Houston, Tex.).', 'Such sensors are fiber-optic based and can provide for real time sensing of temperature, for example, in SAGD or other operations.', 'As shown in the example of \nFIG.', '1\n, a well can include a relatively horizontal portion.', 'Such a portion may collect heated heavy oil responsive to steam injection.', 'Measurements of temperature along the length of the well can provide for feedback, for example, to understand conditions downhole of an ESP.', 'Well sensors may extend a considerable distance into a well and possibly beyond a position of an ESP.', 'In the example of \nFIG.', '2\n, the controller \n230\n can include one or more interfaces, for example, for receipt, transmission or receipt and transmission of information with the motor controller \n250\n, a VSD unit \n270\n, the power supply \n205\n (e.g., a gas fueled turbine generator, a power company, etc.), the network \n201\n, equipment in the well \n203\n, equipment in another well, etc.', 'As shown in \nFIG.', '2\n, the controller \n230\n may include or provide access to one or more modules or frameworks.', 'Further, the controller \n230\n may include features of an ESP motor controller and optionally supplant the ESP motor controller \n250\n.', 'For example, the controller \n230\n may include the UNICONN™ motor controller \n282\n marketed by Schlumberger Limited (Houston, Tex.).', 'In the example of \nFIG. \n2\n, the controller \n230\n may access one or more of the PIPESIM™ framework \n284\n, the ECLIPSE™ framework \n286\n marketed by Schlumberger Limited (Houston, Tex.) and the PETREL™ framework \n288\n marketed by Schlumberger Limited (Houston, Tex.)', '(e.g., and optionally the OCEAN™ framework marketed by Schlumberger Limited (Houston, Tex.)).', 'In the example of \nFIG.', '2\n, the motor controller \n250\n may be a commercially available motor controller such as the UNICONN™ motor controller.', 'The UNICONN™ motor controller can connect to a SCADA system, the ESPWATCHER™ surveillance system, etc.', 'The UNICONN™ motor controller can perform some control and data acquisition tasks for ESPs, surface pumps or other monitored wells.', 'As an example, the UNICONN™ motor controller can interface with the aforementioned PHOENIX™ monitoring system, for example, to access pressure, temperature and vibration data and various protection parameters as well as to provide direct current power to downhole sensors.', 'The UNICONN™ motor controller can interface with fixed speed drive (FSD) controllers or a VSD unit, for example, such as the VSD unit \n270\n.', 'For FSD controllers, the UNICONN™ motor controller can monitor ESP system three-phase currents, three-phase surface voltage, supply voltage and frequency, ESP spinning frequency and leg ground, power factor and motor load.', 'For VSD units, the UNICONN™ motor controller can monitor VSD output current, ESP running current, VSD output voltage, supply voltage, VSD input and VSD output power, VSD output frequency, drive loading, motor load, three-phase ESP running current, three-phase VSD input or output voltage, ESP spinning frequency, and leg-ground.', 'In the example of \nFIG.', '2\n, the ESP motor controller \n250\n includes various modules to handle, for example, backspin of an ESP, sanding of an ESP, flux of an ESP and gas lock of an ESP.', 'The motor controller \n250\n may include any of a variety of features, additionally, alternatively, etc.', 'In the example of \nFIG.', '2\n, the VSD unit \n270\n may be a low voltage drive (LVD) unit, a medium voltage drive (MVD) unit or other type of unit (e.g., a high voltage drive, which may provide a voltage in excess of about 4.16 kV).', 'As an example, the VSD unit \n270\n may receive power with a voltage of about 4.16 kV and control a motor as a load with a voltage from about 0 V to about 4.16 kV. The VSD unit \n270\n may include commercially available control circuitry such as the SPEEDSTAR™ MVD control circuitry marketed by Schlumberger Limited (Houston, Tex.).', 'FIG.', '3\n shows cut-away views of examples of equipment such as, for example, a portion of a pump \n320\n, a protector \n370\n, a motor \n350\n of an ESP and a sensor unit \n360\n.', 'In the examples of \nFIG. \n3\n, each of the pieces of equipment may be considered to be assemblies that, for example, can be operatively coupled to form a system (e.g., an ESP or ESP system).', 'In \nFIG. \n3\n, the pump \n320\n, the protector \n370\n, the motor \n350\n and the sensor unit \n360\n are shown with respect to cylindrical coordinate systems (e.g., r, z, Θ).', 'Various features of equipment may be described, defined, etc. with respect to a cylindrical coordinate system.', 'As an example, a lower end of the pump \n320\n may be coupled to an upper end of the protector \n370\n, a lower end of the protector \n370\n may be coupled to an upper end of the motor \n350\n and a lower end of the motor \n350\n may be coupled to an upper end of the sensor unit \n360\n (e.g., via a bridge or other suitable coupling).', 'As shown in \nFIG.', '3\n, a shaft segment of the pump \n320\n may be coupled via a connector to a shaft segment of the protector \n370\n and the shaft segment of the protector \n370\n may be coupled via a connector to a shaft segment of the motor \n350\n.', 'As an example, an ESP may be oriented in a desired direction, which may be vertical, horizontal or other angle (e.g., as may be defined with respect to gravity, etc.).', 'Orientation of an ESP with respect to gravity may be considered as a factor, for example, to determine ESP features, operation, etc.', 'As shown in \nFIG.', '3\n, the motor \n350\n is an electric motor that includes a connector \n352\n, for example, to operatively couple the electric motor to a multiphase power cable, for example, optionally via one or more motor lead extensions.', 'Power supplied to the motor \n350\n via the connector \n352\n may be further supplied to the sensor unit \n360\n, for example, via a wye point of the motor \n350\n (e.g., a wye point of a multiphase motor).', 'As an example, a connector may include features to connect one or more transmission lines, optionally dedicated to a monitoring system.', 'For example, the connector \n352\n may include a socket, a pin, etc., that can couple to a transmission line dedicated to the sensor unit \n360\n.', 'As an example, the sensor unit \n360\n can include a connector that can connect the sensor unit \n360\n to a dedicated transmission line or lines, for example, directly and/or indirectly.', 'As an example, the motor \n350\n may include a transmission line jumper that extends from the connector \n352\n to a connector that can couple to the sensor unit \n360\n.', 'Such a transmission line jumper may be, for example, one or more conductors, twisted conductors, an optical fiber, optical fibers, a waveguide, waveguides, etc.', 'As an example, the motor \n350\n may include a high-temperature optical material that can transmit information.', 'In such an example, the optical material may couple to one or more optical transmission lines and/or to one or more electrical-to-optical and/or optical-to-electrical signal converters.', 'In the examples of \nFIG.', '3\n, one or more coated electrical conductors may be present.', 'For example, the pump \n320\n may include one or more coated electrical conductors operatively coupled to and/or part of sensor circuitry and/or another type of circuitry; the protector \n370\n may include one or more coated electrical conductors operatively coupled to and/or part of sensor circuitry and/or another type of circuitry; the motor \n350\n may include one or more coated electrical conductors operatively coupled to and/or part of sensor circuitry, electric motor circuitry and/or another type of circuitry; and the unit \n360\n may include one or more coated electrical conductors operatively coupled to and/or part of sensor circuitry and/or another type of circuitry.', 'In the examples of \nFIG.', '3\n, the pump \n320\n can include a housing \n324\n, the protector \n370\n can include a housing \n374\n, the motor \n350\n can include a housing \n354\n and the unit \n360\n can include a housing \n364\n.', 'In such examples, a housing can include opposing ends, a longitudinal axis, an axial length defined between the opposing ends, a maximum transverse dimension that is less than the length and an interior space.', 'As an example, circuitry may be disposed at least in part in the interior space.', 'As an example, a coated electrical conductor can be electrically coupled to such circuitry where the coated electrical conductor includes an electrical conductor that includes copper and a length defined by opposing ends, a polymeric electrical insulation layer disposed about at least a portion of the length of the electrical conductor, and a barrier layer disposed about at least a portion of the polymeric electrical insulation layer.', 'As an example, an interior space of an assembly may be sealed via one or more seal elements, joints, etc.', 'As an example, the equipment \n150\n of \nFIG.', '1\n can include a sealed motor or a motor included in a sealed housing.', 'As an example, the equipment \n170\n of \nFIG.', '1\n can include a sealed housing that aims to protect the one or more actuators \n182\n, the one or more sensors \n184\n and/or the one or more other components from fluid in a downhole environment.', 'As an example, the one or more conductors \n180\n may include one or more coated electrical conductors.', 'As an example, the equipment \n150\n and/or the equipment \n170\n can be assemblies that include a coated electrical conductor electrically coupled to circuitry where the coated electrical conductor includes an electrical conductor that includes copper and a length defined by opposing ends, a polymeric electrical insulation layer disposed about at least a portion of the length of the electrical conductor, and a barrier layer disposed about at least a portion of the polymeric electrical insulation layer.', 'As to the pump \n320\n, the motor \n350\n, the unit \n360\n and the protector \n370\n of \nFIG.', '3\n, these may be individual assemblies that include a coated electrical conductor electrically coupled to circuitry where the coated electrical conductor includes an electrical conductor that includes copper and a length defined by opposing ends, a polymeric electrical insulation layer disposed about at least a portion of the length of the electrical conductor, and a barrier layer disposed about at least a portion of the polymeric electrical insulation layer.', 'As an example, one or more of such assemblies can include one or more sealed interior spaces, for example, consider a housing that includes one or more seal elements, one or more joints, etc. that aim to protect circuitry, etc., in the interior space or spaces from fluid in a downhole environment.', 'As an example, an assembly can include an encapsulant or encapsulating material in an interior space.', 'As an example, an assembly can include a specialized fluid in an interior space (e.g., a dielectric oil, etc.).', 'As an example, where water and/or gas (e.g., CO\n2\n, H\n2\nS) penetrates a housing and enters an interior space, a coated electrical conductor can include an electrical conductor that includes copper and a length defined by opposing ends, a polymeric electrical insulation layer disposed about at least a portion of the length of the electrical conductor, and a barrier layer disposed about at least a portion of the polymeric electrical insulation layer where the barrier layer acts to protect the polymeric electrical insulation layer from the water and/or gas.', 'In such an example, the barrier layer may prolong the useful life (e.g., operational life) of an assembly.\n \nFIG.', '4\n shows a block diagram of an example of a system \n400\n that includes a power source \n401\n as well as data \n402\n (e.g., information).', 'The power source \n401\n provides power to a VSD block \n470\n while the data \n402\n may be provided to a communication block \n430\n.', 'The data \n402\n may include instructions, for example, to instruct circuitry of the circuitry block \n450\n, one or more sensors of the sensor block \n460\n, etc.', 'The data \n402\n may be or include data communicated, for example, from the circuitry block \n450\n, the sensor block \n460\n, etc.', 'In the example of \nFIG.', '4\n, a choke block \n440\n can provide for transmission of data signals via a power cable \n411\n (e.g., including motor lead extensions “MLEs”).', 'A power cable may be provided in a format such as a round format or a flat format with multiple conductors.', 'MLEs may be spliced onto a power cable to allow each of the conductors to physically connect to an appropriate corresponding connector of an electric motor (see, e.g., the connector \n352\n of \nFIG.', '3\n).', 'As an example, MLEs may be bundled within an outer casing (e.g., a layer of armor, etc.).', 'As shown, the power cable \n411\n connects to a motor block \n415\n, which may be a motor (or motors) of an ESP and be controllable via the VSD block \n470\n.', 'In the example of \nFIG.', '4\n, the conductors of the power cable \n411\n electrically connect at a wye point \n425\n.', 'The circuitry block \n450\n may derive power via the wye point \n425\n and may optionally transmit, receive or transmit and receive data via the wye point \n425\n.', 'As shown, the circuitry block \n450\n may be grounded.', 'As an example, a cable as in \nFIG.', '4\n can include multiple conductors where each conductor can carry current of a phase of a multiphase power supply for a multiphase electric motor.', 'In such an example, a conductor may be in a range from about 8 AWG (about 3.7 mm) to about 00 AWG (about 9.3 mm).', 'TABLE 1\n \n \n \n \n \n \n \n \nExamples of some components.', 'Cable Component\n \nDimensions\n \n \n \n \n \n \n \n \nConductor (Cu)\n \n\u20028 AWG to 00 AWG (3.7 mm to 9.3 mm)\n \n \n \n \nInsulation\n \n58 mils to 130 mils (1.5 mm to 3.3 mm)\n \n \n \n \nLead (Pb)\n \n20 mils to 60 mils (0.5 mm to 1.5 mm)\n \n \n \n \nJacket over Lead (Pb)\n \n20 mils to 85 mils (0.5 mm to 2.2 mm)\n \n \n \n \nArmor (e.g., optional)\n \n10 mils to 120 mils (0.25 mm to 3.0 mm)\n \n \n \n \nPolymeric Coat\n \n20 mils to 60 mils (0.5 mm to 1.5 mm)\n \n \n \n \n(e.g., optional)', 'As an example, a cable as in \nFIG.', '4\n may include conductors for delivery of power to a multiphase electric motor with a voltage range of about 3 kV to about 8 kV. As an example, a cable may carry power, at times, for example, with amperage of up to about 200 A or more.', 'As an example, a cable may carry current to power a multiphase electric motor or other piece of equipment (e.g., downhole equipment powerable by a cable).', 'As noted above, in the example of \nFIG.', '4\n, a conductor may be in a range from about 8 AWG (about 3.3 mm) to about 00 AWG (about 9.3 mm).', 'As to magnet wire or other type of wire that may be insulated, a conductor may be in a range from about 28 AWG (about 0.3 mm) to about 1 AWG (about 7.3 mm).', 'As mentioned, magnet wire may be used in construction of an electric motor or in construction of various other types of equipment (e.g., wireline equipment, etc.).', 'As an example, a cable or other type of component that can be suitable for use in a fluid environment (e.g., a submersible component) can include one or more types of polymers (e.g., one or more types of polymeric materials, etc.).', 'As an example, a polymeric material can include one or more types of polymers.', 'A polymer may be considered to be a relatively large molecule or macromolecule composed of subunits.', 'Polymers are created via polymerization of smaller molecules that can include molecules known as monomers.', 'Polymers may be characterized by physical properties such as, for example, toughness, viscoelasticity, tendency to form glasses and semicrystalline structures, melting temperature, etc.', 'As an example, a polymeric material can be an electrical insulator.', 'As an example, a polymeric material can be a dielectric material that is an electrical insulator.', 'A dielectric material or dielectric is an electrical insulator that can be polarized by an applied electric field.', 'As an example, a polymeric material can be characterized at least in part by a dielectric constant.', 'For example, KAPTON™ polyimide film (marketed by E. I. Du Pont de Nemours and Company, Wilmington, Del.) can be characterized by a dielectric constant that can depend on humidity where the dielectric constant increases with respect to increasing relative humidity (RH), for example, from about 3 to about 4 for an increase from about 0 percent RH to about 100 percent RH (e.g., for a 1 mil film of KAPTON® type HN polymer).', 'Such water-related changes in properties are due to polyimide films being formed by condensation reactions.', 'Polyimide, when exposed to water, can degrade via hydrolytic attack.', 'The kinetics of hydrolytic degradation can depend on temperature and pressure as well as, for example, presence of other constituents in an environment.', 'In Table 1, the insulation may be a polymeric material.', 'As an example, the insulation may be a polymeric material that is or includes polyimide.', 'In such an example, the lead (Pb) layer can be a barrier layer that acts to protect the insulation.', 'For example, the lead (Pb) layer can reduce permeation of water, H\n2\nS, CO\n2 \nor one or more other constituents that can degrade the insulation and/or otherwise impact its dielectric properties (e.g., ability to insulate a conductor).', 'While lead (Pb) is mentioned as a barrier material, one or more other types of barrier materials may be utilized, which may be, for example, one or more of metallic material, ceramic material, and polymeric material.', 'As an example, a magnet wire can include insulation and a barrier layer disposed about the insulation where the insulation may be or include polymeric material and where the barrier layer includes barrier material that can reduce permeation of water, H\n2\nS, CO\n2 \nor one or more other constituents that can degrade the insulation and/or otherwise impact its dielectric properties (e.g., ability to insulate a conductor).', 'As an example, a barrier material can include one or more of metallic material, ceramic material, and polymeric material.\n \nFIG.', '5\n shows various examples of motor equipment.', 'A pothead unit \n501\n includes opposing ends \n502\n and \n504\n and a through bore, for example, defined by a bore wall \n505\n.', 'As shown, the ends \n502\n and \n504\n may include flanges configured for connection to other units (e.g., a protector unit at the end \n502\n and a motor unit at the end \n504\n).', 'The pothead unit \n501\n includes cable passages \n507\n-\n1\n, \n507\n-\n2\n and \n507\n-\n3\n (e.g., cable connector sockets) configured for receipt of cable connectors \n516\n-\n1\n, \n516\n-\n2\n and \n516\n-\n3\n of respective cables \n514\n-\n1\n, \n514\n-\n2\n and \n514\n-\n3\n.', 'As an example, the cables \n514\n-\n1\n, \n514\n-\n2\n and \n514\n-\n3\n and/or the cable connectors \n516\n-\n1\n, \n516\n-\n2\n and \n516\n-\n3\n may include one or more polymeric materials.', 'For example, a cable may include polymeric insulation while a cable connector may include polymeric insulation, a polymeric component (e.g., a bushing), etc.', 'As an example, the cables \n514\n-\n1\n, \n514\n-\n2\n and \n514\n-\n3\n may be coupled to a single larger cable.', 'The single larger cable may extend to a connector end for connection to a power source or, for example, equipment intermediate the cable and a power source (e.g., an electrical filter unit, etc.).', 'As an example, a power source may be a VSD unit that provides three-phase power for operation of a motor.\n \nFIG.', '5\n also shows a pothead unit \n520\n that includes a socket \n521\n.', 'As an example, a cable \n522\n may include a plug \n524\n that can couple to the socket \n521\n of the pothead unit \n520\n.', 'In such an example, the cable \n522\n may include one or more conductors \n526\n.', 'As an example, a cable may include at least one fiber optic cable or one or more other types of cables.', 'As an example, a fiber optic cable can include a layer of polymeric material where a barrier layer may be disposed over the layer of polymeric material.', 'In such an example, the barrier layer may help to protect the layer of polymeric material from one or more constituents in an environment.', 'As an example, a fiber optic cable may be suitable for use in a fluid environment where the fiber optic cable is a submersible fiber optic cable.', 'As explained above, equipment may be placed in a geologic environment where such equipment may be subject to conditions associated with function or functions of the equipment and/or be subject to conditions associated with the geologic environment.', 'Equipment may experience conditions that are persistent (e.g., relatively constant), transient or a combination of both.', 'As an example, to enhance equipment integrity (e.g., reduction in failures, increased performance, longevity, etc.), equipment may include at least one polymeric material and at least one barrier layer disposed about at least one of the at least one polymeric material.\n \nFIG.', '6\n shows a perspective cut-away view of an example of a motor assembly \n600\n that includes a power cable \n644\n (e.g., MLEs, etc.) to supply energy, a shaft \n650\n, a housing \n660\n that may be made of multiple components (e.g., multiple units joined to form the housing \n660\n), stacked laminations \n680\n, stator windings \n670\n of wire (e.g., magnet wire) and rotor laminations \n690\n and rotor windings \n695\n coupled to the shaft \n650\n (e.g., rotatably driven by energizing the stator windings \n670\n).', 'As shown in \nFIG. \n6\n, the housing \n660\n includes an inner surface \n661\n and an outer surface \n665\n.', 'As an example, the housing \n660\n can define one or more cavities via its inner surface \n661\n where one or more of the cavities may be hermetically sealed.', 'As an example, such a cavity may be filled at least partially with dielectric oil.', 'As an example, dielectric oil may be formulated to have a desired viscosity and/or viscoelastic properties, etc.', 'As shown, the shaft \n650\n may be fitted with a coupling \n652\n to couple the shaft to another shaft.', 'A coupling may include, for example, splines that engage splines of one or more shafts.', 'The shaft \n650\n may be supported by bearings \n654\n-\n1\n, \n654\n-\n2\n, \n654\n-\n3\n, etc. disposed in the housing \n660\n.', 'As shown, the housing \n660\n includes opposing axial ends \n662\n and \n664\n with the substantially cylindrical outer surface \n665\n extending therebetween.', 'The outer surface \n665\n can include one or more sealable openings for passage of oil (e.g., dielectric oil), for example, to lubricate the bearings and to protect various components of the motor assembly \n600\n.', 'As an example, the motor assembly \n600\n may include one or more sealable cavities.', 'For example, a passage \n666\n allows for passage of one or more conductors of the cable \n644\n (e.g., or cables) to a motor cavity \n667\n of the motor assembly \n600\n where the motor cavity \n667\n may be a sealable cavity.', 'As shown, the motor cavity \n667\n houses the stator windings \n670\n and the stator laminations \n680\n.', 'As an example, an individual winding may include a plurality of conductors (e.g., magnet wires).', 'For example, a cross-section \n672\n of an individual winding may reveal a plurality of conductors that are disposed in a matrix (e.g., of material or materials) or otherwise bound together (e.g., by a material or materials).', 'In the example of \nFIG. \n6\n, the motor housing \n660\n includes an oil reservoir \n668\n, for example, that may include one or more passages (e.g., a sealable external passage and a passage to the motor cavity \n667\n) for passage of oil.', 'As an example, a shaft may be reciprocating, for example, where a shaft includes one or more magnets (e.g., permanent magnets) that respond to current that passes through stator windings.', 'As an example, a polymeric matrix may be formed of organic and/or inorganic monomeric and/or polymeric materials.', 'As an example, one or more of an epoxy, bismaleimide, polybutadiene, benzoxazine, cyanate ester, silicone, Ring-Opening Metathesis Polymers (ROMP), and preceramic polymers may be utilized.', 'As an example, one or more monomers and/or polymers may be amphiphilic, which may facilitate blending in one or more fillers.', 'As an example, the functionalized linseed oil marketed as DILULIN™ material (Cargill, Inc., Wayzata, Minn.) is amphiphilic and can allow for increasing content of one or more inorganic fillers of a composite material.', 'Where DILULIN™ material is mentioned, a functionalized linseed oil other than that marketed as DILULIN™ may optionally be utilized.', 'The PubChem open chemistry database lists the following information for “Dilulin”: \n \n \n \nPubChem CID: 102162842\n \nMolecular Formula: C\n62\nH\n106\nO\n6 \n \nMolecular Weight:', '947.50144 g/mol\n \nInChl Key: CFMHDZMTXRKWMC-PUJZDUKBSA-N\n \n \n \n \n \nDilulin has an IUPAC name as follows: “[3-[(Z)-octadec-9-enoyl]oxy-2-[8-[3-[(2Z,5Z)-octa-2,5-dienyl]-2-bicyclo[2.2.1]hept-5-enyl]octanoyloxy]propyl] (Z)-octadec-9-enoate”.', 'As to linseed oil, which is a triglyceride, it includes a triester (triglyceride) derived of linoleic acid, alpha-linolenic acid, and oleic acid.', 'As an example, Dilulin or DILULIN™ material may be a modified linseed oil.', 'As an example, a polymeric material can be thermally conductive and electrically insulative and be utilized to encapsulate windings of an electric motor.', 'Such an approach may provide for lower winding temperatures and end coil temperatures through heat dissipation.', 'An electric motor may include a coil retention system such as, for example, a full winding encapsulation type, a varnished windings type, or an end coil retention type (e.g., one that does not support wires in slots).', 'As an example, a glass-fiber tape can be included in a coil retention system where, for example, the glass-fiber tape is wrapped around end turns and where the glass-fiber tape is impregnated with a crosslinking resin.', 'As an example, an encapsulation technique can depend on the type of coil retention system employed.', 'For example, the use of a thermosetting polymer can depend on the type of coil retention system.', 'An encapsulated system can involve use of one or more materials and one or more particular processes.', 'As an example, varnished windings approach can include use of a solvent-based polybutadiene system, which tends to be more elastomeric than structural.', 'An end coil retention resin can be a silica-filled epoxy, which has suitable structural properties due in part to the fact that the end coil retention provides coil stabilization while holding the end turns and while not supporting wires in the slots.', 'As an example, to maintain mechanical robustness of magnet wire wrapped in a stator of an electric motor, insulated motor windings may use a coil retention system where at least ends of coils are held in place by a structural composite that includes fibrous reinforcement (e.g., one or more of glass, quartz, aramid, etc.) and an organic and/or inorganic polymer matrix.', 'As to dielectric fluids (e.g., motor oils, etc.), consider as examples one or more of purified mineral oils, polyalphaolefin (PAO) synthetic oils, PFPE (polyperfluoroether), etc.', 'Such dielectric fluids can be relatively resistance to well fluid(s), which can thereby allow an electric motor to function in case of leakage well fluid.', 'FIG.', '7\n shows an example of an electric motor \n710\n, an example of a photograph of a portion of an electric motor \n770\n and a photograph \n780\n of a portion of an electric motor.', 'As shown in \nFIG.', '7\n, the electric motor \n710\n includes a housing \n720\n with threads \n722\n.', 'Lead wires (e.g., brush wires) \n732\n are shown where a number of such wires can correspond to a number of phases.', 'For example, for a three phase electric motor, there can be three lead wires \n732\n (e.g., two being shown in the cutaway view).', 'The lead wires \n732\n can be associated with a top or uphole end of an electric motor; whereas, at a bottom or downhole end, a wye point may exist where phases are electrically coupled.', 'As an example, a wye point may be electrically coupled to one or more other components such as, for example, a gauge (e.g., a sensor unit, etc.).', 'As shown in the example of \nFIG.', '7\n, the lead wires \n732\n are electrically coupled to phase windings or phase coils where ends of the windings or coils \n734\n can extend downward through slots \n727\n in laminations \n725\n.', 'As shown in the example of \nFIG.', '7\n, a polymeric material \n742\n, which may optionally be a polymeric composite material (e.g., polymeric material that includes one or more fillers) contacts the ends of the windings or coils \n734\n and a portion of the polymeric material \n742\n extends downwardly through the slots \n727\n in the laminations \n725\n.', 'In the example of \nFIG.', '7\n, a molding insert may be utilized to contain the polymeric material \n742\n (e.g. encapsulant material) during curing of the polymeric material (e.g., where reactions occur involving at least in part monomers, etc.).', 'As an example, a method can include an injection process for injecting the polymeric material \n742\n into a cavity of the housing \n720\n to contact ends of windings or coils (e.g., of magnet wire), a molding process for molding the polymeric material \n742\n about the ends of the windings or coils in a manner to not interfere with other components of an electric motor (e.g., to create a shaft space and/or rotor space, etc.), an assembly process for assembling an electric motor \n710\n that includes the stator disposed in the housing \n720\n and an assembly process for assembly of a downhole tool that can utilize the electric motor \n710\n (e.g., an ESP, etc.).', 'As an example, an electric motor of an ESP may have a substantially cylindrical shape with a diameter of about 18 cm and an axial length of about 10 m. In such an example, a volume of encapsulant may be of the order of tens of liters.', 'As an example, for an electric motor of another type of downhole tool, a volume may be in a range where a lower limit of the range is of the order of milliliters.', 'As an example, a downhole tool may be a wireline tool.', 'As an example, a downhole tool may be a completions tool.', 'As an example, a downhole tool can include an electric motor that has a substantially cylindrical shape.', 'In such an example, consider, as an example, a total volume of about 350 milliliters, a length of about 12 cm and a diameter of about 5 cm.', 'Of the total volume, a fraction thereof can be encapsulant (e.g., an encapsulant volume of the order of tens of milliliters).', 'In the example of \nFIG.', '7\n, the photograph \n770\n shows a portion of an electric motor where resin is applied to glass fabric for the lower portion of the windings shown in the photograph \n770\n (e.g., upper portion shows the glass fabric without the resin).', 'As an example, windings can be held in place by a polymeric material (e.g., optionally a polymeric composite material) that completely encapsulates end turns and that fills slots.', 'In such an example, air voids may be substantially removed through use of vacuum impregnation and degassing while prepolymer is heated to a low viscosity prior to gelation.', 'Thermally conductive encapsulants can improve reliability of ESP systems by decreasing motor winding temperatures.', 'Applications can include SAGD, subsea, geothermal, etc.', 'Such materials may be suitable for use in equipment for drilling and measurement operations (e.g., D&M).', 'In the example of \nFIG.', '7\n, the photograph \n780\n of an example of a portion of a product (e.g., a portion of an example of a stator).', 'In particular, the photograph \n780\n shows a lamination \n781\n that includes a slot \n782\n where slot liner material \n783\n defines an interior space such that the slot liner material \n783\n surrounds magnet wire \n792\n that includes insulation \n791\n.', 'As shown in the photograph \n780\n, polymeric material \n793\n, which may be polymeric composite material, is disposed exteriorly and interiorly with respect to the slot liner material \n783\n.', 'As an example, the insulation \n791\n can be of the order of about 0.1 mm to about 0.3 mm.', 'As an example, the slot liner material \n783\n can be a polymeric film that may be of one or more layers where a layer of the film may be of the order of about 0.1 mm to about 0.3 mm.', 'As shown, the polymeric material \n793\n can at least partially fill spaces defined by the slot \n782\n of the lamination \n781\n.', 'As an example, an individual plate may be formed of carbon steel with an oxide coating where a plurality of such plates can be stacked to form the laminations.', 'As an example, heat energy generated during operation of an electric motor that includes the stator of the photograph \n780\n may be transferred to the polymeric material \n793\n.', 'For example, current in the magnet wire \n792\n can generate heat due at least in part to resistance of the magnet wire \n792\n.', 'As the polymeric material \n793\n is in contact with the magnet wire \n792\n (e.g., via the electrical insulation \n791\n) it can conduct at least a portion of the heat energy away from the magnet wire \n792\n, noting that resistance of the magnet wire \n792\n may depend on temperature (e.g., consider a wire where resistance increases with temperature or, in other words, where the wire becomes less efficient as temperature increases).', 'As an example, insulation may include one layer or multiple layers of a high temperature polymeric dielectric material.', 'As an example, polymeric insulating material may be in the form of tape that may be applied helically or longitudinally (e.g., by wrapping polyimide tape onto a conductor in an overlap configuration).', 'As an example, a polymeric insulating material may be extruded.', 'As mentioned, water can degrade various types of polymeric materials.', 'For example, water phases at high temperatures (e.g. SAGD) and pressures can rapidly degrade polyimides and thereby reduce mean time between failures (MTBF) of equipment.', 'Environments that include H\n2\nS and water can degrade materials.', 'For example, sour high-pressure conditions where H\n2\nS and water are present, polymer insulation degradation may occur at a relatively rapid rate.', 'As an example, one or more methods can be utilized to manufacture insulated conductors that exhibit resistance to water, steam, gas, etc., which may thereby impart reliability and/or usability in particular environments.', 'As an example, a polymeric material can be a polyaryletherketone (PAEK) family polymer-based material such as, for example, polyetheretherketone (PEEK).', 'As an example, a polymeric material can be a fluoropolymer-based material.', 'As an example, consider one or more fluoroelastomers such as, for example, fluoroelastomers abbreviated as FKMs.', 'FKM (FPM by ISO) is a designation for about 80 percent of fluoroelastomers as defined in ASTM D1418.', 'FKMs may exhibit heat and fluid resistance.', 'For example, in FKMs, bonds between carbon atoms of the polymer backbone and attached (pendant) fluorine atoms tend to be resistant to chain scission and relatively high fluorine-to-hydrogen ratios can provide stability (e.g., reduced risk of reactions or environmental breakdown).', 'Further, FKMs tend to include a carbon backbone that is saturated (e.g., lacking covalent double bonds, which may be attack sites).', 'Elastomers such as one or more of the VITON™ class of FKM elastomers (E. I. du Pont de Nemours & Co., Wilmington, Del.) may be used (e.g., VITON™', 'A, VITON™ B, VITON™ F, VITON™ GF, VITON™ GLT, VITON™ GFLT, etc.).', 'As an example, a polymeric material may be a thermoplastic material.', 'For example, consider a poly-aryl ether ketone (e.g., PEK, PEEK, PEKEKK, etc.), a melt extrudable fluoropolymer (e.g., ethylene tetrafluoroethylene (ETFE), polyvinylidene fluoride (PVDF), fluorinated ethylene propylene (FEP), perfluoroalkoxy (PFA), epitaxial co-crystaline alloy (ECA) fluoroplastic, etc.), or other suitable material.', 'As an example, polyether ether ketone (PEEK) may be utilized as a polymeric material.', 'As an example, polytetrafluoroethylene (PTFE) may be utilized as a polymeric material.', 'As an example, a composition may be or include a commercially available DuPont™ ECCtreme® ECA 3000 fluoroplastic resin (DuPont Chemicals and Fluoroproducts, Wilmington Del.).', 'As an example, such a resin may be a perfluoropolymer mixture (PFP) that may be heat aged to become an ECC PFP.', 'As an example, a polymeric material can include epitaxial co-crystals of perfluoroalkoxy (PFA) and polytetrafluoroethylene (PTFE).', 'As an example, perfluoroalkoxy (PFA) can be a polymer of tetrafluoroethylene and perfluorovinylether.', 'As an example, a polymeric material may be classified based on temperature.', 'For example, a low-temperature class may include materials such as polypropylene (PP), co-polymers of PP and polyethylene (PE), ETFE, PVDF, etc.; and, for example, a mid-temperature class may include materials such as FEP, PFA, etc.', 'As an example, a high-temperature class may include materials that can withstand temperatures greater than approximately 260 degrees C. (e.g., approximately 500 degrees F.).', 'As an example, PEEK and ECA may function as insulators at temperatures in excess of approximately 260 degrees C. (e.g., approximately 500 degrees F.).', 'As an example, a material can be a PEEK/fluoropolymer composite material.', 'Such a material may be suitable for high temperature downhole applications.', 'For high temperature and pressure applications in harsh environment as in downhole oil industry, PEEK finds use as an insulation material, such as in high temperature cables and motor lead extensions (MLEs).', 'As an example, a PEEK-based cable may be rated for temperatures up to about 260 degrees C. in the presence of corrosive fluids and gases, such as hydrogen sulfide (H\n2\nS) and carbon dioxide (CO\n2\n).', 'The crystalline structure of PEEK can be developed at temperatures above the glass transition temperature (Tg) and below the melting point.', 'The crystallinity of PEEK may increase during service time in a manner that depends on one or more conditions (e.g., temperature, etc.).', 'As an example, an increase in crystallinity of PEEK during operation may lead to an increase in stiffness and a decrease in toughness.', 'Cracks may form in PEEK insulation material after some amount of operation time, for example, under mechanical stress.', 'Under hot/wet conditions, PEEK can adsorb some amount of humidity, which can negatively impact dielectric strength, which may allow for arc tracking and consequently high electrical test failure rates in a manufacturing process.', 'Therefore, a process may aim to develop the structure of PEEK material to make it tougher and more water resistant under expected operational conditions.', 'As an example, a material can be formed by blending PEEK with one or more selected fluoropolymers.', 'For example, consider one or more of polytetrafluoroethylene (PTFE) and perfluoroalkoxy copolymer (PFA).', 'As an example, one or more fillers may be electrically insulative (e.g., relatively non-conductive).', 'As an example, consider silica, which is a group IV metal oxide, which has good abrasion resistance, electrical insulation and high thermal stability.', 'It is insoluble in acid with the exception of hydrogen fluoride (HF).', 'As an example, a filler may be or include ceramic grade sand, which may be less than about 75 microns in particle size with a silica content above about 97.5 percent where additional material may include less than about 0.55 percent alumina (Al\n2\nO\n3\n) and less than about 0.2 ferric oxide (Fe\n2\nO\n3\n).', 'As an example, one or more fillers may include silica and/or alumina and/or one or more other materials.', 'As an example, thermal conductivity of a PEEK/PTFE blend and/or a PEEK/PFA blend may be enhanced via addition of one or more types of thermally conductive ceramic fillers.', 'For example, consider one or more of silica, alumina and boron nitride.', 'As an example, inclusion of PFA and PTFE may improve toughness and water resistance of PEEK, while a ceramic filler or fillers can improve thermal conductivity, which can offer opportunities to decrease operational temperatures (e.g., via improved heat transfer), which, in turn, may help to prevent overheating (e.g., or reduce time-temperature area experienced during operation).', 'As an example, consider an MLE or MLEs that are utilized in an operation where space constraints may exist in a downhole environment.', 'In such an example, reducing ampacity of a cable can be desirable as it can help to increase current carrying capacity for a given geometry.', 'As an example, a composite material that includes PEEK, fluoropolymer and thermally conductive filler may be utilized in one or more pieces of equipment such as, for example, cables, MLEs, magnet wires, and slot liners.', 'As mentioned, various materials can experience issues during operation at high temperature and pressure in a wet environment.', 'For example, a high temperature above Tg and below the melting point can induce crystallization of PEEK.', 'Increasing the percentage of crystallinity of PEEK during service time at high temperature can have a negative impact on the mechanical properties and performance of PEEK insulation materials.', 'Stiffness can also increase and consequently such material can become more brittle (e.g., more readily generate cracks under mechanical stress).', 'Where such phenomena occur, failure rate may be expected to increase.', 'Further, as mentioned, PEEK can adsorb humidity when utilized at high temperature in a wet environment.', 'Adsorbed humidity can reduce the breakdown voltage, increase dielectric constant, and may allow for arc tracking that may result in electrical failure.', 'As an example, a composite material can include PEEK, another polymeric material and optionally one or more fillers where the crystallization behavior of PEEK may be mediated and/or PEEK may be improved as to its toughness under operation at high temperature.', 'As an example, such a composite material may include or may be shielded by one or more materials that can counter the effects of humidity.', 'As an example, a method can include mixing PEEK with PFA or PTFE flouropolymers to produce a compatible blend with improved mechanical properties as well as water resistance.', 'PFA and PTFE tend to be high performance flouropolymers with high dielectric strength, low dissipation factor, chemical inertness, high hydrophobicity, and corrosion resistance.', 'Favorable interaction between PEEK and PFA or PTFE can help to inhibit the crystallization process of PEEK at high temperature, for example, as may be experienced during service time of a component that includes such a blend.', 'As an example, PFA and/or PTFE can impart elasticity to PEEK and, for example, increase toughness.', 'As an example, PEEK may be a graded PEEK.', 'For example, consider a medium viscosity grade PEEK.', 'As an example, PEEK 381 may be utilized (see, e.g., VICTREX™ PEEK 381G, etc.).', 'As an example, PEEK can have a melting point of about 340 degrees C. (e.g., about 343 degrees C.).', 'As an example, PEEK can have a glass transition temperature (Tg) of about 140 degrees C. (e.g., about 143 degrees C.).', 'As an example, PEEK may have a thermal conductivity of about 0.3 W/m-k. As an example, PEEK may have a melt viscosity of about 300 Pa·s at a temperature of about 400 degrees C. As an example, PEEK may have a dielectric constant of about 3 (e.g., about 3.2 at about 23 degrees C. and about 50 Hz).', 'As an example, PFA may be a graded PFA.', 'For example, consider a medium viscosity grade PFA.', 'As an example, PFA 345 may be utilized (see, e.g., TEFLON™ PFA 345, etc.).', 'As an example, PFA can have a melting point of about 300 degrees C. (e.g., about 305 degrees C.).', 'As an example, PFA may have a thermal conductivity of about 0.2 W/m-k. As an example, PFA may have a dielectric constant of about 2 (e.g., about 2.1 short term about 60 Hz to about 1 GHz).', 'As to dielectric constant, per the theory of permittivity, in a frequency domain, the complex relative permittivity ε* of a material to that of free space may be expressed as ε*=ε′−jε″ where the real part ε′ is referred to as the dielectric constant and represents stored energy when the material is exposed to an electric field while the dielectric loss factor ε″ is the imaginary part, which influences energy absorption and attenuation and where j=(−1)\n0.5\n.', 'Another parameter in electro-magnetic theory is the tangent of loss angle, tan δ, which is equal to the ratio of the dielectric loss factor to the dielectric constant.', 'As an example, air can have a dielectric constant of about 1 at a given frequency and temperature and can have an electrical conductivity of about 0 while distilled/deionized water can have a dielectric constant of about 80 (e.g., 27 MHz to about 915 MHz) and an electrical conductivity of about 0.01 S/m; whereas, 0.05 percent salt water can have an electrical conductivity of about 3.25 S/m, which increases to about 173 S/m at a salt concentration of about 1 percent.', 'In dielectric materials, the electric field strength decreases with distance z from the surface and may be estimated as follows: E=E\n0\ne\n−αz \nwhere α is an attenuation factor that depends on the dielectric properties of the material, which can depend on the free-space wavelength, λ\n0\n.', 'The temperature of a material has an effect on dielectric properties.', 'For example, in some types of materials (e.g., fluids, etc.) loss factor can increase with increasing temperature at low frequencies due to ionic conductance and can decrease with increasing temperature at high frequencies due to free water dispersion.', 'As an example, a material may be semi-conductive or a semiconductor.', 'As an example, a semiconductor can be a solid substance that exhibits conductivity between that of an insulator and that of an electrically conductive metal, for example, due to addition of an impurity, impurities or particles and/or due to one or more types of temperature effects.', 'As an example, a thermoplastic blend of PEEK/PFA may include a filler or fillers that can provide semi-conductive character.', 'As an example, a thermoplastic blend of PEEK/PFA may include a filler or fillers that can be thermally conductive.', 'As an example, a thermoplastic blend of PEEK/PFA may include a filler or fillers that can be thermally conductive and optionally provide one or more other types of character.', 'As an example, a filler or fillers may be electrically insulative and optionally provide one or more other desirable properties (e.g., electrically insulative and thermally conductive).', 'As an example, a thermally conductive composite material may be prepared by mixing a blend of PEEK/PFA, a blend of PEEK/PTFE or a blend of PEEK/PFA/PTFE with an amount of thermally conductive filler or fillers (e.g. silica, alumina, boron nitride, or mixture of them).', 'As an example, a thermally conductive fillers can help to reduce risk and/or time profile of overheating and may, for example, help to decrease the operation temperature.', 'As an example, a thermally conductive composite of PEEK/PFA/ceramic, PEEK/PTFE/ceramic, or PEEK/PFA/PTFE/ceramic can be tailored for a particular application or applications (e.g., ESP cables, MLEs, magnet wires, and slot liner).', 'Such an approach may aim to retain properties of PEEK while mediating drawbacks as may be associated with post crystallization, increase stiffness, decrease toughness during operation at high temperature, etc.', 'As an example, a polymeric composite material can be obtained through use of a polymer matrix filled with one or more types of particulate fillers.', 'As an example, particulate filler may be or include aluminum oxide, aluminum nitride, boron nitride, silicon nitride and/or beryllium oxide.', 'Examples of some types of fillers and properties are presented in Table 2, below.', 'TABLE 2\n \n \n \n \n \n \n \n \nExamples of thermally conductive/electrically insulative fillers.', 'Properties\n \nBN\n \nAIN\n \nAl\n2\nO\n3\n \nSiO\n2\n \nZnO\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nThermal Conductivity\n \n\u2002300+\n \n260\n \n30\n \n1.4\n \n54\n \n \n \n(W/m-K)\n \n \n \n \n \n \n \n \nSpecific Heat\n \n794\n \n734\n \n798\n \n689\n \n523\n \n \n \n(J/kg-K) @ 25 C.\n \n \n \n \n \n \n \n \nDensity\n \n\u2003\u2003\u20092.25\n \n3.26\n \n3.98\n \n2.20\n \n5.64', 'In Table 2, the example fillers tend to have relatively high levels of thermal conductivity while still having relatively high dielectric strengths.', 'As to shapes of fillers, alumina may be relatively spherical with a relatively low surface area while boron nitride may be plate-like; though boron nitride may be provided in a more spherical shape as an agglomerate (e.g., a spherical agglomerate).', 'As an example, silica may be of a more irregular shape than alumina.', 'As an example, alumina may be of a particle size or sizes (e.g., 80 percent of particles or mean particle size D50) that are in a range from about one micron to about 200 microns.', 'As an example, surface area of alumina may be less than about 0.9 m\n2 \nper gram.', 'As an example, boron nitride may be particulate with a particle size or sizes (e.g., 80 percent of particles or mean particle size D50) that are in a range from about 1 micron to about 500 microns.', 'Such particles may include boron nitride crystals sized from about 1 micron to about 30 microns.', 'As an example, boron nitride particles may of a surface area less than about 100 m\n2 \nper gram.', 'As an example, boron nitride particles may be of a dielectric constant of about 2 to about 5.', 'As an example, boron nitride particles may be of a thermal conductivity of about 10 to 300 or more (W/m-K).', 'As an example, a polymeric composite material can include alumina and boron nitride and may be relatively free of silica (e.g., less than about 1 percent of silica, less than about 0.5 percent silica, less than about 0.1 percent silica).', 'As an example, a polymeric composite material can include a filler that is plate-like in shape and a filler that is substantially spherical in shape where the two fillers may be dispersed in a polymeric matrix.', 'In such an example, a ratio of the two fillers may be adjusted.', 'As an example, flow dynamics and/or properties of a polymeric composite material may be tailored by use of differently shaped particles (e.g., of one or more fillers) and/or differently sized particles (e.g., of one or more fillers).', 'As an example, alumina may be present in a polymeric composite material at a volume percent up to about 65 percent of total volume of the polymeric composite material.', 'As an example, boron nitride may be present in a polymeric composite material at a volume percent up to about 65 percent of total volume of the polymeric composite material.', 'As an example, alumina and boron nitride may be present in a polymeric composite material at a volume percent up to about 65 percent of total volume of the polymeric composite material.', 'As an example, boron nitride may be present in a polymeric composite material at a volume percent up to about 40 percent of total volume of the polymeric composite material.', 'In such an example, the polymeric composite material may also include alumina.', 'As an example, where boron nitride is present in a polymeric composite material, it may be present at a volume percent of about 0.5 percent or more of total volume of the polymeric composite material (e.g., in a range from about 0.5 percent to about 40 percent).', 'FIG.', '8\n shows an example method \n810\n and an example method \n850\n.', 'As shown, the method \n810\n includes a provision block \n812\n for providing PEEK and one or more fluoropolymers, an optionally provision block \n814\n for providing one or more fillers, a mix block \n816\n for mixing provided materials and a formation block \n818\n for forming a component based at least in part on the mixtures of provided materials.', 'As shown, the method \n850\n includes a provision block \n852\n for providing polymeric material, a provision block \n854\n for providing one or more fillers, a mix block \n856\n for mixing provided materials and a formation block \n858\n for forming a component based at least in part on the mixtures of provided materials.', 'As shown, the method \n810\n can include providing thermoplastic material(s) and the method \n850\n can include providing thermoset material(s).', 'As an example, a component formed by the method \n810\n may be an insulation material, for example, suitable to insulate a conductor or conductors.', 'As an example, a component formed by the method \n850\n may be an encapsulant such as, for example, an encapsulant for a submersible electrical unit (e.g., a submersible electric motor).', 'Various example plots are shown in \nFIGS.', '9\n to \n15\n that can correspond to a method such as the method \n810\n of \nFIG.', '8\n and various example plots are shown in \nFIGS.', '16\n to \n24\n that can correspond to a method such as the method \n850\n of \nFIG.', '8\n.', 'FIG.', '9\n shows an example of a plot \n900\n that includes data as to angular frequency dependence of complex viscosity for PEEK and PFA at about 370 degrees C.\n \nAs an example, PEEK and PFA with one or more ceramic fillers may be mixed and melt extruded at high temperature and shear rate.', 'In such an example, viscosity of one or more components, particularly the thermoplastic ones (PEEK and PFA) at the processing temperature (e.g. about 370 degrees C.), can be relevant to processing.', 'As seen in the plot \n900\n of \nFIG.', '9\n, data for angular frequency dependence of complex viscosity for PEEK and PFA at about 370 degrees C. indicated presence of a linear viscoelastic regime.', 'In the plot \n900\n, markers indicate data while lines are calculated from a Cross Model:\n \n \n \n \n \n \nη\n \n*\n \n \n=\n \n \n \nη\n \n0\n \n \n \n1\n \n+\n \n \n \n(\n \n \nω\n \n/\n \n \nω\n \nc\n \n \n \n)\n \n \nβ\n \n \n \n \n \n \n \n where η\no \nis zero shear viscosity, ω\nc \nis critical shear frequency and β is a material constant.', 'In the plot \n900\n, both components exhibit Newtonian behavior and shear thinning at low and high angular frequency, respectively.', 'The viscosity of PEEK is higher than that of PFA at lower angular frequency and both of them are about the same at about 30 rad/s. Based on such information, a process can provide for compatibility via blending PEEK and PFA at about 370 degrees C. under shear force, particularly when the viscosity ratio is about one.\n \nFIG.', '10\n shows an example plot \n1000\n of data for temperature dependence of storage modulus and tan δ for PEEK/PFA blends.', 'In \nFIG. \n10\n, the temperature dependence of storage modulus and tan δ for different PEEK/PFA blends is provided based on DMA data.', 'The data indicate one glass relaxation process for blends with PFA content at about 50 percent by weight or more, which is an indication of suitable compatibility.', 'Further, two relaxation processes can be observed for a PEEK/PFA 25/75 blend (e.g., macroscopic phase separation).', 'Yet further, it can be observed that the storage modulus of the PEEK/PFA 75/25 blend is higher than the pure components at low temperature range.', 'The phase separated blends (PEEK/PFA 25/75) tend to relatively low storage modulus.', 'Based on the data in \nFIG.', '10\n, the PEEK/PFA 75/25 blend may be suitable for use as a polymeric material and/or as a polymeric matrix, optionally as a polymeric matrix for a composite material.', 'For example, as a composite material, one or more fillers may be included and dispersed within the polymeric matrix.', 'As an example, a filler or fillers may provide semi-conductive character and/or improve thermal conductivity.\n \nFIGS. \n11\n and \n12\n show plots \n1100\n and \n1200\n, respectively.', 'The plot \n1100\n shows DSC thermograms for PEEK/PFA blends and the plot \n1200\n shows melting enthalpies of PEEK-rich and PFA-rich phases of the PEEK/PFA blends.', 'The melting behavior of both PEEK and PFA were also developed considerably by blending.', 'The melting peak of PFA is lower than that of PEEK and systematically shifted to higher temperature with increasing the concentration of PEEK (see the plot \n1100\n of \nFIG.', '11\n).', 'However, the melting temperature of PEEK does not change by blending.', 'Thus, two rich phases exist where the percentage of PEEK dissolved in the PFA-rich phase is higher than the percentage of PFA dissolved in the PEEK-rich phase.', 'The melting enthalpy calculated from the endothermic melting peaks of PEEK-rich and PFA-rich phases were linearly changed with composition as seen in the plot \n1200\n of \nFIG.', '12\n.', 'The data of the plots \n1100\n and \n1200\n indicates suitable compatibility of the various PEEK/PFA blends.\n \nFIGS. \n13\n and \n14\n shows plots \n1300\n and \n1400\n where the plot \n1300\n shows temperature dependence of dielectric constant for PEEK/PFA blends and where the plot \n1400\n shows temperature dependence of dielectric tan δ for PEEK/PFA blends.', 'As shown in the plots \n1300\n and \n1400\n, dielectric properties of the PEEK/PFA blends improved with increasing PFA concentration.', 'The plot \n1300\n shows the dielectric constant versus temperature for different blend compositions where the dielectric constant decreased with increasing PFA content.', 'As shown in the plot \n1400\n, the dielectric dissipation factor, tan δ, also decreased systematically with increasing the concentration of PFA.', 'An increase in the resistivity with increasing PFA over wide range of temperature was also observed.', 'As shown in the plot \n1300\n at temperatures greater than about 200 degrees C., increasing content of PFA lowers the dielectric constant (e.g., relative permittivity).', 'In particular, at temperatures of about 215 degrees C. and higher, PEEK (e.g., greater than about 99 percent PEEK) exhibits a dielectric constant that increases dramatically with temperature.', 'As shown, PFA can reduce that effect such that a dielectric constant may be relatively assured to not exceed about 10 at a temperature of about 250 degrees C. In such an example, a blend can substantially maintain structural properties of PEEK while assuring a lack of runaway with respect to dielectric constant with respect to temperature.', 'As mentioned, one or more types of ceramic fillers may be included in a polymeric blend to improve thermal conductivity of a composite material.\n \nFIG.', '15\n shows a plot \n1500\n of data for a PEEK/PFA 75/25 blend.', 'Specifically, the data show the effect of different thermally conductive fillers on the thermomechanical properties.', 'As seen in \nFIG.', '15\n, the Tg of the PEEK/PFA 75/25 blend does not change noticeably with addition of about 25 percent by weight of the different thermally conductive fillers, which are alumina, silica, and boron nitride (BN).', 'The data indicate that the storage modulus increased by adding the different fillers and that the magnitude of the elevation was found to be a maximum for BN when compared to alumina and silica.', 'As an example, a method can include tailoring the concentration of one or more thermally conductive fillers to achieve a desired thermal conductivity, which may account for stiffness, for example, to include an amount that does not appreciably increase stiffness.', 'As an example, a method can include utilizing one or more surface treatments.', 'For example, one or more fillers can be surface treated by one or more techniques such as, for example, plasma, electron beam, chemical functionalization, etc.', 'As an example, a composite material can be thermally stable after accelerated aging.', 'For example, a composite material was aged at about 225 degrees C. in REDA oil #5 and about 0.1 weight percent water under nitrogen gas at about 1500 psi.', 'DMA data for PEEK/PTFE blends before and after accelerated aging process for 7 and 14 days indicated that Tg remained substantially the same after aging and that a slight increase in the storage modulus occurred, particularly above the Tg.', 'As an example, a PEEK/fluoropolymer composite material can be thermally stable and exhibit suitable mechanical, thermal, and dielectric properties.', 'Such a composite material can also exhibit water resistance, corrosion resistance, and relatively high thermal conductivity.', 'As an example, such a composite material may be utilized in a cable, a MLE, magnet wire, a slot liner or another component or components that may be used in a downhole environment, etc.', 'As an example, a polymeric composite material can include PEEK and one or more fluoropolymers and, for example, one or more fillers.', 'In such an example, one or more fillers may be selected to be in a total amount by weight of the polymeric composite material.', 'For example, consider a selected total amount that is in a range from about 1 percent by weight to about 40 percent by weight of a polymeric composite material.', 'As an example, consider a selected total amount that is in a range from about 2 percent by weight to about 30 percent by weight of a polymeric composite material.', 'As an example, consider a selected total amount that is in a range from about 5 percent by weight to about 25 percent by weight of a polymeric composite material.', 'As an example, a filler may be selected from a group of alumina, silica and boron nitride.', 'As an example, a filler may be selected from a group of alumina and boron nitride.', 'As an example, a filler may be selected from a group of alumina and silica.', 'As an example, a filler may be selected from a group of silica and boron nitride.', 'As an example, a polymeric composite material can include PEEK and one or more fluoropolymers and optionally, for example, one or more fillers.', 'In such an example, the one or more fluoropolymers may be present at at least approximately 5 percent by weight.', 'As an example, a polymeric composite material that includes PEEK may include ingredients that extend an operational temperature range beyond that of a polymeric material that is 99 percent by weight or more PEEK.', 'For example, such a polymeric composite material may have an operational temperature range that extends to temperatures above about 200 degrees C. where, for example, structural aspects of PEEK are substantially retained.', 'As an example, consider an operational temperature range that extends to about 260 degrees C.\n \nAs an example, a polymeric composite material can include PEEK up to about 50 percent by weight, can include PFA up to about 50 percent by weight and can include one or more fillers up to about 30 percent by weight.', 'Such a polymeric composite material may be utilized in one or more types of electrical units that may be submersible electrical units.', 'As an example, a submersible electrical unit can be a submersible electric motor.', 'As an example, a submersible electric motor can be a relatively high amperage electric motor that can benefit from inclusion of a polymeric composite material that includes one or more fillers that increase the thermal conductivity of a polymeric matrix within which the one or more fillers are dispersed.', 'As an example, a polymeric material can include about 5 percent or more by weight of PFA.', 'For example, such a polymeric material can include PEEK and at least approximately 5 percent by weight PFA.', 'In such an example, the polymeric material may be a polymeric composite material that includes one or more fillers.', 'In such an example, as an example, the weight of the PFA may be at least approximately 5 percent.', 'As an example, a polymeric composite material can include PEEK up to about 50 percent by weight, can include PFA from about 5 percent by weight up to about 50 percent by weight and can optionally include one or more fillers up to about 30 percent by weight.', 'As an example, a polymeric material can include PEEK and PFA, PEEK and PTFE or PEEK, PFA and PTFE.', 'As an example, a method can include providing medium viscosity grades of one or more polymers (e.g., PEEK, PFA, PTFE, etc.).', 'As an example, such grades may correspond to medium molecular weight.', 'As an example, PEEK and PFA and/or PTFE with thermally conductive ceramic fillers may be mixed and melt extruded at an appropriate temperature and shear rate.', 'In such an example, viscosity of the components, particularly the thermoplastic ones (PEEK and PFA), can effect processing.', 'As an example, a polymeric composite can include one or more thermally conductive fillers.', 'For example, such a composite can include two or more different types of thermally conductive fillers, which can be different filler materials.', 'For example, consider a polymeric composite material that includes one or more of alumina, silica and boron nitride (BN).', 'As an example, a polymeric composite material may be utilized as an encapsulant (e.g., an encapsulant material) for an electric motor, which may be, for example, a submersible electric motor (e.g., of an ESP).', 'As an example, a thermally conductive polymer composite material can be of suitable mechanical and dielectric properties to encapsulate portions of an electric motor (e.g., electric motor stator, etc.).', 'As an example, a thermally conductive encapsulant may provide for dielectric insulation, mechanical protection, reduced operating temperature and overheating mitigation of an ESP motor.', 'As an example, such an encapsulant may be utilized to help protects a slot liner and/or magnet wire insulation material from thermal and/or hydrolytic degradation.', 'As an example, a thermally conductive composite material may include one or more different types of polymeric matrices.', 'As an example, a polymeric matrix may be an epoxy resin matrix.', 'Epoxy resins, also known as polyepoxides are a class of reactive prepolymers and polymers which contain epoxide groups.', 'As an example, a polymeric matrix may be formed at least in part via a ring-opening metathesis polymerization (ROMP), which is a type of olefin metathesis chain-growth polymerization.', 'Such reactions can be driven by relief of ring strain in cyclic olefins (e.g. norbornene, cyclopentene, etc.).', 'A catalyst that may be used in a ROMP reaction can include a metal, for example, consider a RuCl\n3\n/alcohol mixture, a catalyst, etc.', 'As an example, a catalyst can be a transition metal carbene complex.', 'For example, consider benzylidene-bis(tricyclohexylphosphine)-dichlororuthenium, [1,3-bis-(2,4,6-trim ethyl phenyl)-2-imidazolidinylidene]dichloro(phenylmethylene)(tricyclohexylphosphine)ruthenium, Dichloro(o-isopropoxyphenylmethylene)(tricyclohexylphosphine)ruthenium(II), and [1,3-Bis-(2,4,6-trimethylphenyl)-2-imidazolidinylidene]dichloro(o-isopropoxyphenylmethylene)ruthenium.', 'As an example, a polymer may be formed at least in part via ROMP.', 'For example, as a prepolymer component amenable to forming a polymer via ROMP, consider a carbon backbone with functional groups that include at least one oxygen that provides an amount of hydrophilicity may be present along with a hydrocarbon chain (e.g., carbon backbone) that provides an amount of hydrophobicity where at least one functional group may be present on the hydrophobic hydrocarbon chain where such a functional group may participate in ROMP (e.g., via relief of ring stress).', 'In such an example, the prepolymer component may be an ester such as a diester, a triester, etc. (e.g., an n-ester).', 'As an example, consider a triester that includes at least one hydrocarbon chain with a functional group that includes a ring that is amenable to ROMP via relief of ring stress.', 'As mentioned, a ROMP process can employ a catalyst that can include a metal (e.g., Ru, etc.).', 'As an example, a ROMP process may be utilized to form a copolymer (e.g., via two monomers, three monomers, etc.).', 'For example, consider a scheme for forming a copolymer utilizing a functionalized triester as one of the monomers.', 'As an example, DILULIN™ material (Cargill Inc., Minneapolis, Minn.) may be utilized, which is a mixture of norbornyl-functionalized linseed oil and cyclopentadiene (CPD) oligomers (e.g., one fraction of modified linseed oil at about 70 percent by weight and another of cyclopentadiene (CPD) oligomers at about 30 percent by weight).', 'In such an example, the norbornene groups are ROMP-reactive.', 'In such a scheme, one or more additional materials can be included such as, for example, one or more of dicyclopentadiene (DCPD) and ethylidenenorbornene (ENB) (e.g., to form a copolymer, which may be a terpolymer, etc.).', 'At room temperature, DCPD is a white crystalline solid.', 'Norbornene is a bridged cyclic hydrocarbon that can be provided as a white solid.', 'Norbornene includes a cyclohexene ring with a methylene bridge between C-3 and C-6; it carries a double bond which induces ring strain.', 'ENB is a bicyclic monomer and intermediate that includes two double bonds, each with a different reactivity.', 'ENB can be produced from vinyl norbornene, which can be made from butadiene and dicyclopentadiene DCPD.', 'The PubChem open chemistry database lists the following information for DCPD: \n \n \n \nPubChem CID: 6492\n \nChemical Names: DICYCLOPENTADIENE; 77-73-6; Cyclopentadiene dimer; Bicyclopentadiene; Biscyclopentadiene; Dicyklopentadien; etc.', 'Molecular Formula: C\n10\nH\n12 \n \nMolecular Weight: 132.20228', 'g/mol\n \nInChl Key: HECLRDQVFMWTQS-UHFFFAOYSA-N\n \n \n \n \n \nThe PubChem open chemistry database lists the following information for ENB: \n \n \n \nPubChem CID: 5365543\n \nChemical Names: Ethylidenenorbornene; Ethylidene norbornene; 2-Norbornene, 5-ethylidene-; 5-ETHYLIDENE-2-NORBORNENE; 5-Ethylidene-8,9,10-trinorborn-2-ene; CCRIS 4816; etc.', 'Molecular Formula: C\n9\nH\n12 \n \nMolecular Weight: 120.19158', 'g/mol\n \nInChl Key: OJOWICOBYCXEKR-KRXBUXKQSA-N\n \n \n \n \n \nAs an example, a terpolymer may be a DCPD/ENB/DILULIN™ material terpolymer (DED terpolymer).', 'Synthesis of such a terpolymer may proceed at least in part via ROMP.', 'For example, DED terpolymer can be cured via ROMP using transition metal chlorides (e.g., WCl\n6\n, hexachloro tungsten) in combination with Lewis-acidic co-catalysts (e.g., EtAICl\n2\n, ethylaluminum dichloride).', 'As an example, a DED terpolymer can also be cured with transition metal complexes (e.g. titanium, tungsten, molybdenum, ruthenium, osmium, etc.) with organic ligands.', 'As an example, cationic polymerization can be accomplished using one or more cationic catalysts, such as, for example, one or more of BF\n3\n·O(C\n2\nH\n5\n)\n2 \n(boron trifluoride ethyl etherate), B(C\n6\nF\n5\n)\n3 \n(tris (pentafluorophenyl) borane), MAO (methylalumoxane), VCl\n4 \n(tetrachlorovanadium), and AlBr\n3 \n(tribromoalumane).', 'While a terpolymer is mentioned as an example of a copolymer, in general, one or more types of copolymers may be synthesized.', 'For example, consider a DCPD/DILULIN™ material copolymer (DD copolymer) or an ENB/DILULIN™ material copolymer (ED copolymer).', 'As mentioned, a copolymer thermosets can be synthesized from DCPD and/or ENB as well as a functionalized oil (e.g., as in the DILULIN™ material, etc.).', "Such synthesis can include ring opening metathesis polymerization (ROMP), which may employ a catalyst or catalysts (e.g., 2nd generation Grubbs' catalyst, etc.).", 'The DILULIN™ material includes norbornyl-functionalized linseed oil synthesized by Diels-Alder reaction of linseed oil and DCPD at high temperatures and pressures.', 'The DILULIN™ oil component, a triester, has an average of less than one bicyclic moiety per triglyceride.', 'The low reactivity of the DILULIN™ material due to the low number of bicyclic moiety compared to DCPD and ENB can decrease curing kinetics, which can, for example, provide time for one or more filling and/or impregnation process (e.g., before gelation, a transition from liquid to solid).', 'As an example, the relatively low viscosity of DCPD and/or ENB may be controlled by adding different concentrations of the DILULIN™ material.', 'As an example, a terpolymer or other copolymer formed via use of a functionalized n-ester and ROMP, may exhibit toughness and adhesion to a component or components of an electric motor (e.g., consider magnet wire insulation), for example, via presence of the n-ester structure.', 'As an example, a polymeric composite material can include one or more of epoxy resin, blends of DCPD/ENB or terpolymers of DCPD/ENB/DILULIN™ material.', 'As to examples of fillers, consider one or more types of inorganic ceramic fillers such as, for example, boron nitride (BN), silica, alumina, and mixtures of two or more thereof.', 'As an example, where two or more filler materials are utilized, a polymeric composite material may be referred to as a hybrid filler polymeric composite material.', 'For example, a hybrid structure imparted by use of two or more thermally conductive fillers can provide for desired thermal conductivity and, for example, a decrease in the coefficient of thermal expansion (CTE).', 'Such a hybrid structure may further allow for tailoring viscosity and tailoring toughness.', 'As an example, inorganic hybrid fillers may be substantially homogenously mixed within a polymeric matrix (e.g., as a low viscosity liquid matrix) under relatively high shear force, for example, using a planetary mixer.', 'As an example, such a method may include in-situ polymerization.', 'As an example, a viscosity may be relatively low.', 'For example, a relatively low viscosity may be achieved via use of polymeric material such as DCPD/ENB or DCPD/ENB/DILLUIN™ material.', 'Such an approach can allow for fabrication of thermally conductive composites with relatively high concentrations of fillers.', 'As an example, a polymeric composite material can include polymer and micro/nano-sized fillers (e.g. particles, fibers, platelets, or tubes).', 'Such an approach may enhance properties relative to a neat polymeric matrix.', 'As an example, a filler or fillers may help to tailor one or more of modulus, strength, heat resistance, flame retardancy and gas permeability.', 'As an example, a polymeric composite material may be tailored for one or more of electrical, magnetic and optical properties.', 'As an example, a method may include tailoring via control of one or more micro-/nanostructural parameters such as, for example, dimension, shape, distribution, volume fraction, and packing arrangement of filler(s).', 'As an example, a filler concentration for substantial change in overall material properties may be referred to as a threshold filler volume fraction.', 'Enhancement of material properties in polymeric composites can be linked to interfacial interactions between polymeric matrix and filler(s) as well as, for example, formation of a network of interconnected filler particles.', 'As an example, a network of interconnected particles may help to improve thermal conductivity of a polymeric matrix.', 'As to thermally conductive fillers, a polymeric composite material may include, for example, one or more of alumina, aluminum nitride, wollastonite, boron nitride, and silicon carbide.', 'As to an encapsulation process of an electric motor, such a process may utilize a polymer thermosets.', 'For example, polybutadiene, epoxy, phenolic, acrylic, etc. may be utilized to provide mechanical protection against shock and/or vibration and to help protect magnet wire insulation materials and slot liner from degradation.', 'In downhole oil industry applications, an electric submersible pump may be used in an environment that may be high temperature and high pressure (HTHP) and include one or more types of corrosive fluids and/or gases (e.g., hydrogen sulfide (H\n2\nS), carbon dioxide (CO\n2\n), etc.).', 'An ESP encapsulant material can be specified to possess suitable dielectric properties, low CTE, high glass transition temperature, high storage modulus at operating temperature, suitable toughness, suitable thermal stability and suitable stability against hydrolytic degradation as well as, for example, relatively low viscosity before curing (e.g., for flow, filling, gas evacuation, etc.).', 'High thermal conductivity of an ESP encapsulant can be beneficial where operating temperatures are in excess of about 200 degrees C. (e.g., greater than about 400 degrees F.).', 'As an example, a thermally conductive encapsulant can help to mitigate risk of overheating and, for example, potentially reduce operating temperature.', 'As mentioned, a polymeric composite material can include a selected polymer matrix that may include, for example, copolymers of dicyclopentadiene (DCPD) and ethylidene-norbornene (ENB), a terpolymer thermosets of DCPD/ENB/DILULIN™ material (e.g., functionalized linseed oil), and/or an epoxy resin.', 'As an example, inorganic thermally conductive fillers may be selected from boron nitride, silica, alumina, and mixtures of two or more thereof.', 'As an example, a hybrid structure of inorganic fillers may be utilized to form an interconnected network that can improve thermal conductivity, for example, compared to a polymeric matrix that includes a single type of inorganic filler.', 'To improve the thermal conductive and decrease the CTE of a polymeric matrix, a volume of thermally conductive fillers can be substantially homogenously mixed with a polymeric matrix that is in a flowable state (e.g., a liquid state of suitable viscosity).', 'As an example, a method can include adding an amount of thermally conductive fillers where effect on viscosity of the polymeric matrix in the flowable state is relatively small.', 'For example, viscosity of a filled composite can be targeted to be sufficiently low to allow ease of filling/impregnation processes with respect to one or more electric motor structures (e.g., consider relatively narrow ESP slot stators).', 'As an example, a viscosity may be targeted to be sufficiently low prior to curing to allow for formation of a relatively homogenous encapsulant that does not entrain a substantial amount of air (e.g., relatively free of air bubbles or other gas bubbles).', 'For example, viscosity with respect to time and temperature may be suitable to allow for gas bubbles to rise, optionally under influence of a vacuum, such that a set encapsulant is relatively free from voids, etc.', 'As an example, viscosities of DCPD/ENB and DCPD/ENB/DILULIN™ material blends tend to be relatively low even where a method includes adding an amount of thermally conductive fillers up to about 50 percent by volume.', 'Such examples of blends may be lower in viscosity and suitable for relatively large amounts of fillers compared to an epoxy resin.', 'Thus, where an epoxy resin is utilized, the amount of fillers may be determined at least in part via effect of such thermally conductive fillers on the viscosity of the epoxy resin (e.g., as a function of filler concentration at different temperatures).', 'FIG.', '16\n shows an example plot \n1600\n of temperature dependence of complex viscosity at about a 2 degrees C. per minute heating rate and at about 1 radians per second angular frequency for epoxy resins with different volume percentages of hybrid thermally conductive fillers without hardener (e.g., without curing).', 'As shown in the plot \n1600\n, viscosity decreases with increasing temperature due to increased mobility of polymer chains at higher temperatures.', 'As shown in the plot \n1600\n, mixtures with about 50 percent by volume alumina and 42/5 alumina/boron nitride percent by volume tend to have relatively low viscosities at the higher temperatures.', 'As an example, a polymeric composite material can include an amount of alumina filler that may be in excess of about 30 percent by volume and optionally an amount of boron nitride (BN) that may be in a range from about 0.1 percent by volume to about 10 percent by volume.', 'As an example, a polymeric composite material can include an amount of alumina filler that may be in excess of about 30 percent by volume without including another type of thermally conductive filler.', 'As an example, a polymeric composite material may be about 50/0/0 percent by volume alumina/silica/BN per the example of \nFIG.', '16\n or may be about 42/0/5 percent by volume alumina/silica/BN per the example of \nFIG.', '16\n.', 'One or more of such examples may be utilized as an ESP encapsulant where, for example, suitable amount of hardener, etc. is included.', 'As an example, a hybrid filler may be an alumina and boron nitride (BN) hybrid filler.', 'FIGS.', '17\n and \n18\n show example plots \n1700\n and \n1800\n of data as to composition dependence of thermal conductivity at about 25 degrees C. and at about 200 degrees C. for epoxy resins (the plot \n1700\n) and DCPD/ENB/DILULIN™ material composites (the plot \n1800\n).', 'As shown in the plots \n1700\n and \n1800\n, thermal conductivity increases in a relatively exponentially manner with increasing volume percent of alumina.', 'As shown in the plots \n1700\n and \n1800\n, hybrid fillers (e.g., two or more of alumina, silica, and BN) can increase thermal conductivity more than the same volume percent of alumina alone (see, e.g., the arrows in the plots \n1700\n and \n1800\n).', 'A polymeric composite with a hybrid filler system can allow for building interconnected structure and enhance thermally conductivity when compared to use of a single filler (e.g., alumina).', 'FIGS.', '19\n and \n20\n show example plots \n1900\n and \n2000\n as to effect of filler on curing kinetics of epoxy resins composites (the plot \n1900\n) and DCPD/ENB/DILULIN™ material composites (the plot \n2000\n).', 'The plot \n1900\n of \nFIG.', '19\n shows curing time dependence of dynamic shear moduli (elastic modulus, G′ and viscous modulus, G″) at about 100 degrees C. As shown in the plot \n1900\n, gel time may be calculated from the cross over point between G′ and G″ (see arrows).', 'As indicated in the plot \n1900\n, gel time decreases from about 15 min for unfilled resin to about 12 min for a composite with about 50 percent by volume of alumina.', 'As shown in the plot \n2000\n of \nFIG. \n20\n, a decrease in gel time occurs for DCPD/ENB/DILULIN™ material when loaded with about 30 percent by volume alumina (e.g., gel time decreases from about 37 min to about 23 min at about 35 degrees C.).', 'In the systems corresponding to data of the plots \n1900\n and \n2000\n, values of G′ and G″ for filled composites are higher than those of unfilled ones at a substantially constant curing time.', 'FIGS.', '21\n and \n22\n show example plots \n2100\n and \n2200\n of data for effect of inorganic fillers on both CTE and dielectric properties of polymeric matrices.', 'In the plot \n1900\n, data show CTE as a function of alumina volume percent for epoxy resin composites at about 25 degrees C. and at about 200 degrees C. As shown in the plot \n2100\n, the value of CTE tends to be quite high at about 200 degree C. compared to the corresponding value at about 25 degrees C. Further, CTE decreases in a relatively exponential manner with increasing alumina concentration.', 'As to the data of the plot \n2200\n, CTE values for DCPD/ENB/DILULIN™ material composites tend to be lower than those of the epoxy resin composites per the data of the plot \n2100\n.', 'FIGS.', '23\n and \n24\n show example plots \n2300\n and \n2400\n of data for dielectric properties of epoxy resin composites with different inorganic filler compositions at different temperatures (the plot \n2300\n) and dielectric properties of DCPD/ENB/DILULIN™ material composites with different inorganic filler compositions at different temperatures (the plot \n2400\n).', 'As shown in the plots \n2300\n and \n2400\n, the dielectric constant and tan δ increase as temperature increases while the resistivity decreases as temperature increases.', 'As indicated in the plot \n2300\n, alumina can increase the dielectric constant of epoxy resin greater than BN.', 'The dielectric constant decreases from approximately 32 for a composite with about 30 percent by volume alumina to about 15 for a composite with about 25/5 alumina/BN percentages by volume (e.g., a total of about 30 percent by volume of fillers) at about 250 degrees C.\n \nAs to encapsulants, the dielectric properties of DCPD/ENB/DILULIN™ material composites tend to be better than those of epoxy resin composites.', 'As shown in the plot \n2400\n, the dielectric constant for DCPD/ENB/DILULIN™ material composites tends to be much lower than those of the epoxy resin, as shown in the plot \n2300\n, over a relatively wide range of temperatures even for a relatively high load of filler up to about 65 percent by volume alumina.', 'As an example, a polymeric composite material can exhibit a relatively high thermal conductivity, a relatively low viscosity (e.g., in a liquid state), relatively controllable curing kinetics, a relatively low CTE, a relatively high dielectric breakdown, a relatively low resistivity, a relatively low dissipation factor, a relatively high water resistance, as well as a relatively high glass transition temperature, suitable toughness, and a relatively high storage modulus at relatively high temperatures.', 'As an example, such a polymeric composite material may be used in one or more types of downhole oil industry applications, for example, as a dielectric material, an electric motor varnish, an electric motor encapsulant, etc.', 'As an example, a polymeric composite material can include an amount of one or more fillers by volume in a range from about 20 percent by total volume to about 50 percent by total volume.', 'As an example, a method may include mixing polymeric materials and one or more fillers in a manner where viscosity is controlled or predetermined to be within a desired range, which may correspond to a range suitable for use of the mixture as an encapsulant.', 'For example, the mixture may be in a liquid state suitable for being disposed in an electric motor housing prior to hardening.', 'As an example, a submersible component can include a conductor; and a polymeric material disposed about at least a portion of the conductor where the polymeric material includes at least approximately 50 percent by weight polyether ether ketone (PEEK) and at least 5 percent by weight perfluoroalkoxy alkanes (PFA) (e.g., perfluoro(alkoxy alkane)).', 'In such an example, the polymeric material can include or be a polymeric composite material that includes a thermally conductive filler that has a thermal conductivity greater than the polymeric material.', 'For example, consider a thermally conductive filler that includes alumina, boron nitride or alumina and boron nitride.', 'As an example, a submersible component can include polymeric material with a dielectric constant of less than approximately 10 at a temperature of approximately 250 degrees C.\n \nAs an example, a submersible component can include a conductor; and a polymeric material disposed about at least a portion of the conductor where the polymeric material includes at least approximately 50 percent by weight polyether ether ketone (PEEK) and at least 5 percent by weight perfluoroalkoxy alkanes (PFA) (e.g., perfluoro(alkoxy alkane)).', 'As an example, consider the component being an electric submersible pump power cable, an electric submersible pump motor lead extension (MLE), an electric submersible pump electric motor slot liner or an electric submersible pump magnet wire insulation.', 'As an example, a submersible component may be formed at least in part from a polymeric material that is a melt extrudable polymeric material, which may be, for example, a polymeric composite material.', 'As an example, a submersible electrical unit can include an electrically conductive winding; and a polymeric composite material disposed about at least a portion of the electrically conductive winding where the polymeric composite material includes polymeric material at at least approximately 40 percent by volume and one or more fillers at at least approximately 10 percent by volume.', 'In such an example, the one or more fillers can include alumina and/or boron nitride.', 'For example, consider fillers that include alumina and boron nitride, which may optionally be of different shapes.', 'As an example, differently shaped fillers may pack in a polymeric matrix in a manner that differs from similarly shaped fillers (e.g., or a single filler of a particular shape).', 'As an example, a submersible electrical unit can include an electrically conductive winding; and a polymeric composite material disposed about at least a portion of the electrically conductive winding where the polymeric composite material includes polymeric material at at least approximately 40 percent by volume and one or more fillers at at least approximately 10 percent by volume where the polymeric material includes dicyclopentadiene (DCPD), where the polymeric material includes ethylidenenorbornene (ENB) and/or where the polymeric material includes norbornyl-functionalized linseed oil (e.g., DILULIN™ material).', 'As an example, a polymeric material can include dicyclopentadiene, ethylidenenorbornene and norbornyl-functionalized linseed oil and can serve as a matrix for dispersion of one or more thermally conductive fillers therein (e.g., consider one or more of alumina and boron nitride).', 'As an example, a submersible electrical unit can be a submersible electric motor.', 'As an example, a polymeric composite material can be an encapsulant (e.g., for a stator or other component of a submersible electrical unit).', 'As an example, a polymeric composite material can be a varnish (e.g., for at least a portion of a submersible electrical unit).', 'As an example, a submersible component can include a conductor; and a polymeric material disposed about at least a portion of the conductor where the polymeric material includes at least approximately 50 percent by weight polyether ether ketone and at least 5 percent by weight perfluoroalkoxy alkanes and a submersible electrical unit can include an electrically conductive winding; and a polymeric composite material disposed about at least a portion of the electrically conductive winding where the polymeric composite material includes polymeric material at at least approximately 40 percent by volume and one or more fillers at at least approximately 10 percent by volume.', 'In such an example, the submersible component may be part of and/or operatively coupled to the submersible electrical unit.', 'For example, consider a cable as a submersible component that is operatively coupled to an electric motor that is part of a submersible electrical unit (e.g., an ESP motor, etc.).', 'As an example, equipment \n150\n and/or equipment \n170\n of \nFIG.', '1\n may optionally include a submersible component that includes a conductor; and a polymeric material disposed about at least a portion of the conductor where the polymeric material includes at least approximately 50 percent by weight polyether ether ketone and at least 5 percent by weight perfluoroalkoxy alkanes.', 'As an example, equipment \n150\n and/or equipment \n170\n of \nFIG.', '1\n may optionally be or include a submersible electrical unit can include an electrically conductive winding; and a polymeric composite material disposed about at least a portion of the electrically conductive winding where the polymeric composite material includes polymeric material at at least approximately 40 percent by volume and one or more fillers at at least approximately 10 percent by volume.', 'As an example, one or more methods described herein may include associated computer-readable storage media (CRM) blocks.', 'Such blocks can include instructions suitable for execution by one or more processors (or cores) to instruct a computing device or system to perform one or more actions.', 'According to an embodiment, one or more computer-readable media may include computer-executable instructions to instruct a computing system to output information for controlling a process.', 'For example, such instructions may provide for output to a sensing process, an injection process, drilling process, an extraction process, an extrusion process, a deposition process, a pumping process, a heating process, etc.', 'As an example, a method may be computer-controlled or otherwise controlled at least in part via processor-executable instructions stored in a storage medium or storage media.', 'As an example, consider control of a mixing process, a weighing process, an extrusion process, a filling process, a varnishing process, an encapsulation process, etc.', 'As an example, consider control of a method such as the method \n810\n and/or the method \n850\n of \nFIG. \n8\n.', 'As an example, a portion of the method \n810\n and/or a portion of the method \n850\n may be controlled via a computing system.\n \nFIG.', '25\n shows components of a computing system \n2500\n and a networked system \n2510\n.', 'The system \n2500\n includes one or more processors \n2502\n, memory and/or storage components \n2504\n, one or more input and/or output devices \n2506\n and a bus \n2508\n.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components \n2504\n).', 'Such instructions may be read by one or more processors (e.g., the processor(s) \n2502\n) via a communication bus (e.g., the bus \n2508\n), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device \n2506\n).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.', 'According to an embodiment, components may be distributed, such as in the network system \n2510\n.', 'The network system \n2510\n includes components \n2522\n-\n1\n, \n2522\n-\n2\n, \n2522\n-\n3\n, . .', '.', ', \n2522\n-N.', 'For example, the components \n2522\n-\n1\n may include the processor(s) \n2502\n while the component(s) \n2522\n-\n3\n may include memory accessible by the processor(s) \n2502\n.', 'Further, the component(s) \n2522\n-\n2\n may include an I/O device for display and optionally interaction with a method.', 'The network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words “means for” together with an associated function.']

['1.', 'A submersible electrical unit comprising:\nan electrically conductive winding; and\na polymeric composite material disposed about at least a portion of the electrically conductive winding, wherein the polymeric composite material comprises polymeric material at at least approximately 40 percent by volume and fillers at at least approximately 10 percent by volume, wherein the polymeric material comprises one or more amphiphilic molecules, and the fillers comprise alumina and/or boron nitride.', '2.', 'The submersible electrical unit of claim 1, wherein the amphiphilic molecules are ROMP capable.\n\n\n\n\n\n\n3.', 'The submersible electrical unit of claim 1, wherein the amphiphilic molecules comprise norbornyl-functional groups and/or cyclopentadiene-functional groups.', '4.', 'The submersible electrical unit of claim 1 wherein the polymeric material comprises dicyclopentadiene, ethylidenenorbornene, and norbornyl-functionalized linseed oil.', '5.', 'The submersible electrical unit of claim 1 comprising a submersible electric motor.', '6.', 'The submersible electrical unit of claim 1 wherein the polymeric composite material comprises an encapsulant.', '7.', 'The submersible electrical unit of claim 1 wherein the polymeric composite material comprises a varnish.', '8.', 'A submersible electrical unit comprising:\nan electrically conductive winding; and\na polymeric composite material disposed about at least a portion of the electrically conductive winding, the polymeric composite material comprising: one or more amphiphilic molecules; alumina filler in excess of about 30 percent by volume; and an amount of boron nitride filler in a range from about 0.1 percent by volume to about 10 percent by volume.', '9.', 'The submersible electrical unit of claim 8, wherein the polymeric composite material is about 42 percent by volume alumina filler and about 5 percent by volume boron nitride filler.', '10.', 'The submersible electrical unit of claim 8 comprising a submersible electric motor.\n\n\n\n\n\n\n11.', 'The submersible electrical unit of claim 8 wherein the polymeric composite material comprises an encapsulant.\n\n\n\n\n\n\n12.', 'The submersible electrical unit of claim 8 wherein the polymeric composite material comprises a varnish.', '13.', 'The submersible electrical unit of claim 8, wherein the amphiphilic molecules are ROMP capable.\n\n\n\n\n\n\n14.', 'The submersible electrical unit of claim 8, wherein the amphiphilic molecules comprise at least one of norbornyl-functional groups and cyclopentadiene-functional groups.', '15.', 'The submersible electrical unit of claim 8, wherein the polymeric material comprises dicyclopentadiene, ethylidenenorbornene and norbornyl-functionalized linseed oil.\n\n\n\n\n\n\n16.', 'A submersible component comprising:\na conductor; and\na polymeric composite material disposed about at least a portion of the conductor, wherein the polymeric composite material comprises polymeric material at at least approximately 40 percent by volume and fillers at at least approximately 10 percent by volume, the fillers comprising a first filler having a relatively low surface area, and a second filler having a higher aspect ratio than the first filler, the first filler comprising a greater percentage by volume of the polymeric composite material than the second filler.', '17.', 'The submersible component of claim 16, wherein the polymeric material comprises one or more amphiphilic molecules.', '18.', 'The submersible component of claim 17, wherein the amphiphilic molecules comprise norbornyl-functional groups and/or cyclopentadiene-functional groups.\n\n\n\n\n\n\n19.', 'The submersible component of claim 16, wherein the first filler comprises alumina and the second filler comprises boron nitride.', '20.', 'The submersible component of claim 16, wherein the polymeric material comprises dicyclopentadiene, ethylidenenorbornene and norbornyl-functionalized linseed oil.']

['FIG. 1 illustrates examples of equipment in geologic environments;; FIG.', '2 illustrates an example of an electric submersible pump system;; FIG. 3 illustrates examples of equipment;; FIG.', '4 illustrates an example of a system that includes a motor;; FIG. 5 illustrates examples of equipment;; FIG.', '6 illustrates examples of equipment;; FIG.', '7 illustrates examples of equipment;; FIG. 8 illustrates an example of an insulated conductor;; FIG. 9 illustrates examples of methods;; FIG.', '10 illustrates an example of a plot of data;; FIG.', '11 illustrates an example of a plot of data;; FIG.', '12 illustrates an example of a plot of data;; FIG.', '13 illustrates an example of a plot of data;; FIG.', '14 illustrates an example of a plot of data;; FIG.', '15 illustrates an example of a plot of data;; FIG.', '16 illustrates an example of a plot of data;; FIG.', '17 illustrates an example of a plot of data;; FIG.', '18 illustrates an example of a plot of data;; FIG.', '19 illustrates an example of a plot of data;; FIG.', '20 illustrates an example of a plot of data;; FIG.', '21 illustrates an example of a plot of data;; FIG.', '22 illustrates an example of a plot of data;; FIG.', '23 illustrates an example of a plot of data;; FIG.', '24 illustrates an example of a plot of data; and; FIG.', '25 illustrates example components of a system and a networked system.; FIG.', '1 shows an example of a geologic environment 120 and examples of equipment 150 and 170.', 'In FIG.', '1, the geologic environment 120 may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir 121 and that may be, for example, intersected by a fault 123 (e.g., or faults).', 'As an example, the geologic environment 120 may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment 122 may include communication circuitry to receive and to transmit information with respect to one or more networks 125.', 'Such information may include information associated with downhole equipment 124, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment 126 may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, FIG. 1 shows a satellite in communication with the network 125 that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', '; FIG. 1 also shows the geologic environment 120 as optionally including equipment 127 and 128 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 129.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 127 and/or 128 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG.', '2 shows an example of an ESP system 200 that includes an ESP 210 as an example of equipment that may be placed in a geologic environment.', 'As an example, an ESP may be expected to function in an environment over an extended period of time (e.g., optionally of the order of years).', '; FIG.', '3 shows cut-away views of examples of equipment such as, for example, a portion of a pump 320, a protector 370, a motor 350 of an ESP and a sensor unit 360.', 'In the examples of FIG.', '3, each of the pieces of equipment may be considered to be assemblies that, for example, can be operatively coupled to form a system (e.g., an ESP or ESP system).', 'In FIG.', '3, the pump 320, the protector 370, the motor 350 and the sensor unit 360 are shown with respect to cylindrical coordinate systems (e.g., r, z, Θ).', 'Various features of equipment may be described, defined, etc. with respect to a cylindrical coordinate system.', 'As an example, a lower end of the pump 320 may be coupled to an upper end of the protector 370, a lower end of the protector 370 may be coupled to an upper end of the motor 350 and a lower end of the motor 350 may be coupled to an upper end of the sensor unit 360 (e.g., via a bridge or other suitable coupling).; FIG.', '4 shows a block diagram of an example of a system 400 that includes a power source 401 as well as data 402 (e.g., information).', 'The power source 401 provides power to a VSD block 470 while the data 402 may be provided to a communication block 430.', 'The data 402 may include instructions, for example, to instruct circuitry of the circuitry block 450, one or more sensors of the sensor block 460, etc.', 'The data 402 may be or include data communicated, for example, from the circuitry block 450, the sensor block 460, etc.', 'In the example of FIG. 4, a choke block 440 can provide for transmission of data signals via a power cable 411 (e.g., including motor lead extensions “MLEs”).', 'A power cable may be provided in a format such as a round format or a flat format with multiple conductors.', 'MLEs may be spliced onto a power cable to allow each of the conductors to physically connect to an appropriate corresponding connector of an electric motor (see, e.g., the connector 352 of FIG.', '3).', 'As an example, MLEs may be bundled within an outer casing (e.g., a layer of armor, etc.).', '; FIG.', '5 shows various examples of motor equipment.', 'A pothead unit 501 includes opposing ends 502 and 504 and a through bore, for example, defined by a bore wall 505.', 'As shown, the ends 502 and 504 may include flanges configured for connection to other units (e.g., a protector unit at the end 502 and a motor unit at the end 504).', 'The pothead unit 501 includes cable passages 507-1, 507-2 and 507-3 (e.g., cable connector sockets) configured for receipt of cable connectors 516-1, 516-2 and 516-3 of respective cables 514-1, 514-2 and 514-3.', 'As an example, the cables 514-1, 514-2 and 514-3 and/or the cable connectors 516-1, 516-2 and 516-3 may include one or more polymeric materials.', 'For example, a cable may include polymeric insulation while a cable connector may include polymeric insulation, a polymeric component (e.g., a bushing), etc.', 'As an example, the cables 514-1, 514-2 and 514-3 may be coupled to a single larger cable.', 'The single larger cable may extend to a connector end for connection to a power source or, for example, equipment intermediate the cable and a power source (e.g., an electrical filter unit, etc.).', 'As an example, a power source may be a VSD unit that provides three-phase power for operation of a motor.; FIG.', '5 also shows a pothead unit 520 that includes a socket 521.', 'As an example, a cable 522 may include a plug 524 that can couple to the socket 521 of the pothead unit 520.', 'In such an example, the cable 522 may include one or more conductors 526.', 'As an example, a cable may include at least one fiber optic cable or one or more other types of cables.', 'As an example, a fiber optic cable can include a layer of polymeric material where a barrier layer may be disposed over the layer of polymeric material.', 'In such an example, the barrier layer may help to protect the layer of polymeric material from one or more constituents in an environment.', 'As an example, a fiber optic cable may be suitable for use in a fluid environment where the fiber optic cable is a submersible fiber optic cable.; FIG.', '6 shows a perspective cut-away view of an example of a motor assembly 600 that includes a power cable 644 (e.g., MLEs, etc.) to supply energy, a shaft 650, a housing 660 that may be made of multiple components (e.g., multiple units joined to form the housing 660), stacked laminations 680, stator windings 670 of wire (e.g., magnet wire) and rotor laminations 690 and rotor windings 695 coupled to the shaft 650 (e.g., rotatably driven by energizing the stator windings 670).; FIG.', '7 shows an example of an electric motor 710, an example of a photograph of a portion of an electric motor 770 and a photograph 780 of a portion of an electric motor.; FIG.', '8 shows an example method 810 and an example method 850.', 'As shown, the method 810 includes a provision block 812 for providing PEEK and one or more fluoropolymers, an optionally provision block 814 for providing one or more fillers, a mix block 816 for mixing provided materials and a formation block 818 for forming a component based at least in part on the mixtures of provided materials.; FIG.', '9 shows an example of a plot 900 that includes data as to angular frequency dependence of complex viscosity for PEEK and PFA at about 370 degrees C.; FIG.', '10 shows an example plot 1000 of data for temperature dependence of storage modulus and tan δ for PEEK/PFA blends.; FIGS.', '11 and 12 show plots 1100 and 1200, respectively.', 'The plot 1100 shows DSC thermograms for PEEK/PFA blends and the plot 1200 shows melting enthalpies of PEEK-rich and PFA-rich phases of the PEEK/PFA blends.; FIGS.', '13 and 14 shows plots 1300 and 1400 where the plot 1300 shows temperature dependence of dielectric constant for PEEK/PFA blends and where the plot 1400 shows temperature dependence of dielectric tan δ for PEEK/PFA blends.; FIG.', '15 shows a plot 1500 of data for a PEEK/PFA 75/25 blend.', 'Specifically, the data show the effect of different thermally conductive fillers on the thermomechanical properties.', 'As seen in FIG.', '15, the Tg of the PEEK/PFA 75/25 blend does not change noticeably with addition of about 25 percent by weight of the different thermally conductive fillers, which are alumina, silica, and boron nitride (BN).', 'The data indicate that the storage modulus increased by adding the different fillers and that the magnitude of the elevation was found to be a maximum for BN when compared to alumina and silica.;', 'FIG.', '16 shows an example plot 1600 of temperature dependence of complex viscosity at about a 2 degrees C. per minute heating rate and at about 1 radians per second angular frequency for epoxy resins with different volume percentages of hybrid thermally conductive fillers without hardener (e.g., without curing).; FIGS.', '17 and 18 show example plots 1700 and 1800 of data as to composition dependence of thermal conductivity at about 25 degrees C. and at about 200 degrees C. for epoxy resins (the plot 1700) and DCPD/ENB/DILULIN™ material composites (the plot 1800).', 'As shown in the plots 1700 and 1800, thermal conductivity increases in a relatively exponentially manner with increasing volume percent of alumina.', 'As shown in the plots 1700 and 1800, hybrid fillers (e.g., two or more of alumina, silica, and BN) can increase thermal conductivity more than the same volume percent of alumina alone (see, e.g., the arrows in the plots 1700 and 1800).', 'A polymeric composite with a hybrid filler system can allow for building interconnected structure and enhance thermally conductivity when compared to use of a single filler (e.g., alumina).;', 'FIGS. 19 and 20 show example plots 1900 and 2000 as to effect of filler on curing kinetics of epoxy resins composites (the plot 1900) and DCPD/ENB/DILULIN™ material composites (the plot 2000).', 'The plot 1900 of FIG.', '19 shows curing time dependence of dynamic shear moduli (elastic modulus, G′ and viscous modulus, G″) at about 100 degrees C. As shown in the plot 1900, gel time may be calculated from the cross over point between G′ and G″ (see arrows).', 'As indicated in the plot 1900, gel time decreases from about 15 min for unfilled resin to about 12 min for a composite with about 50 percent by volume of alumina.; FIGS.', '21 and 22 show example plots 2100 and 2200 of data for effect of inorganic fillers on both CTE and dielectric properties of polymeric matrices.', 'In the plot 1900, data show CTE as a function of alumina volume percent for epoxy resin composites at about 25 degrees C. and at about 200 degrees C. As shown in the plot 2100, the value of CTE tends to be quite high at about 200 degree C. compared to the corresponding value at about 25 degrees C. Further, CTE decreases in a relatively exponential manner with increasing alumina concentration.', 'As to the data of the plot 2200, CTE values for DCPD/ENB/DILULIN™ material composites tend to be lower than those of the epoxy resin composites per the data of the plot 2100.', '; FIGS.', '23 and 24 show example plots 2300 and 2400 of data for dielectric properties of epoxy resin composites with different inorganic filler compositions at different temperatures (the plot 2300) and dielectric properties of DCPD/ENB/DILULIN™ material composites with different inorganic filler compositions at different temperatures (the plot 2400).', 'As shown in the plots 2300 and 2400, the dielectric constant and tan δ increase as temperature increases while the resistivity decreases as temperature increases.', '; FIG.', '25 shows components of a computing system 2500 and a networked system 2510.', 'The system 2500 includes one or more processors 2502, memory and/or storage components 2504, one or more input and/or output devices 2506 and a bus 2508.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components 2504).', 'Such instructions may be read by one or more processors (e.g., the processor(s) 2502) via a communication bus (e.g., the bus 2508), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device 2506).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.']

US11971128

Plug removal tool and methods thereof

Dec 16, 2022

Hugues Trifol, Matthieu Dezaphix

Schlumberger Technology Corporation

NPL References not found.

4519519; May 28, 1985; Meuschke; 8353420; January 15, 2013; Carlson; 20190023589; January 24, 2019; Norman

Foreign Citations not found.

['A plug removal tool may include a mount for attaching the plug removal tool to a structure and a plug nut.', 'Additionally, the plug removal tool may include at least one rigid arm extending between the mount and the plug nut.', 'Further, the at least one arm may have at least one translational degree of movement and at least one rotational degree of movement.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority as a continuation application to co-pending U.S. patent application Ser.', 'No. 16/664,516 filed Oct. 25, 2019, which claims priority to U.S. Provisional Patent Application No. 62/751,182 filed Oct. 26, 2018, the foregoing are incorporated herein in their entirety by reference.', 'BACKGROUND\n \nField\n \nEmbodiments described herein generally relate to flow skids used in the oil & gas industry.', 'Specifically, embodiments described herein relate to removal of a plug from such flow skids.', 'Description of the Related Art\n \nModular flow skids may be useful in the process of extracting and managing wells that are drilled into the earth to retrieve one or more subterranean natural resources, including oil and gas.', 'Such skids may be utilized both offshore and onshore.', 'For example, modular flow skids may be used for surface well testing to assess the reservoir potential, validate well performance during cleanup and commissioning, and to allow for reservoir monitoring for better field management.', 'A modular flow skid is a structure having a set of pipes and components (i.e., fluid conduits) through which fluid (e.g., oil, gas, water, frac fluid, and testing fluids) may flow.', 'In addition, the flow skid may include a number of flow control devices, including chokes, valves, and plugs, and may also include a number of instruments or devices for measuring and obtaining pertinent data about the fluid flowing through the one or more pipes located in the flow control modules.', 'Further, the modular flow skid may include screens or filters inserted within the fluid conduits of the modular flow skid.', 'Screens or filters are used to clean, filter, and remove debris from the fluid flowing through the fluid conduits.', 'During operations, the screens or filters are used to filter, clean, and remove debris from the fluid flowing through the fluid conduits.', 'Subsequently, the screens or filters need to cleaned, emptied, repaired and/or replaced from time to time.', 'As known in the art, a filter may be a structure used to filter, clean, and remove debris from fluids flowing through fluid conduits.', 'In order to clean, empty, and/or replace the filters, the fluid conduits are opened in order to access the filter.', 'For example, the fluid conduit may have an opening, which is closed with a plug or insert, to access the filter within the fluid conduits.', 'As illustrated in \nFIG.', '1\n, in conventional methods, a plug \n1\n, which is used to close an opening \n2\n of a flow conduit \n3\n of a modular flow skid \n4\n, is taken off the opening \n2\n using a manual hook \n5\n attached to said plug \n1\n in combination with an overhead crane or pulley \n6\n to support a weight of the plug \n1\n.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'In one aspect, the embodiments disclosed herein provide a plug removal tool that has a mount for attaching the plug removal tool to a structure; a plug nut; and at least one rigid arm extending between the mount and the plug nut, the at least one arm having at least one translational degree of movement and at least one rotational degree of movement.', 'In another aspect, the embodiments disclosed herein provide a method for removing a filter in a fluid conduit by removing a plug nut from an opening of the fluid conduit; supporting the plug nut with a plug removal tool, thereby defining a limited movement of the plug nut while removed from the opening; and removing the filter through the opening of the fluid conduit.', 'In another aspect, the embodiments disclosed herein provide a system with a modular skid having a fluid conduit, wherein the fluid conduit has a fluid inlet and a fluid outlet; and at least one plug removal tool removably attached to the modular skid, wherein the plug removal tool includes a mounting bracket that comprises a first swivel joint, a first arm extending from a first end to a second end, wherein the first end is attached to the first swivel joint, a second arm slidably attached to the first arm between the first end and the second end, a second swivel joint connected to a distal end of the second arm, and a plug nut attached to the second swivel joint, wherein the plug removal tool is configured to remove or insert the plug nut from an opening of the fluid conduit.', 'Other aspects and advantages will be apparent from the following description and the appended claims\n \n \nBRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings.', 'It is to be noted, however, that the appended drawings illustrate only exemplary embodiments and are therefore not to be considered limiting of its scope, may admit to other equally effective embodiments.\n \nFIG.', '1\n is a perspective view of a plug removal system in accordance with the prior art.\n \nFIG.', '2\n is a perspective view of a plug removal tool in accordance with one or more embodiments of the present disclosure.', 'FIGS.', '3\n and \n4\n are a perspective view of a modular skid with the plug removal tool of \nFIG.', '2\n in accordance with one or more embodiments of the present disclosure.', 'FIG.', '5\nA\n is a side view of the plug removal tool of \nFIG.', '3\n in accordance with one or more embodiments of the present disclosure.', 'FIG.', '5\nB\n is a cross-sectional view along line \n5\nB-\n5\nB in \nFIG.', '5\nA\n in accordance with one or more embodiments of the present disclosure.', 'To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures.', 'It is contemplated that elements and features of one embodiment may be beneficially incorporated in other embodiments without further recitation.', 'DETAILED DESCRIPTION\n \nEmbodiments of the present disclosure are described below in detail with reference to the accompanying figures.', 'Like elements in the various figures may be denoted by like reference numerals for consistency.', 'Further, in the following detailed description, numerous specific details are set forth in order to provide a more thorough understanding of the claimed subject matter.', 'However, it will be apparent to one having ordinary skill in the art that the embodiments described may be practiced without these specific details.', 'In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description.', 'Further, embodiments disclosed herein are described with terms designating a drilling rig site in reference to a drilling rig, but any terms designating rig type (i.e., any land rig or offshore rig) should not be deemed to limit the scope of the disclosure.', 'It is to be further understood that the various embodiments described herein may be used in various stages of a well, such as rig site preparation, drilling, completion, abandonment etc., and in other environments, such as work-over rigs, fracking installation, well-testing installation, oil and gas production installation, without departing from the scope of the present disclosure.', 'The embodiments are described merely as examples of useful applications, which are not limited to any specific details of the embodiments herein.', 'In one aspect, embodiments disclosed herein relate to a plug removal tool.', 'A plug removal tool may also be interchangeably referred to as a plug support tool in the present disclosure.', 'Similarly, a filter may be interchangeably referred to as a screen in the present disclosure.', 'As used herein, the term “coupled” or “coupled to” or “connected” or “connected to” may indicate establishing either a direct or an indirect connection, and is not limited to either unless expressly referenced as such.', 'Wherever possible, like or identical reference numerals are used in the figures to identify common or the same elements.', 'The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale for purposes of clarification.', 'Plug removal tools, according to embodiments herein, are apparatuses that include a plurality of joints for moving a plug from or to an opening of a fluid conduit and at least one arm to aid in moving and supporting the plug when unplugged from the fluid conduct.', 'It is envisioned that the plug removal tool may have at least one rigid arm to which the plug nut is attached, where the at least one rigid arm includes at least one rotational degree of movement and at least one translational degree of movement such that the plug nut may be moved away from the opening to remove a filter therefrom.', 'However, the rigidity provided by the at least one arm eliminates the greater degrees of movement allowed by conventional mechanisms for removing the plug from the opening of the conduit.', 'In addition, the plug removal tools may be run mechanically, hydraulically, or pneumatically.', 'The elimination of manual hooks and the use of an overhead crane significantly reduce HSE risks, potentially equipment damage, and unwanted downtime.', 'As described in \nFIG.', '1\n, conventional methods of removing (or inserting) the plug \n1\n from the opening \n2\n of the flow conduit \n3\n within the modular flow skid \n4\n in the oil and gas industry are typically the manual hook \n5\n handled by a user (not shown).', 'Further, the overhead crane or pulley \n6\n is needed to complete the extraction (or insertion) of the plug \n1\n.', 'Such conventional methods may be both time consuming and may also increase HSE risks.', 'For example, in order to remove the plug \n1\n, the user manually attaches the hook \n5\n to the plug \n1\n and rotates the plug \n1\n onto (or off) the opening \n2\n until enough of the plug \n1\n is free from the opening \n2\n such that the user may use the overhead crane \n6\n to support the plug \n1\n.', 'This additional manual hands-on method by the user adds to increasing the likelihood of HSE risk, spillage of fluids onto the rig floor, damage to equipment, and cause unwanted downtown.', 'Accordingly, one or more embodiments in the present disclosure may be used to overcome such challenges as well as provide additional advantages over conventional methods of plug removal in oil and gas operations, as will be apparent to one of ordinary skill in the art upon reading this disclosure.', 'Turning to \nFIG.', '2\n, \nFIG.', '2\n shows a perspective view of a plug removal tool \n100\n for removing/inserting and supporting a plug nut \n120\n in accordance with one or more embodiments of the present disclosure.', 'As used herein, a plug nut, such as the plug nut \n120\n, may include any structure that blocks a flow of fluids (which may include liquids, gases, and/or mixtures thereof) in a fluid conduit from flowing further and which may be secured in place to serve as such a blockage.', 'In a non-limiting example, the plug nut \n120\n may include a thread such that the plug nut \n120\n may be unscrewed or screwed onto a body of the fluid conduit.', 'The plug nut \n120\n is further described in \nFIGS.', '5\nA and \n5\nB\n and shown as including a plug component and a nut component.', 'In one or more embodiments, the plug removal tool \n100\n may include a mounting bracket \n101\n or other mount for mounting the plug removal tool \n100\n onto a structure so that the weight of plug nut \n120\n may be supported by plug removal tool \n100\n (and in particular the mounting bracket \n101\n.', 'In a non-limiting example, the mounting bracket \n101\n may have mount holes \n102\n such that bolts (not shown) may bolt the mounting bracket \n101\n to a structure, such as a housing or exterior of a fluid conduit or to a frame component of a modular skid.', 'As known in the art, a mounting bracket, such as the mounting bracket \n101\n, may be any structure used to attach and support the plug removal tool \n100\n on a structure.', 'It is noted that the mounting bracket \n101\n in one or more embodiments may be configured as a flat metal sheet or any shape that fits the plug removal tool \n100\n on a structure.', 'In one or more embodiments, the plug removal tool \n100\n may include a first swivel joint \n103\n fixed to the mounting bracket \n101\n about an axis of rotation \n104\n.', 'As illustrated, the first swivel joint \n103\n may rotate counter-clockwise (see arrow \n105\n).', 'While the first swivel joint \n103\n is shown rotating counter-clockwise, it may be understood that the first swivel joint \n103\n may rotate clockwise or both counter-clockwise and clockwise.', 'In some embodiments, the first swivel joint \n103\n may include a pin (not shown) to fix the first swivel joint \n103\n from rotating and/or to limit a degree of rotation.', 'In a non-limiting example, the first swivel joint \n103\n may rotate 360 degrees about the axis of rotation \n104\n and a pin may be inserted into the first swivel joint \n103\n such that the first swivel joint \n103\n rotates 90 degrees in a counter-clockwise direction.', 'One skilled in the art will appreciate how the first swivel joint \n103\n may be any joint allowing a degree of rotation.', 'As illustrated in \nFIG.', '2\n (as well as some components in \nFIGS.', '3\n and \n4\n which are discussed in greater detail below), in one or more embodiments, a first arm \n106\n may be attached or fixed to the first swivel joint \n103\n.', 'In addition, a cover \n122\n may be used to further connect the first arm \n106\n to the first swivel joint \n103\n.', 'The first arm \n106\n extends from a first end \n107\n to a second end \n108\n, such that the first end \n107\n is fixed to the first swivel joint \n103\n and the second end \n108\n is free.', 'Further, as illustrated, a second arm \n109\n is slidably attached to the first arm \n106\n between the first end \n107\n and the second end \n108\n.', 'The second arm \n109\n may include bearings \n110\n to allow a sliding movement of the second arm \n109\n with respect to the first arm \n106\n (see arrow \n111\n), perpendicular to the axis of rotation \n104\n, both toward and away from swivel joint \n103\n and axis of rotation \n104\n.', 'While two bearings \n110\n are shown, it may be understood that any number of bearings may be used to slidably attach the second arm \n109\n to the first arm \n106\n.', 'It is further envisioned that the second arm \n109\n may include a lock to fix the second arm \n109\n in a position on the first arm \n106\n.', 'Additionally, the second arm \n109\n may be integrated into the first arm \n106\n.', 'Still referring to \nFIG.', '2\n, in one or more embodiments, at a distal end \n112\n of the second arm \n109\n, second arm \n109\n may include a second swivel joint \n113\n connected thereon, such that the second swivel joint \n113\n may rotate about an axis of rotation \n114\n at the distal end \n112\n.', 'As illustrated, the second swivel joint \n113\n may rotate counter-clockwise (see arrow \n115\n).', 'While the second swivel joint \n113\n is shown rotating counter-clockwise, it may be understood that the second swivel joint \n113\n may rotate clockwise or both counter-clockwise and clockwise.', 'In this case, the axis of rotation \n104\n is parallel to the axis of rotation \n114\n.', 'In some embodiments, the second swivel joint \n113\n may include a pin (not shown) to fix the second swivel joint \n113\n from rotating or limiting a degree of rotation.', 'In a non-limiting example, the second swivel joint \n113\n may rotate 360 degrees about the axis of rotation \n114\n and a pin may be inserted into the second swivel joint \n113\n such that the second swivel joint \n113\n rotates in a limited degree range in a counter-clockwise direction.', 'One skilled in the art will appreciate how the second swivel joint \n113\n may be any joint allowing a degree of rotation.', 'Further, the second swivel joint \n113\n may aid in aligning the plug nut \n120\n with an opening of a fluid conduit such that the plug nut \n120\n is inserted into the opening straight.', 'Further illustrated by \nFIG.', '2\n, in one or more embodiments, the plug nut \n120\n may be coupled to the second swivel joint \n113\n.', 'In a non-limiting example, a second mounting bracket \n116\n may be used to removably attach the plug nut \n120\n to the second swivel joint \n113\n.', 'The second mounting bracket \n116\n may be any apparatus, such as an L-shaped bracket, that includes a first end \n117\n attached to the second swivel joint \n113\n and a second end \n118\n bolted (directly or indirectly through another piece) to the plug nut \n120\n.', 'Furthermore, plug nut \n120\n may be rotated by a hand-wheel \n121\n Further, the plug nut \n120\n may be rotated mechanically or automatically.', 'As the plug nut \n120\n is unscrewed, the second arm \n109\n may slide with respect to the opening to the fluid conduit, thereby translationally moving the position of the plug nut \n120\n with respect to the opening of a flow conduit.', 'It is further envisioned that while \nFIG.', '2\n shows two arms and two swivel joints, the present disclose is not limited to such a configuration and may include any numbers of arms and swivel joints (and/or hoists) without departing from present scope of the disclose.', 'For example, in a non-limiting example, the plug removal tool \n100\n may have one arm slidably attached to one swivel joint that allow for both rotating and sliding the plug nut \n120\n.', 'As seen by \nFIGS. \n3\n and \n4\n, in one or more embodiments, the plug removal tool \n100\n (as described in \nFIG.', '2\n) is attached to a body \n200\n having a fluid conduit \n201\n, which may be a pot, on a modular skid \n300\n.', 'It is noted that \nFIG.', '3\n shows a close-up perspective view of the plug removal tool \n100\n on the modular skid \n300\n while the plug nut is attached to the opening of the fluid conduit, and \nFIG.', '4\n shows a zoomed-out perspective view of the plug removal tool \n100\n when the opening is open (the plug nut is detached from the opening).', 'The modular skid \n300\n may be any type of modular skid used for fluid flows through a fluid conduit \n201\n.', 'In a non-limiting example, the modular skid \n300\n may be a plug and trash catcher skid.', 'The plug and trash catcher skid may be used to help prevent plugging of chokes (on the skid) and/or other surface process equipment during drilling, well testing or fracturing frac flow back operations.', 'Specifically, the plug and trash catcher skid has the capability of continuous debris removal without shutting down flow back or drilling operations.', 'Further, the trash catcher (debris catcher) is designed to catch and retain chunks from drilled plugs, for example.', 'Said trash catchers are very effective to prevent erosion damage to downstream equipment and catch and retain debris, chunks and trash, drilled bridge plugs etc.', 'Advantageously, the plug and trash catcher skid may aid in: removal and cleanup on horizontal-multilateral completion and workover; drill out of completion tools such as bridge plugs, selective frac packer system; capture of frac sand and formation solids; and/or work over use to capture drill out solids, such as cement retainer, bride plug, cement and formation solids frac sand, and fishing operation solids.', 'In one or more embodiments, the modular skid \n300\n may include isolation valves \n202\n coupled to the fluid conduit \n201\n.', 'The fluid conduit \n201\n, in this case a pot, holds the filter (not shown).', 'In some embodiments, the isolation valves \n202\n are used to direct fluid from a fluid conduit of the modular skid \n300\n to the fluid conduit \n201\n where the filters are in fluid communications with the fluid conduit and are configured to filter a fluid flowing through the fluid conduit.', 'While only one fluid conduit \n201\n is shown, the present disclose is not limited to such a configuration and may include any numbers of pots without departing from present scope of the disclosure.', 'In a non-limiting example, the isolations valves \n202\n allow for fluid flow to only go through one fluid conduit at a time, both fluid conduits, or none of the fluid conduits.', 'Further, each fluid conduit \n201\n includes an opening \n203\n at an end of the body \n200\n.', 'In combination with the plug nut \n120\n, when the fluid conduit \n201\n is a pot, the plug \n201\n forms a pot plug (\n201\n, \n120\n) to enclose the filter (not shown).', 'As further shown by \nFIGS. \n3\n and \n4\n, the plug removal tool \n100\n is mounted to the body \n200\n of the fluid conduit \n201\n, in this case on top of the fluid conduit \n201\n, to have the plug removal tool \n100\n near the opening \n203\n.', 'While the plug removal tool \n100\n is shown mounted on the body \n200\n, one skilled in the art will appreciate how the plug removal tool \n100\n may be mounted on any part of the modular skid \n300\n such as a structural frame or a component of the skid, without departing from present scope of the disclose.', 'In a non-limiting example, the plug removal tool \n100\n may be mounted on a base \n301\n or a support beam \n302\n of the modular skid \n300\n.', 'In some embodiments, it is further envisioned that the plug removal tool \n100\n may be mounted on a filter extractor tool \n303\n.', 'In one or more embodiments, the filter extractor tool \n303\n is mounted on the base \n301\n to align the filter extractor tool \n303\n with the pot plug (\n201\n, \n120\n).', 'One skilled in the art will appreciate how the filter extractor tool \n303\n is coupled to the base \n301\n to be removable or fixed via mechanical fasteners, welding, adhesives, or any known way in the art.', 'It is further envisioned that while \nFIG.', '4\n illustrates the filter extractor tool \n303\n coupled to the base \n301\n, the filter extractor tool \n303\n may be coupled to any part of the modular skid \n300\n.', 'In some embodiments, the filter extractor tool \n303\n may remain unattached to the modular skid \n300\n and be disposed on a surface near the pot plug (\n201\n, \n120\n).', 'Once filter extractor tool \n303\n is aligned with the fluid conduit \n201\n, the plug nut \n120\n may be removed such that the filter extractor tool \n303\n is used to remove and clean the filter within the fluid conduit \n201\n.', 'Additionally, while the filter is being cleaned, a spare filter may be inserted into the fluid conduit \n201\n to ensure operations continue without delay.', 'As described above, in one or more embodiments, \nFIG.', '3\n shows the close-up perspective view of the plug removal tool \n100\n with the plug nut \n120\n closed on the opening \n203\n.', 'In order for the plug nut \n120\n to be sealingly closed on the opening \n203\n, the second arm \n109\n has slid in axial direction on the first arm \n106\n to be at a position in which the second arm \n109\n is closest to the first end \n107\n of the first arm \n106\n.', 'It is further envisioned that the second end \n108\n of the first arm \n106\n may act as a stop for the hand-wheel \n121\n to abut against.', 'Furthermore, as described above, \nFIG.', '4\n shows a zoomed-out perspective view of the plug nut \n120\n removed from the opening \n203\n by the plug removal tool \n100\n.', 'As illustrated by \nFIG.', '4\n, in one or more embodiments, the plug removal tool \n100\n may be rotated 90 degrees (or any other desired degree) about the axis of rotation \n104\n of the first swivel joint \n103\n such that the plug nut \n120\n is in a non-operation position such that it no longer interferes with or blocks the opening \n203\n of the pot \n207\n.', 'Additionally, the first swivel joint \n103\n may then be locked to ensure that the plug removal tool \n100\n does not sway.', 'While it is shown that the plug removal tool \n100\n is rotated 90 degrees, one skilled in the art will appreciate how the plug removal tool \n100\n may move any degree needed to have the opening \n203\n be accessible.', 'With the plug nut \n120\n rotated away from the opening \n203\n, the filter extractor tool \n303\n may now be used to remove the filter from the fluid conduit \n201\n.', 'As shown in \nFIGS.', '5\nA and \n5\nB\n, in one or more embodiments, the plug nut \n120\n may be a combination of a nut \n123\n and a plug \n124\n, which are slidable relative to each other.', 'When plug \n124\n is inserted into a body \n200\n, nut \n123\n slides over the distal end of plug \n124\n and retains plug \n124\n within body by threading onto body.', 'Specifically, the nut \n123\n is coupled to the body \n200\n via a threaded connection \n126\n such that an inner surface \n127\n of the nut \n123\n may include threads to be threaded on threads of an outer surface \n128\n of the body \n200\n.', 'Nut \n123\n may be screwed onto body \n200\n by rotating hand-wheel \n121\n attached to nut \n123\n.', 'As nut \n123\n is tightened onto body \n200\n, a shoulder of nut \n123\n may abut a shoulder of plug \n124\n, thereby retaining plug \n124\n within body \n200\n (and sealing body \n200\n from the external environment).', 'In some embodiments, a bolted connection \n125\n connects the second mounting bracket \n116\n to the plug \n124\n, thereby.', 'When nut \n123\n is rotated via hand-wheel \n121\n, plug \n124\n and the second mounting bracket \n116\n remain stationary.', 'In a non-limiting example, bearings (not shown) may be inserted between the nut \n123\n and the plug \n124\n to allow the nut \n123\n to rotate over the plug \n124\n.', 'In another non-limiting example, a sufficient clearance may be provided between nut \n123\n and plug \n124\n to allow the nut \n123\n to rotate over plug \n124\n.', 'As nut \n123\n is unscrewed away from body \n200\n, plug \n124\n may be removed from body \n200\n via its attachment to mounting bracket \n116\n.', 'Furthermore, methods of the present disclosure may include use of the filter extractor tool and other structures, such as in \nFIGS.', '2\n-\n5\nB\n.', 'Because the method may apply to any of the embodiments, reference numbers are not referenced to avoid confusion of the numbering between the different embodiments.', 'Initially, a plug removal tool is coupled to a body of a fluid conduit to be near an opening of the fluid conduit in a modular skid.', 'In a non-limiting example, a mount bracket of the plug removal tool is bolted onto the body.', 'Once the plug removal tool is attached to the body, a plug nut is then connected to an arm of the plug removal tool via a second mounting bracket so that the plug removal tool may support a weight of the plug nut.', 'The second mounting bracket is coupled to the plug nut and a swivel joint of the arm.', 'Next, the arm is slid in an axial direction on a second arm to positon the plug nut in front of an opening of the body (the opening being in fluid communication with the fluid conduit).', 'Further, at least one swivel joint of the arm is used to align the plug nut with the opening.', 'Once straightly aligned, a hand-wheel coupled to the plug nut is rotated to screw the plug nut onto the opening and sealingly close the opening to ensure no fluids flowing through the fluid conduit leak.', 'Further, the plug nut is screwed onto the body via threads on a nut of the plug nut being threaded onto threads of the body as the hand-wheel is rotated.', 'Additionally, while nut is being threaded onto the body, a plug attached to the nut is sealingly inserted into the opening.', 'Further, while the plug nut is thread onto the opening, the arm may in to correspond with any translational movement of the plug nut while being screwed.', 'As fluids flow through the fluid conduit, the fluids travel through a filter disposed in the fluid conduit to filter debris from the fluid.', 'Eventually, the filter may need to be removed for maintenance.', 'In order to perform maintenance on the filter, the filter may be removed from the fluid conduit through the opening; however, the plug nut will need be removed first.', 'In order to remove the plug nut (and filter), the hand-wheel is rotated to unscrew the plug nut from the opening such that the threads of the nut are unthreaded from the threads of the body and correspondingly, the plug is removed out of the opening.', 'As the plug nut is unscrewed, the arm may axially move in a direction corresponding to the axial movement of the plug nut unscrewing.', 'Once the plug nut is fully unscrewed from the opening, the plug nut removal tool supports all of the weight of the plug nut.', 'In order to move the plug nut away from the opening, the plug nut may be rotated by at least one degree of movement away from the opening (including translational movement and/or rotational movement.', 'For example, the first and/or second arm of the plug nut tool may be rotated about an axis of rotation of the swivel joint(s), thereby rotating or pivoting the plug nut away from the opening.', 'For example, the plug nut may be rotated 90 degrees from the opening to be in a non-operation position and then the swivel joint may be locked to keep the plug nut from swaying.', 'While 90 degrees is used, the degree of rotation is not limited to 90 degrees and may be any degree necessary to clear the opening without departing from the scope of the present disclosure.', 'With the plug nut removed from the opening, the filter may be removed from the fluid conduit through the opening.', 'In some embodiments, a filter extracting tool may be used to extract the filter through the opening.', 'Once the filter is removed, a spare or new filter may be inserting into the fluid conduit through the opening.', 'With the spare or new filter set in the fluid conduit, the swivel joint of the second arm may be unlocked so that the second arm may rotate back to position the plug nut in front of the opening.', 'Then the swivel joint of the arm and a swivel joint of the second arm are used to re-align the plug nut with the opening to then rotate the hand-wheel to screw the plug nut back into the opening.', 'With the plug nut sealingly closing the opening, fluids may flow through the spare or new filter without leaks from the opening.', 'While the foregoing is directed to embodiments of the present invention, other and further embodiments of the present disclosure may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.']

['1.', 'A plug removal tool, comprising:\na mount for attaching the plug removal tool to a structure;\na plug nut; and\nan arm assembly extending between the mount and the plug nut, the arm assembly having at least one translational degree of movement and at least one rotational degree of movement, wherein the arm assembly comprises:\na first arm; and\na second arm configured to slide along the first arm via a translational joint, wherein the translational joint comprises a first bearing above the first arm and a second bearing below the first arm, and wherein the second arm is oriented at a fixed angle relative to the first arm\nwherein the fixed angle is an acute angle relative to the first arm.', '2.', 'The plug removal tool of claim 1, wherein:\nthe mount comprises a mounting bracket that comprises a first swivel joint;\nthe first arm extends from a first end to a second end, wherein the first end is attached to the first swivel joint;\nthe second arm slidably attaches to the first arm between the first end and the second end via the translational joint; and\na second swivel joint connects to a distal end of the second arm and attaches to the plug nut.', '3.', 'The plug removal tool of claim 2, wherein the second swivel joint has an axis of rotation about which a second mounting bracket rotates.', '4.', 'The plug removal tool of claim 2, wherein the first swivel joint has a first axis of rotation about which the first arm rotates.', '5.', 'The plug removal tool of claim 4, wherein the second swivel joint has a second axis of rotation, parallel to the first axis of rotation of the first swivel joint, about which the second mounting bracket rotates.', '6.', 'The plug removal tool of claim 1, further comprising a hand-wheel attached to the plug nut, wherein the hand-wheel is configured to rotate the plug nut.', '7.', 'The plug removal tool of claim 1, wherein the plug nut comprises a nut and a plug, the plug is configured to extend through an opening into a fluid conduit, the nut is configured to couple to an outer circumference of a fluid conduit, the arm assembly is coupled to the plug via a mounting bracket, a hand-wheel is coupled to the nut, and the nut is configured to rotate relative to the plug.', '8.', 'A method for removing a filter in a fluid conduit, comprising:\nremoving a plug nut from an opening of the fluid conduit;\nsupporting the plug nut with a plug removal tool coupled to a mount, thereby defining a limited movement of the plug nut while removed from the opening, wherein the plug removal tool comprises an arm assembly extending between the mount and the plug nut, the arm assembly having at least one translational degree of movement and at least one rotational degree of movement, wherein the arm assembly comprises a first arm, and a second arm configured to slide along the first arm via a translational joint, wherein the translational joint comprises a first bearing above the first arm and a second bearing below the first arm, and wherein the second arm is oriented at a fixed angle relative to the first arm and wherein the fixed angle is an acute angle relative to the first arm; and\nremoving the filter through the opening of the fluid conduit.', '9.', 'The method of claim 8, wherein the removing of the plug nut comprises rotating a hand-wheel attached to the plug nut to unscrew the plug nut from the opening.\n\n\n\n\n\n\n10.', 'The method of claim 9, further comprising sliding the second arm of the plug removal tool to correspond with an axial movement of the plug nut.', '11.', 'The method of claim 9, wherein the rotating of the arm assembly comprises rotating the arm assembly about an axis of rotation of a swivel joint attached to an end of the arm assembly.\n\n\n\n\n\n\n12.', 'The method of claim 9, further comprising rotating the plug nut 90 degrees from the opening.\n\n\n\n\n\n\n13.', 'The method of claim 8, further comprising rotating the arm assembly of the plug removal tool to have the plug nut in non-operation position.\n\n\n\n\n\n\n14.', 'A system, comprising:\na modular skid having a fluid conduit, wherein the fluid conduit has a fluid inlet and a fluid outlet; and\nat least one plug removal tool removably attached to the modular skid, wherein the plug removal tool comprises:\na mounting bracket that comprises a first swivel joint;\na first arm extending from a first end to a second end, wherein the first end is attached to the first swivel joint;\na second arm slidably attached to the first arm at a fixed angle between the first end and the second end via a translational joint, wherein the translational joint comprises a first bearing above the first arm and a second bearing below the first arm, and wherein the fixed angle is an acute angle relative to the first arm;\na second swivel joint connected to a distal end of the second arm; and\na plug nut attached to the second swivel joint, wherein the plug removal tool is configured to remove or insert the plug nut from an opening of the fluid conduit.\n\n\n\n\n\n\n15.', 'The system of claim 14, further comprising at least one filter in fluid communication with the fluid conduit, wherein the filter is configured to filter a fluid flowing through the fluid conduit, and wherein the filter is accessed through the opening of the fluid conduit.', '16.', 'The system of claim 15, wherein the modular skid is a plug and trash catcher skid and the filter is disposed in a pot attached to the fluid conduit, wherein the opening is at an end of the pot.', '17.', 'The system of claim 16, wherein the plug removal tool is mounted on top of the pot.', '18.', 'The system of claim 14, further comprising at least one filter extractor removably attached to the modular skid, wherein the filter extractor is configured to remove a filter when the plug removal tool has removed the plug nut from the opening.\n\n\n\n\n\n\n19.', 'The system of claim 14, wherein the first and second swivel joints have parallel axes of rotation.']

['FIG.', '1 is a perspective view of a plug removal system in accordance with the prior art.; FIG.', '2 is a perspective view of a plug removal tool in accordance with one or more embodiments of the present disclosure.; FIGS.', '3', 'and 4 are a perspective view of a modular skid with the plug removal tool of FIG.', '2 in accordance with one or more embodiments of the present disclosure.', '; FIG.', '5A is a side view of the plug removal tool of FIG.', '3 in accordance with one or more embodiments of the present disclosure.', '; FIG.', '5B is a cross-sectional view along line 5B-5B in FIG.', '5A in accordance with one or more embodiments of the present disclosure.']

US11814928

Isolation valves

Nov 4, 2019

Ganesh Balasubramanian, Ashish Sharma

SCHLUMBERGER TECHNOLOGY CORPORATION

International Preliminary Report on Patentability issued in PCT application PCT/US2019/059633 dated May 20, 2021, 9 pages.; International Search Report and Written Opinion issued in PCT application PCT/US2019/059633, dated Apr. 7, 2020 (12 pages).; Frangibolt—Aerospace, http://www.tinialloy.com/aero.htm, downloaded on May 4, 2021 (5 pages).

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Foreign Citations not found.

['A valve assembly that can be deployed in a subterranean well that includes a valve adapted to selectively isolate a region of the subterranean well, and a separating apparatus.', 'The separating apparatus may further include at least one member being formed from a functional material and at least two sleeves connected by the at least one member.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'The present document is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/755,901, filed Nov. 5, 2018, which is incorporated herein by reference in its entirety.\n \nBACKGROUND OF THE DISCLOSURE', 'The invention generally relates to systems and techniques to actuate isolation valves, such as formation isolation valves, for example.', 'A formation isolation valve may be used in a well for such purposes as preventing fluid loss and controlling an underbalanced condition.', 'The valve forms a controllable sealed access to formations below the valve.', 'When the valve is open, well equipment (a tubular string, a wireline system, a slickline system, etc.) may be deployed through the valve for purposes of performing one or more testing, perforating and/or completion functions below the valve.', 'After these functions are complete, the well equipment may be retrieved, and the valve may be subsequently closed.', 'For purposes of opening and closing the valve, an intervention may be performed.', 'In the intervention, a tool, such as a shifting tool, is run downhole into the well to engage and change the state of the valve.', 'More specifically, the shifting tool interacts with a mechanical section of the valve.', 'The mechanical section typically is tied to a barrier valve element (a ball valve element, for example) of the valve so that linear motion of the shifting tool (caused by controlled movement of a string connected to the shifting tool, for example) acts to either directly or indirectly open or close the valve element.', 'In addition, the mechanical section holds the valve element in position (i.e., keeps the valve either open or closed) after the shifting tool is removed from the valve.', 'After the formation isolation valve is closed, the well may be suspended for days or months.', 'A well intervention typically consumes a significant amount of time and money.', 'Therefore, interventionless techniques have been developed to operate the formation isolation valve.', 'For example, a conventional formation isolation valve may include a chamber that has precharged nitrogen, which acts as a gas spring for purposes of providing downhole power to operate the valve.', 'More specifically, a control mechanism (a J-slot-based mechanism, for example) of the valve, which limits expansion of the nitrogen, may also be used that controls opening and closing of the valve by manipulating the well pressure.', 'After a given sequence of well pressure fluctuations, the control mechanism allows the nitrogen to expand to push a piston for purposes of rotating a ball valve element of the valve open.', 'A potential challenge in using the above-described formation isolation valve with precharged nitrogen is that the gas chamber of the valve typically is charged on the rig floor next to rig personnel before the valve is run downhole and installed.', 'In addition, under certain well conditions, the well pressure may exceed the rating of the tools in the well or the rating of the ball valve element during the sequence of pressure fluctuations.', 'Thus, there exists a continuing need for better ways to remotely actuate a downhole tool, such as a formation isolation valve, for example.', 'SUMMARY OF THE DISCLOSURE', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure introduces a valve assembly usable in a subterranean well, comprising: a valve adapted to selectively isolate a region of the subterranean well; and a separating apparatus comprised of: at least one member being formed from a functional material and at least two sleeves connected by the at least one member.', 'The present disclosure further introduces a method including sending an electrical signal to a separator apparatus comprised of a heating device member and at least one member comprised of a functional material, the at least one heating device member connected to the at least one member comprised of the functional material.', 'The method also includes converting the electrical signal into thermal energy using the heating device member such that the at least one member separates into a plurality of pieces, and separating a first sleeve from a second sleeve such that a mandrel connected to the second sleeve is released.', 'The method also includes transitioning a valve from a first state to a second state within a subterranean formation.', 'These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the material herein and/or practicing the principles described herein.', 'At least some aspects of the present disclosure may be achieved via means recited in the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is understood from the following detailed description when read with the accompanying figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n depicts a schematic diagram of a formation isolation valve assembly at least according to at least a portion of an example implementation according to one or more aspects of the present disclosure.', 'FIGS.', '2\n-\n3\n depict more detailed schematic diagrams of sections of a formation isolation valve assembly according to at least a portion of an example implementation according to one or more aspects of the present disclosure.', 'DETAILED DESCRIPTION', 'It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments.', 'Specific examples of components and arrangements are described below to simplify the present disclosure.', 'These are, of course, merely examples and are not intended to be limiting.', 'In addition, the present disclosure may repeat reference numerals and/or letters in the various examples.', 'This repetition is for simplicity and clarity, and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.', 'Moreover, the formation of a first feature over or on a second feature in the description that follows may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.', 'In the following description, numerous details are set forth to provide an understanding of the present disclosure.', 'However, it may be understood by those skilled in the art that the methods of the present disclosure may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', "At the outset, it should be noted that in the development of any such actual embodiment, numerous implementation-specific decisions may be made to achieve the developer's specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort might be complex and time consuming but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'In the summary and this detailed description, each numerical value should be read once as modified by the term “about” (unless already expressly so modified), and then read again as not so modified unless otherwise indicated in context.', 'Also, in the summary and this detailed description, it should be understood that a range listed or described as being useful, suitable, or the like, is intended to include support for any conceivable sub-range within the range at least because every point within the range, including the end points, is to be considered as having been stated.', 'For example, “a range of from 1 to 10” is to be read as indicating each possible number along the continuum between about 1 and about 10.', 'Furthermore, one or more of the data points in the present examples may be combined together, or may be combined with one of the data points in the specification to create a range, and thus include each possible value or number within this range.', 'Thus, (1) even if numerous specific data points within the range are explicitly identified, (2) even if reference is made to a few specific data points within the range, or (3) even when no data points within the range are explicitly identified, it is to be understood (i) that the inventors appreciate and understand that any conceivable data point within the range is to be considered to have been specified, and (ii) that the inventors possessed knowledge of the entire range, each conceivable sub-range within the range, and each conceivable point within the range.', 'Furthermore, the subject matter of this application illustratively disclosed herein suitably may be practiced in the absence of any element(s) that are not specifically disclosed herein.', 'Referring to \nFIG.', '1\n, an embodiment of a formation isolation valve assembly \n100\n in accordance with the present disclosure controls access to a region of a well below the valve assembly \n100\n.', 'In this manner, the valve assembly \n100\n allows a string, such as a string \n101\n, to pass through the valve assembly \n100\n to the region beneath the valve assembly \n100\n when the valve assembly \n100\n is in an open state (as depicted in \nFIG.', '1\n), and when the valve assembly \n100\n is in a closed state, the valve assembly \n100\n seals off communication with the region beneath the valve assembly \n100\n.', 'An annular region, or annulus \n102\n, that is located between an exterior surface of the valve assembly \n100\n and a production tubing \n103\n of the well may be sealed off by a packer (not shown).', 'More specifically, in some embodiments of the present disclosure, the valve assembly \n100\n includes a ball valve \n104\n that assumes an open state for the string \n101\n to pass through the valve assembly \n100\n and assumes a closed state to seal off the region below the valve assembly \n100\n when the string \n101\n no longer extends through the ball valve \n104\n.', 'In some embodiments, when the formation isolation valve assembly \n100\n is first set in place downhole, the ball valve \n104\n may be opened (or run into the well bore open) to permit the string \n101\n to pass through.', 'Alternatively, the formation isolation valve assembly \n100\n may be run with the string \n101\n already included through the ball valve \n104\n.', 'The string \n101\n may include a gravel packing tool to perform gravel packing operations downhole.', 'After the gravel packing operations are complete, the string \n101\n may be withdrawn from the well bore.', 'After the gravel packing operation is complete, the ball valve \n104\n is closed.', 'In this manner, the string \n101\n may include a shifting tool \n105\n (near a lower end of the string \n101\n) to physically close the ball valve \n104\n.', 'More specifically, after lower end of the string \n101\n is retracted above the ball valve \n104\n, a profiled section \n106\n of the shifting tool \n105\n engages (as described below) the valve assembly \n100\n and is operated in a manner (described below) to cause the ball valve \n104\n to close.', 'The valve assembly \n100\n also includes an operator mandrel \n107\n that moves up in response to applied tubing pressure (in the central passageway of the assembly \n100\n) and moves down when trigger mechanism (described below) is released.', 'The downward travel of the operator mandrel \n107\n causes the mandrel \n107\n to contact a collet actuator \n108\n that is engaged with a ball valve operator mandrel \n109\n that, in turn, operates the ball valve \n104\n.', 'In this manner, the downward movement of the operator mandrel \n107\n causes the ball valve operator mandrel \n109\n to move in a downward direction to open the ball valve \n104\n.', 'In other embodiments, to close the ball valve \n104\n via the shifting tool \n105\n, the profiled section \n106\n of the shifting tool \n105\n engages (as described below) the collet actuator \n108\n to force the collet actuator \n108\n up and down.', 'On each upward stroke, the collet actuator \n108\n disengages from the ball valve operator mandrel \n109\n, as described below.', 'When the ball valve operator mandrel \n109\n moves up by a predetermined distance, the mandrel \n109\n closes the ball valve \n104\n.', 'After the cycles occur, the ball valve operator mandrel \n109\n engages with the collet actuator \n108\n on the downstoke and remains engaged with the collet actuator \n108\n on the upstroke of the collet actuator \n108\n, thereby permitting the shifting tool \n105\n to lift the ball valve operator mandrel \n109\n up for a sufficient distance to close the ball valve \n104\n.', 'The shifting tool \n105\n has nothing to do with the cycling mechanism of the ball valve \n104\n.', 'The shifting tool \n105\n is used when the cycling mechanism fails or in formation isolation valves with no cycling mechanism.', 'The cycling mechanism on the other hand is used to open the ball valve \n104\n remotely without intervention (by using any tool).', 'Both are independent of each other.', 'The ball valve \n104\n can be opened or closed independently by the shifting tool \n105\n.', 'The shifting tool \n105\n has the necessary profiles to shift the ball valve operator mandrel \n109\n downhole to open the ball valve \n104\n and shift the ball valve operator mandrel \n109\n uphole to close the ball valve \n104\n.', 'Referring to the formation isolation valve assembly \n100\n in more detail, \nFIGS.', '2\n, and \n3\n depict sections \n100\nA and \n100\nB that form a section (of the valve assembly \n100\n) that houses the release module \n200\n and the mandrel \n107\n.', 'The upper part of this section is formed from an upper housing section \n201\n that mates with a lower housing section \n202\n.', 'In this manner, the lower end of the upper housing section \n201\n is received into a bore in the upper end of the housing section \n202\n.', 'Both housing sections \n201\n and \n202\n are generally cylindrical and circumscribe a longitudinal axis of the valve assembly \n100\n.', 'In other embodiments and illustrated in \nFIG. \n2\n., the upper housing \n201\n contains the release module \n200\n.', 'The release module \n200\n is an example of a type of separating apparatus, which may contain of one or more fracturing bolts \n205\n arranged longitudinally to circumscribe a vertical axis of the valve assembly \n100\n.', 'The fracturing bolt \n205\n is a type of coupling mechanism (e.g., pins, screw or rods) that is (1) configured to couple at least two objects together and (2) at a predetermined point in time, can be configured to separate or fracture.', 'As used herein the terms “separate” or “fracture” are defined to be the loss of a connecting mechanism such that after release, the object is in at least two separate pieces.', 'In this case, the fracturing bolt \n205\n couples at least two cages (actuator cage \n208\n and release cage \n209\n) together, which provide additional support, stability and security for the fracturing bolts \n205\n.', 'The fracturing bolt \n205\n is contained/secured in at least a portion of the actuator cage \n208\n and release cage \n209\n such that at least a portion of the fracturing bolt \n205\n is located on the surface of the actuator cage \n208\n and the release cage \n209\n.', 'The actuator cage \n208\n contacts the upper support sleeve \n206\n and the release cage \n209\n contacts the lower support sleeve \n207\n, the upper support sleeve \n206\n and the lower support sleeve \n207\n both being arranged about a longitudinal axis of the valve assembly \n100\n.', 'The fracturing bolt \n205\n may be comprised of a threaded or unthreaded cylindrical shaft having an optional head member attached to the cylindrical shaft.', 'Regardless of the head/shaft arrangement, the shaft is comprised of a shaped memory alloy.', 'The fracturing bolt \n205\n is considered to be pre-strained or pre-loaded to a predetermined strain value.', 'In other words, the fracturing bolt \n205\n is pre-strained when its structure has been deformed using an applied force.', 'For example, the fracturing bolt \n205\n may be pre-strained by applying a sufficient force to both ends of the bolt causing the deformation (i.e., shrinking) of the fracturing bolt \n205\n.', 'The fracturing bolt \n205\n may be comprised of a functional material such as a shape memory material in the martensitic phase at ambient and operating temperatures.', 'Other examples of functional materials include piezoelectric materials, magnetostriction materials, electrorheological fluids and shaped memory plastics.', 'Upon receiving an electrical signal from the one or more wires \n203\n, the heating connector \n204\n converts the received electrical signal to a heat source (joule heating) causing a phase change to a high temperature austenitic phase such that fracturing bolt \n205\n fractures (i.e., separates into at least two pieces and/or experiences a reduction in length).', 'This results in a crystal structure change in the grains of the bolt material, causing the fracturing bolt \n205\n to shorten in length.', 'Since the fracturing bolt \n205\n is secured at both the ends to the actuator cage \n208\n and the release cage \n209\n respectively, it results in its fracture, thereby releasing the operator mandrel \n107\n and opening the ball valve \n104\n.', 'According to one or more embodiments of the present disclosure, the electrical signal can be sent to the release module \n200\n through a control line or wire \n203\n running from surface to the isolation valve downhole that is directly connected to the release module \n200\n, to enable fracturing of the fracturing bolt \n205\n at the desired time.', 'In alternative embodiments, a battery pack (not shown) can also be built into the smart release module \n200\n that can be activated remotely through a radiofrequency signal from the surface to provide the necessary electrical voltage required for fracturing the bolt.', 'As discussed above, the operator mandrel \n107\n moves up in response to applied tubing pressure in a central passageway \n210\n of the valve assembly \n100\n.', 'However, the fracturing of the fracturing bolt \n205\n separates the connection between the upper support sleeve \n206\n and the lower support sleeve \n207\n causing the operator mandrel \n107\n to move down in response to the pressure exerted by a gas chamber \n301\n (\nFIG.', '3\n).', 'The gas chamber \n301\n, in some embodiments, is formed from an annularly recessed cavity located between the upper housing section \n201\n and the operator mandrel \n107\n.', 'The gas chamber \n301\n, in other embodiments of the invention, may include either atmospheric pressure or compressed nitrogen gas.', 'However, in other embodiments, the gas chamber \n301\n may be replaced by a compression spring or another type of spring, which would enable mechanical engagement with the downhole sections discussed above to open the ball valve \n104\n of the valve assembly \n100\n.', 'The responsiveness of the operator mandrel \n107\n to the tubing pressure and the pressure that is exerted by the gas in the chamber \n301\n is attributable to an upper annular surface \n302\n of the mandrel \n107\n that is in contact with the gas in the gas chamber \n301\n and a lower annular surface \n303\n of the ball valve operator mandrel \n109\n that is in contact with the fluid in the central passageway \n210\n.', 'Therefore, when the fluid in the central passageway \n210\n exerts a force (on the lower annular surface \n303\n) that is sufficient to overcome the force that the gas in the chamber \n301\n exerts on the upper annular surface \n302\n, a net upward force is established on the mandrel \n107\n.', 'Otherwise, a net downward force is exerted on the mandrel \n107\n (i.e., piston effect) to force the ball valve operator mandrel \n109\n down.', 'In other words, the potential energy stored in the chamber \n301\n in the form of compressed nitrogen gas or spring pushes the ball valve operator mandrel \n109\n downhole like a piston.', 'This causes the ball valve operator mandrel \n109\n to engage and push a latch nut and other connected mandrels (not shown) in the mechanical section of the valve assembly.', 'Referring to \nFIG.', '3\n, the mandrel \n107\n includes an exterior annular notch to hold O-rings \n304\n to seal off the bottom of the gas chamber \n301\n.', 'O-rings \n305\n are also located in an interior annular notch of the upper housing section \n201\n (see \nFIG.', '3\n) to form a seal between the upper housing \n201\n and the operator mandrel \n107\n to seal off the gas chamber \n301\n.', 'O-rings \n306\n form a seal between the upper housing sections \n201\n and the lower housing section \n202\n.', 'In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces a valve assembly usable in a subterranean well, comprising: a valve adapted to selectively isolate a region of the subterranean well; and a separating apparatus comprised of: at least one member being formed from a functional material and at least two sleeves connected by the at least one member.', 'For example, the separating apparatus may further comprise a heating device member connected to the at least one member.', 'The separating apparatus may further comprise an electrical wire connected to the heating device member such that when an electrical current is applied to the heating device member, the at least two sleeves are no longer connected by the at least one member.', 'The separating apparatus may further comprise an actuator cage and a release cage, the actuator cage and the release cage being arranged longitudinally about a vertical axis of the valve assembly.', 'For example, the valve assembly may further comprise a mandrel to be operated by pressure to transition the valve from a first state to a second state.', 'The first state is a closed state and the second state is an open state.', 'The valve assembly may also comprise a charge chamber located between a mandrel and a housing of the valve assembly, wherein the charge chamber contains atmospheric pressure, compressed nitrogen or a compression spring.', 'The functional material may be a material selected from the group consisting of shaped memory alloys, piezoelectric materials, magnetostriction materials, electrorheological fluids, shaped memory plastics and combinations thereof.', 'The present disclosure also introduces a method comprising: sending an electrical signal to a separator apparatus comprised of a heating device member and at least one member comprised of a functional material, the at least one heating device member connected to the at least one member comprised of the functional material; converting the electrical signal into thermal energy using the heating device member such that the at least one member separates into a plurality of pieces; separating a first sleeve from a second sleeve such that a mandrel connected to the second sleeve is released; and transitioning a valve from a first state to a second state within a subterranean formation.', 'For example, the mandrel may be operated by pressure to transition the valve from a first state to a second state such that the first state is a closed state and the second state is an open state.', 'The sending may further comprise sending an electrical signal via one or more wires connected to the separator apparatus, or sending a wireless electrical signal to the separator apparatus.', 'The valve may be a formation isolation valve.', 'The separating apparatus may further comprise an actuator cage and a release cage, the actuator cage and the release cage being arranged longitudinally about a vertical axis of the valve assembly.', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ or ‘step for’ together with an associated function without the recitation of structure.', 'The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure.', 'A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same functions and/or achieving the same benefits of the embodiments introduced herein.', 'A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.', 'The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. § 1.72(b) to permit the reader to quickly ascertain the nature of the technical disclosure.', 'It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.']

['1.', 'A valve assembly usable in a subterranean well, comprising:\na valve adapted to selectively isolate a region of the subterranean well and comprising a mandrel selectively releasable to operate the valve; and\na separating apparatus comprised of:\na first sleeve;\na second sleeve coupled to the mandrel;\na member being formed from a functional material and extending through the first sleeve and the second sleeve to couple the first sleeve to the second sleeve and restrain the mandrel; and\na heating device member connected to the member and operable to heat the member when an electrical current is applied to the heating device member to fracture the member and decouple the first sleeve from the second sleeve to release the mandrel.', '2.', 'The valve assembly of claim 1, wherein the separating apparatus further comprises an electrical wire connected to the heating device member such that when an electrical current is applied to the heating device member, the first sleeve and the second sleeve are no longer connected by the member.', '3.', 'The valve assembly of claim 1, wherein the separating apparatus further comprises an actuator cage and a release cage, the actuator cage and the release cage being arranged longitudinally about a vertical axis of the valve assembly.', '4.', 'The valve assembly of claim 1, wherein the valve assembly further comprises a mandrel to be operated by pressure to transition the valve from a first state to a second state.', '5.', 'The valve assembly of claim 4, wherein the first state is a closed state and the second state is an open state.', '6.', 'The valve assembly of claim 1, further comprising a charge chamber located between the mandrel and a housing of the valve assembly.', '7.', 'The valve assembly of claim 6, wherein the charge chamber contains atmospheric pressure or compressed nitrogen.', '8.', 'The valve assembly of claim 6, wherein the charge chamber contains a compression spring.', '9.', 'The valve assembly of claim 1, wherein the functional material is a material selected from the group consisting of shaped memory alloys, piezoelectric materials, magnetostriction materials, electrorheological fluids, shaped memory plastics and combinations thereof.', '10.', 'The valve assembly of claim 1, wherein the functional material is a shaped memory alloys.', '11.', 'A method comprising:\nsending an electrical signal to a separator apparatus comprised of a heating device member and a member comprised of a functional material, the heating device member connected to the member comprised of the functional material and the member extending through a first sleeve of the separator apparatus and a second sleeve of the separator apparatus to couple the first sleeve to the second sleeve and restrain a mandrel connected to the second sleeve;\nconverting the electrical signal into thermal energy using the heating device member such that the member fractures into a plurality of pieces to decouple the first sleeve from the second sleeve such that the mandrel is released; and\ntransitioning a valve from a first state to a second state within a subterranean formation via the released mandrel.\n\n\n\n\n\n\n12.', 'The method of claim 11, wherein the mandrel is operated by pressure to transition the valve from a first state to a second state.', '13.', 'The method of claim 11, wherein the first state is a closed state and the second state is an open state.', '14.', 'The method of claim 11, wherein the sending comprises sending an electrical signal via one or more wires connected to the separator apparatus.', '15.', 'The method of claim 11, wherein the sending comprises sending a wireless electrical signal to the separator apparatus.', '16.', 'The method of claim 11, wherein the functional material is a material selected from the group consisting of shaped memory alloys, piezoelectric materials, magnetostriction materials, electrorheological fluids, shaped memory plastics and combinations thereof.', '17.', 'The method of claim 11, wherein the functional material is a shaped memory alloys.', '18.', 'The method of claim 11, wherein the valve is a formation isolation valve.', '19.', 'The method of claim 11, wherein the separating apparatus further comprises an actuator cage and a release cage, the actuator cage and the release cage being arranged longitudinally about a vertical axis of the valve.']

['FIG.', '1 depicts a schematic diagram of a formation isolation valve assembly at least according to at least a portion of an example implementation according to one or more aspects of the present disclosure.; FIGS.', '2-3 depict more detailed schematic diagrams of sections of a formation isolation valve assembly according to at least a portion of an example implementation according to one or more aspects of the present disclosure.']

US11898415

Cement compositions and methods

Jun 28, 2019

Anatoly Vladimirovich Medvedev, Dominic Vincent Perroni, Laure Martin-Al-Khatib, Adam Ethan Keilers, Petr Kolchanov

SCHLUMBERGER TECHNOLOGY CORPORATION

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['Cement slurries are prepared that comprise water, a hydraulic cement and particles of an oil-absorbent material.', 'The particles are present in an amount sufficient to alter a property of a non-aqueous drilling fluid.', 'The cement slurry is placed in a subterranean well, whereupon the slurry contacts residual drilling fluid on casing and formation surfaces.', 'The oil-absorbent material in the cement slurry may reduce the mobility of the drilling fluid, thereby improving zonal isolation.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application is a nonprovisional application that claims the benefit of U.S. Provisional application No. 62/693,173, filed on Jul. 2, 2018, entitled “Cement Compositions and Methods.”\n \nTECHNICAL FIELD', 'The present disclosure relates generally to cement systems.', 'In particular, the disclosure relates to cement systems that contact drilling fluids within a subterranean well.', 'BACKGROUND', 'The statements in this section merely provide background information related to the present disclosure and may not constitute prior art.', 'During the construction of a subterranean well it is common, during and after drilling, to place a tubular body (e.g., liner or casing) in the well, secured by cement pumped into the annulus around the outside of the liner.', 'The cement supports the tubular body and provides hydraulic isolation of the various fluid-producing zones through which the well passes.', 'This latter function is important because it prevents fluids from different layers contaminating each other.', 'For example, the cement prevents formation fluids from entering the water table and polluting drinking water, or prevents water production instead of oil or gas.', 'A complete discussion of cementing techniques may be found in the following publication.', 'Nelson EB and Guillot D (eds.):', 'Well Cementing \n—2nd Edition, Houston, Schlumberger (2006).', 'Drilling fluid removal has been a subject of interest in the well-cementing community for many years because of its effect on cement quality and zonal isolation.', 'The principal objective of a primary cement job is to provide complete and permanent isolation of the formations behind the casing.', 'To meet this objective, the drilling mud and the preflushes (if any) should be fully removed from the annulus, and the annular space must be completely filled with cement slurry.', 'Once in place, the cement may harden and develop the necessary mechanical properties to maintain a hydraulic seal throughout the life of the well.', 'Therefore, efficient mud removal and proper slurry placement promote well isolation.', 'Incomplete removal of drilling fluids within a wellbore may affect the quality of hydraulic cement placement in the wellbore annulus resulting in incomplete zonal isolation.', 'This may occur particularly in horizontal wellbores where poorly centralized casing may increase the likelihood that gelled mud channels may form.', 'Compromised zonal isolation may increase the potential for fluid flow along the casing at applied pressure gradient.', 'Later in the life of the well, such mud channels that have formed may serve as non-productive communication pathways between stages during a stimulation treatment.', 'The present disclosure provides well cementing systems that may provide additional zonal isolation by facilitating the removal or dispersion of residual drilling fluids, such as non-aqueous drilling fluids, within the wellbore.', 'Further, the cement compositions disclosed herein may interact with residual drilling fluids and alter the properties of such drilling fluids.', 'The present disclosure is particularly directed to drilling fluids, such as non-aqueous drilling fluids which range from diesel- or mineral oil-based fluids to synthetic-based systems.', 'Synthetic-based systems may contain synthetic hydrocarbons, ethers, esters or acetals.', 'The synthetic hydrocarbons may include linear paraffins, linear-α-olefins, poly-α-olefins and internal olefins.', 'The synthetic-based systems may be emulsions in which the hydrocarbon is the external phase.', 'SUMMARY', 'In an aspect, embodiments relate to methods for cementing a subterranean well.', 'A cement slurry may be prepared comprising water, a hydraulic cement and particles of an oil-absorbing material, wherein the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.', 'The cement slurry is placed in the subterranean well, causing the oil-absorbent material particles to contact the non-aqueous drilling fluid component, thereby altering the property of the non-aqueous component.', 'In a further aspect, embodiments relate to methods for establishing zonal isolation in a subterranean well.', 'A cement slurry may be prepared comprising water, a hydraulic cement and particles of an oil-absorbent material, wherein the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.', 'The cement slurry is placed in the subterranean', 'well wherein residual drilling fluid is present along casing and formation surfaces, causing the oil-absorbent material particles to contact the residual drilling fluid, thereby altering the property of the non-aqueous component and creating a hydraulic seal in the subterranean well.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\nA\n is a cross-sectional diagram depicting 100% casing centralization in a wellbore, according to the present disclosure.\n \nFIG.', '1\nB\n is a cross-sectional diagram depicting eccentric casing centralization, which may occur in deviated or horizontal well sections, according to the present disclosure.\n \nFIG.', '2\n is a cross-sectional diagram depicting a drilling fluid channel arising from poor casing centralization in a wellbore, according to the present disclosure.\n \nFIG.', '3\n is a diagram depicting a drilling fluid channel that has been deposited in the narrow region of an eccentric annulus and affected by a cement slurry of the present disclosure.\n \nFIG.', '4\n compares the rheological properties of diesel-based emulsion drilling fluids after exposure to cement slurries.', 'The yield point of a drilling fluid exposed to a cement slurry containing oil-absorbent particles was larger than that of a drilling fluid exposed to a comparative slurry that did not contain absorbent particles.', "The crossover points (stress) where the loss modulus was equal to the storage modulus were the fluids' yield points.", 'FIG.', '5\n depicts pressure test results for a conventional cement slurry and a cement slurry containing oil-absorbing particles.\n \nFIG.', '6\n depicts the viscosities of oils containing various oil-absorbent polymers.', "DETAILED DESCRIPTION\n \nAt the outset, it should be noted that in the development of any such actual embodiment, numerous implementations, such as specific decisions must be made to achieve the developer's specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort might be complex and time consuming but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'In addition, the composition used/disclosed herein can also comprise some components other than those cited.', 'In the summary of the disclosure and this detailed description, each numerical value should be read once as modified by the term “about” (unless already expressly so modified), and then read again as not so modified unless otherwise indicated in context.', 'Also, in the summary of the disclosure and this detailed description, it should be understood that a concentration range listed or described as being useful, suitable, or the like, is intended that any and every concentration within the range, including the end points, is to be considered as having been stated.', 'For example, “a range of from 1 to 10” is to be read as indicating each and every possible number along the continuum between about 1 and about 10.', 'Thus, even if specific data points within the range, or even no data points within the range, are explicitly identified or refer to only a few specific points, it is to be understood that inventors appreciate and understand that any and all data points within the range are to be considered to have been specified, and that inventors possessed knowledge of the entire range and all points within the range.', 'As discussed earlier, one indication of successful cement placement is complete drilling fluid removal.', 'Complete removal of non-aqueous drilling fluids, for example, may be challenging because such drilling fluids may leave casing and formation surfaces oil wet, which may negatively affect cement sheath bond quality.', 'It is known in the art that such drilling fluids may further contain clays, weighting agents or both.', 'During most cementing operations, casing \n1\n is present inside a wellbore having a wall \n2\n.', 'An annulus \n3\n is therefore present between the casing and the wellbore wall.', 'Optimal drilling-fluid removal may occur when the casing is fully centralized in the wellbore (\nFIG.', '1\na\n).', '100% casing centralization maximizes circulation efficiency because there are no narrow regions that may be resistant to fluid flow.', 'However, achieving 100% casing centralization may not be achievable in deviated or horizontal well sections (\nFIG.', '1\nb\n).', 'Due to gravity, the casing has a tendency to migrate toward a borehole wall.', 'As a result, during the cement placement process, when cement slurry \n4\n is pumped to fill the annulus, the eccentric casing position may lead to poor drilling-fluid displacement in the narrow portion of the casing/wellbore annulus, leaving a drilling-fluid channel \n5\n (\nFIG.', '2\n).', 'The present disclosure presents methods for altering drilling-fluid properties as well as achieving zonal isolation.', 'Embodiments may combat drilling fluid channels by interacting with the drilling fluid channels and altering properties of the drilling fluid channels.', 'In an aspect, embodiments relate to methods for cementing a subterranean well.', 'A cement slurry may be prepared comprising water, a hydraulic cement, and particles of an oil-absorbing material, wherein the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.', 'The cement slurry may be placed in the subterranean well, causing the oil-absorbent material particles to contact the non-aqueous drilling fluid component, thereby altering the property of the non-aqueous component.', 'The cement slurry may have a density between 8 lbm/gal and 25 lbm/gal, or between 10 lbm/gal and 24 lbm/gal.', 'In a further aspect, embodiments relate to methods for establishing zonal isolation in a subterranean well.', 'A cement slurry may be prepared comprising water, a hydraulic cement, and particles of an oil-absorbent material, wherein the particles are present in an amount sufficient to interact with a non-aqueous component of a drilling fluid and alter a property of the drilling fluid within the subterranean well.', 'The cement slurry is placed in the subterranean', 'well wherein residual drilling fluid is present along casing and formation surfaces, causing the oil-absorbent material particles to contact the residual drilling fluid, thereby altering the property of the non-aqueous component and creating a hydraulic seal in the subterranean well.', 'In an embodiment, an oil-absorbing material may be added to the cement slurry.', 'The oil-absorbing material may begin interacting with drilling fluid first at the interface between the drilling fluid and cement.', 'Not being bound to any theory, the oil absorbing material may promote oil diffusion into the set cement material.', 'Once oil from oil-based drilling fluid is absorbed or diffused into the cement, the rheological properties of the drilling fluid may change.', 'Consequently, the drilling fluid may be converted from a fluid-like material to a paste-like structure.', 'Such conversion inside the drilling-fluid channel may prevent fluid flow inside the channel and serve to provide zonal isolation.', 'In addition, oil-absorbing particles in the cement sheath may increase in size, physically blocking small channels or compressing a paste-like mud structure.', 'The oil-absorbent material may comprise rubber, ground rubber, acrylonitrile butadiene, styrene butadiene, 2,1 bicycloheptene, alkylstyrene, or crosslinked substituted vinyl acetate copolymer, combinations thereof, or the like.', 'In an embodiment, a process contributing to achieving zonal isolation may include dynamic removal of the mud channel during cement slurry displacement.', 'The oil-absorbing particles \n6\n flowing near the drilling fluid channel may physically remove a portion of the drilling fluid \n5\n and transport the portion away from the drilling fluid channel.', 'Thus, the particles may significantly reduce the size of the drilling fluid channel or even remove it (\nFIG. \n3\n).', 'In an embodiment, a material that viscosifies oil may be added to the cement slurry.', 'Oil-viscosifying particles may interact and diffuse into oil-based drilling fluid during placement or after the cement setting process, and viscosify the residual oil-based mud to an extent that zonal isolation is achieved.', 'Such cement compositions may contain a sufficient concentration of oil-viscosifying particles to increase the yield point (Ty) to a level higher than that of cement compositions that do not contain the oil-viscosifying particles.', 'The yield point increase may take place within three days of exposure, and the ultimate yield point measured by oscillatory rheometry may be at least 100 Pa.', 'In some cases, the yield point may rise to 4600 Pa (see Example 3).', 'Or the yield point may be between 500 Pa and 3000 Pa.', 'Or the yield point may be between 1000 Pa and 2000 Pa.', 'The higher the yield point, the better the zonal isolation may be.', 'Thus, one of the properties that may be altered by the non-aqueous component of the drilling fluid is flowability, and the oil-absorbent material decreases the flowability of the non-aqueous component.', 'The particle size of the block polymer particles may have a D90 of about 1 μm to 850 μm, or a D90 of about 300 μm to 800 μm.', 'For all embodiments, the cement slurry may comprise portland cement, high alumina cement, fly ash, blast furnace slag, microcement, geopolymers, chemically bonded phosphate ceramics, plaster or resins or combinations thereof.', 'The cement slurry further comprises polymers, random copolymers and block polymers comprising alternating sections of one chemical compound separated by sections of a different chemical compound, or a coupling group of low molecular weight.', 'For example, block polymers may have the structure (A-b-B-b-A), wherein A represents a block that is glassy or semi-crystalline and B is a block that is elastomeric.', 'In principle, A can be any polymer that is normally regarded as thermoplastic (e.g., polystyrene, polymethylmethacrylate, isotactic polypropylene, polyurethane, etc.), and B can be any polymer that is normally regarded as elastomeric (e.g., polyisoprene, polybutadiene, polyethers, polyesters, etc.).', 'Example thermoplastic block polymers include styrene-isoprene-styrene (SIS), styrene-butadiene-styrene (SBS) and mixtures thereof.', 'The block-polymer-additive may be in one or more shapes, including (but not limited to) spherical, ovoid, fibrous, ribbon-like and in the form of a mesh.', 'The tensile strength of the block polymer may vary between, but not be limited to, about 1.5 MPa and 40 MPa, or between 3.4 to 34 MPa, or between 2 MPa and 3.45 MPa or between 28 MPa and 34 MPa.', 'The thermoplastic block polymers may be present in the cement slurry at a concentration between about 5 lbm/bbl and 50 lbm/bbl.', 'The abbreviation “bbl” stands for barrels.', 'One barrel equals 42 US gallons.', 'Or the block polymer may be present in the cement slurry at a concentration 8 lbm/bbl and 15 lbm/bbl.', 'The particle size of the block polymer particles may be between about 1 μm and 850 μm, or between 300 μm and 800 μm.', 'The thermoplastic block-particles may be further associated with one or more compounds from the list comprising an emulsion of polymer comprising a betaine group, poly-2, 2, 1-bicyclo heptene (polynorbornene), alkylstyrene, crosslinked substituted vinyl acrylate copolymers, diatomaceous earth, natural rubber, vulcanized rubber, polyisoprene rubber, vinyl acetate rubber, polychloroprene rubber, acrylonitrile butadiene rubber, hydrogenated acrylonitrile butadiene rubber, ethylene propylene diene monomer, ethylene propylene monomer rubber, styrene-butadiene rubber, styrene/propylene/diene monomer, brominated poly(isobutylene-co-4-methylstyrene), butyl rubber, chlorosulfonated polyethylenes, polyacrylate rubber, polyurethane, silicone rubber, brominated butyl rubber, chlorinated butyl rubber, chlorinated polyethylene, epichlorohydrin ethylene oxide copolymer, ethylene acrylate rubber, ethylene propylene diene terpolymer rubber, sulfonated polyethylene, fluoro silicone rubbers, fluoroelastomers, substituted styrene acrylate copolymers and bivalent cationic compounds.', 'In addition to the aforementioned particles, the cement slurries may also comprise customary additives such as retarders, accelerators, extenders, fluid-loss-control additives, lost-circulation additives, gas-migration additives, gas-generating additives, expansion additives and antifoam agents.', 'Furthermore, the cement slurries may contain additives that enhance the flexibility and/or toughness of the set cement.', "Such additives include, but are not limited to, flexible particles having a Young's modulus below about 5000 MPa and a Poisson's ratio above about 0.3.", "Such particles may have a Young's modulus below about 2000 MPa.", 'Examples include, but are not limited to, non-swellable polypropylene, non-swellable polyethylene, acrylonitrile butadiene, styrene butadiene and polyamide.', 'Such additives may also include non-swellable fibers selected from the list comprising polyamide, polyethylene and polyvinyl alcohol.', 'Metallic microribbons may also be included.', 'In an embodiment, the oil-absorbent particles may be elongated, fibrous, cylindrical or asymmetrical.', 'Such particles with an aspect ratio higher than about 1 may interact and form an interconnected network inside the cement slurry.', 'The elongated shape may also improve the absorbing ability of the particles.', 'The higher aspect ratio increases the probability that the particles will contact each other throughout the cement slurry, allowing more efficient oil absorption and lower absorbent-particle concentrations to achieve a given result.', 'The particle aspect ratio may be between 1.1 and 2000, or 10 and 1500, or 15 and 1000 before swelling, and between 2.2 and 3500, or 4 and 1000, or 6 and 350 after swelling.', 'Furthermore, the temperature at which the disclosed fluids operate may be between 80° F. and 400° F., or between 100° F. and 375° F.', 'For all embodiments, the concentration of oil-absorbent particles may vary in the cement sheath.', 'This may be accomplished by varying the rate at which the oil-absorbent particles are added to the cement slurry during mixing and pumping.', 'Certain portions of the cement sheath may not contain oil-absorbent particles.', 'As long as there are regions along the cement sheath providing zonal isolation, the well as a whole may have a hydraulic seal.', 'For example, sections containing the oil-absorbent particles may be located above and below producing zones.', 'Under these circumstances, the concentration of the oil-absorbent particles may vary between 0% and 40% by weight of cement.', 'This approach may be more economical than scenarios where the oil-absorbent particles are present throughout the cement sheath.', 'EXAMPLES\n \nExample 1—Drilling Fluid Rheological Properties\n \nTwo 600-mL cement slurries were prepared in a Waring blender according to a mixing procedure published by the American Petroleum Institute (RP-10B).', 'The density of both slurries was 15 lbm/gal (1800 kg/m\n3\n).', 'Both slurries were prepared with Texas Lehigh Class H cement.', 'A comparative slurry composition is given in Table 1.\n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \n \n \nComparative cement slurry composition.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nAcrylamido-methyl-propane sulfonate (AMPS)/\n \n0.3%\n \nBWOC\n \n \n \n \nAcrylamide copolymer\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.1%\n \nBWOC\n \n \n \n \nPolysaccharide Biopolymer\n \n0.3%\n \nBWOC\n \n \n \n \nPolypropylene Glycol\n \n0.050\n \ngal/sk\n \n \n \n \nWater\n \n6.02\n \ngal/sk\n \n \n \n \n \n \n \n \nBWOC = by weight of cement;\n \n \n \n \nsk = 94-lb sack of portland cement.', 'AMPS = 2-acrylamido-2-methylpropane sulfonic acid.', 'A cement composition according to the disclosure is given in Table 2.', 'The cement slurry contained absorbing particles composed of ground rubber particles.', 'The particle size of the rubber varied between 100 μm and 800 μm.\n \n \n \n \n \n \n \n \nTABLE 2', 'Cement slurry composition according to the disclosure.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \nGround Rubber\n \n31.0%\n \nBVOB\n \n \n \nBarium Sulfate\n \n8.4%\n \nBVOB\n \n \n \nCrystalline Silica\n \n15%\n \nBVOB\n \n \n \nAMPS/Acrylamide copolymer\n \n0.3%\n \nBWOC\n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.4%\n \nBWOC\n \n \n \nPolysaccharide Biopolymer\n \n0.8%\n \nBWOC\n \n \n \nsodium glucoheptonate/crystalline silica/hematite\n \n0.5%\n \nBWOC\n \n \n \nPolypropylene Glycol\n \n0.1\n \ngal/sk\n \n \n \nSIS Copolymer\n \n1%\n \nBWOB\n \n \n \nWater\n \n4.27\n \ngal/sk\n \n \n \n \n \n \nBWOB = by weight of blend;\n \n \n \nBVOB = by volume of blend;\n \n \n \nSIS = styrene-isoprene-styrene\n \n \n \n \n \n \n \nBoth slurries were conditioned for 35 min at 168° F. in an atmospheric consistometer.', 'A representative 13 lbm/gal (1620 kg/m\n3\n) inverse emulsion drilling fluid was chosen that contained diesel as the continuous phase (MegaDril™, available from Schlumberger).', '15 mL of the conditioned slurry were placed at the bottom of a glass vial.', '5 mL of the drilling fluid was carefully added to the top of the conditioned slurry.', 'The glass vials were placed in a Turbiscan AGS instrument (available from Formulaction Inc., Worthington, Ohio) that was preheated to 140° F. (60° C.) and allowed to cure for 8 days.', 'During this time the slurry developed compressive strength, and the drilling fluid in contact with the slurry containing the absorbent particles increased its yield strength compared to that in contact with the comparative cement system.', 'To quantify this rheological change, the drilling fluids were extracted from the vials.', 'The yield strength was analyzed on a TA-DHR3 rheometer (available from TA Instruments, New Castle, Del.) in a parallel plate configuration.', 'An oscillatory amplitude sweep was conducted at 68° F. (20° C.) with an angular frequency of 10 rad/s and a logarithmic strain percent sweep from 0.01% to 100%.', 'The drilling fluid that was exposed to the absorbent slurry exhibited a yield strength in some cases approximately 65 times higher than that of the drilling fluid exposed to the comparative slurry under the same conditions (\nFIG.', '4\n)\n \nExample 2—Channel Flow Reduction\n \nApplicant developed a laboratory method to investigate the ability of absorbent containing cement slurry to reduce fluid flow in a drilling-fluid filled channel.', 'Two 600-mL cement slurries were prepared in a Waring blender.', 'The cement was Class H portland cement.', 'The density of both slurries was 14.5 lbm/gal (1740 kg/m\n3\n).', 'Both slurries were extended with fly ash.', 'A comparative slurry composition is given in Table 3.\n \n \n \n \n \n \n \n \nTABLE 3\n \n \n \n \n \n \n \n \nComparative cement slurry Composition.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nFly ash\n \n40\n \nlb/sk\n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.3%\n \nBWOB\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.3%\n \nBWOB\n \n \n \n \nPolysaccharide Biopolymer\n \n0.3%\n \nBWOB\n \n \n \n \nSilica Fume\n \n8.0%\n \nBWOB\n \n \n \n \nSodium Lignosulfonate\n \n0.3%\n \nBWOB\n \n \n \n \nPolypropylene Glycol\n \n0.050\n \ngal/sk\n \n \n \n \nWater\n \n5.91\n \ngal/sk\n \n \n \n \n \n \n \n \n \n \n A slurry composition according to the disclosure is given in Table 4. \n \n \n \n \n \n \n \n \nTABLE 4\n \n \n \n \n \n \n \n \nCement slurry composition according to the disclosure.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nFly ash\n \n40\n \nlb/sk\n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.3%\n \nBWOB\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.1%\n \nBWOB\n \n \n \n \nPolysaccharide Biopolymer\n \n0.3%\n \nBWOB\n \n \n \n \nPolypropylene Glycol\n \n0.050\n \ngal/sk\n \n \n \n \nSodium Lignosulfonate\n \n0.3%\n \nBWOB\n \n \n \n \nSilica Fume\n \n8.0%\n \nBWOB\n \n \n \n \nGround Rubber\n \n5.0%\n \nBWOC\n \n \n \n \nSIS Copolymer\n \n1%\n \nBWOB\n \n \n \n \nWater\n \n5.60\n \ngal/sk\n \n \n \n \n \n \n \n \n \n \n \nA 3-in.', 'long by 1-in.', 'wide steel pipe was capped on one end and filled with slurry and then capped on the other end.', 'Small vent holes were added to the caps to equalize the pressure during high pressure curing.', 'The pipes containing slurry were loaded into a curing chamber and were exposed to 170° F. (77° F.) and 3000 psi (21 MPa).', 'After the slurry had set, a hole was drilled in the cement leaving a channel of about ⅛-in.', '(0.3-cm) diameter.', 'The bottom of the hole was plugged, the channel was filled with 13-lbm/gal (1620-kg/m\n3\n)', 'MegaDril™ drilling fluid, and was allowed to set for 6 days at atmospheric conditions.', 'The permeability of the resulting mud channel was probed by the flow of water through the channel.', 'The flow rate was set at 1 mL/min and resulting pressure were measured using a Teledyne ISCO D-series syringe pump.', 'The results, presented in \nFIG.', '5\n, show that the cement prepared according to the present disclosure was 5 times more pressure resistant compared to the comparative cement.', 'The absorbent additive concentration could be adjusted to increase pressure even higher, up to 14 psi, if needed.', 'In order to scale the laboratory results to a real application, it could be calculated that 5 psi in a 3-in.', 'tube corresponds to 3000 psi at a 50-ft distance.', 'During another experiment, a 5-in.', 'long by 1-in.', 'wide steel pipe was capped on one end and filled with slurry.', 'Then a 3.175 mm diameter wooden dowel was placed in the setting cement slurry.', 'After 24 hours the dowel was removed and 13-lbm/gal (1620-kg/m\n3\n)', 'MegaDril™ drilling fluid was injected.', 'The interaction time between the drilling fluid and the cement slurry was 3 days.', 'The permeability of the resulting mud channel was probed by flowing water through the channel using a Teledyne ISCO D-series syringe pump.', 'A 14.5-lbm/gal slurry (Table 5) containing rubber particles was shown to hold a pressure of 4.58 psi/in (average of 6 duplicate runs) while a similar control 14.5 lbm/gal system (Table 6), held 0.48 psi/in (average of 3 duplicate runs).', 'TABLE 5\n \n \n \n \n \n \n \n \nCement slurry composition according to the disclosure.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nFly ash\n \n40\n \nlb/sk\n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.15%\n \nBWOB\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.5%\n \nBWOB\n \n \n \n \nPolysaccharide Biopolymer\n \n0.2%\n \nBWOB\n \n \n \n \nSilica Fume\n \n8.0%\n \nBWOB\n \n \n \n \nGround Rubber\n \n5%\n \nBWOC\n \n \n \n \nPolypropylene Glycol\n \n0.050\n \ngal/sk\n \n \n \n \nWater\n \n5.65\n \ngal/sk\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nTABLE 6\n \n \n \n \n \n \n \n \nComparative cement slurry composition.', 'Additive\n \nConcentration\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nFly ash\n \n40\n \nlb/sk\n \n \n \n \nAMPS/Acrylamide copolymer\n \n0.15%\n \nBWOB\n \n \n \n \nSodium Polynaphthalene Sulfonate\n \n0.5%\n \nBWOB\n \n \n \n \nPolysaccharide Biopolymer\n \n0.2%\n \nBWOB\n \n \n \n \nSilica Fume\n \n8.0%\n \nBWOB\n \n \n \n \nPolypropylene Glycol\n \n0.050\n \ngal/sk\n \n \n \n \nWater\n \n5.66\n \ngal/sk\n \n \n \n \n \n \n \n \n \n \n \nExample 3—Oil Viscosification', 'The ability of an absorbent particle to viscosify oil was investigated.', 'The absorbent particles were made of polystyrene-block-poly(ethylene-ran-butylene)-block-polystyrene and polystyrene-block-polybutadiene-block-polystyrene polymers (manufactured by Sigma-Aldrich Chemie GmbH, Steinheim, Germany).', 'The oil was LVT200 oil, a hydrotreated light distillate manufactured by Deep South Chemical, Inc., Broussard, La.', 'The following samples were investigated: 0.8 wt % and 5.8 wt % solutions of polystyrene-block-polybutadiene-block-polystyrene polymer (PS-PB) in LVT200 oil and 1 wt %, 2.8 wt %, 5.9 wt % solutions of polystyrene-block-poly(ethylene-ran-butylene)-block-polystyrene polymer (PS-PEPB-PS) in LVT200.', 'The viscosities of samples were measured by MCR300 rheometer from Anton Paar in parallel plate CC17 geometry (\nFIG.', '6\n).', 'The results show that the oil viscosities increase with polymer concentration.', 'The preceding description has been presented with reference to present embodiments.', 'Persons skilled in the art and technology to which this disclosure pertains will appreciate that alterations and changes in the described structures and methods of operation can be practiced without meaningfully departing from the principle, and scope of this present disclosure.', 'Accordingly, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.']

['1.', 'A method for cementing a subterranean well, comprising:\npreparing a cement slurry comprising water, a hydraulic cement and particles of an oil-absorbent material, wherein the particles absorb a non-aqueous component of a drilling fluid and alter rheological properties of the drilling fluid within the subterranean well, and wherein an amount of the oil-absorbent material particles varies, in portions of the cement slurry, between 0% by weight of the cement (BWOC) and 40% BWOC;\nplacing the cement slurry in the subterranean well and thereby creating a cement sheath in the subterranean well with a variable oil-absorbent material amount;\nallowing the oil-absorbent material particles to contact the non-aqueous drilling fluid component, thereby altering the rheological properties of the drilling fluid and swelling the oil-absorbent material particles;\nwherein the oil-absorbent material particles are elongated, having an aspect ratio between 1.1 and 2000 before the swelling and between 2.2 and 3500 after the swelling.', '2.', 'The method of claim 1, wherein the oil-absorbent material comprises rubber, ground rubber, acrylonitrile butadiene, styrene butadiene, 2,1 bicycloheptene, alkylstyrene, or crosslinked substituted vinyl acetate copolymer, or combinations thereof.', '3.', 'The method of claim 1, wherein the oil-absorbent material particles have a particle size between 1 μm and 850 μm.\n\n\n\n\n\n\n4.', 'The method of claim 1, wherein the rheological properties of the drilling fluid altered by contact with the oil-absorbent material particles comprise flowability, and wherein the oil-absorbent material particles decrease the flowability of the drilling fluid.', '5.', 'The method of claim 1, wherein the elongated particles interact in the subterranean well to form an interconnected network.', '6.', 'The method of claim 1, wherein the oil-absorbent material particles are present in an amount between 5 lbm/bbl and 50 lbm/bbl.', '7.', 'The method of claim 1, wherein the cement slurry has a density between 10 lbm/gal and 24 lbm/gal.\n\n\n\n\n\n\n8.', 'The method of claim 1, wherein the non-aqueous component comprises diesel, mineral oil, olefins, esters, synthetic paraffins, or refined paraffins, or combinations thereof.', '9.', 'A method for establishing zonal isolation in a subterranean well, comprising:\npreparing a cement slurry comprising water, a hydraulic cement, and particles of an oil-absorbent material, wherein the particles absorb a non-aqueous component of a residual drilling fluid present in the subterranean well along casing and formation surfaces thereof and alter rheological properties of the residual drilling fluid within the subterranean well, and wherein an amount of the oil-absorbent material particles varies, in portions of the cement slurry, between 0% by weight of the cement (BWOC) and 40% BWOC;\nplacing the cement slurry in the subterranean well and thereby creating a cement sheath in the subterranean well with a variable oil-absorbent material amount;\nallowing the oil-absorbent material particles to contact the residual drilling fluid, thereby altering the rheological properties of the drilling fluid and swelling the oil-absorbent material particles, wherein the oil-absorbent material particles are elongated, having an aspect ratio between 1.1 and 2000 before the swelling and between 2.2 and 3500 after the swelling.', '10.', 'The method of claim 9, wherein the oil-absorbent material comprises rubber, ground rubber, acrylonitrile butadiene, styrene butadiene, 2,1bicycloheptene, alkylstyrene, or crosslinked substituted vinyl acetate copolymer, or combinations thereof.', '11.', 'The method of claim 9, wherein the oil-absorbent material particles have a particle size between 1 μm and 850 μm.\n\n\n\n\n\n\n12.', 'The method of claim 9, wherein the rheological properties of the drilling fluid altered by contact with the oil-absorbent material particles comprise flowability, and wherein the oil-absorbent material particles decrease the flowability of the drilling fluid.', '13.', 'The method of claim 9, wherein the elongated particles interact in the subterranean well to form an interconnected network.', '14.', 'The method of claim 9, wherein the oil-absorbent material particles are present in an amount between 5 lbm/bbl and 50 lbm/bbl.', '15.', 'The method of claim 9, wherein the cement slurry has a density between 10 lbm/gal and 24 lbm/gal.\n\n\n\n\n\n\n16.', 'The method of claim 9, wherein the non-aqueous component comprises diesel, mineral oil, olefins, esters, synthetic paraffins, or refined paraffins, or combinations thereof.']

['FIG.', '1A is a cross-sectional diagram depicting 100% casing centralization in a wellbore, according to the present disclosure.', ';', 'FIG.', '1B is a cross-sectional diagram depicting eccentric casing centralization, which may occur in deviated or horizontal well sections, according to the present disclosure.', '; FIG.', '2 is a cross-sectional diagram depicting a drilling fluid channel arising from poor casing centralization in a wellbore, according to the present disclosure.', '; FIG.', '3 is a diagram depicting a drilling fluid channel that has been deposited in the narrow region of an eccentric annulus and affected by a cement slurry of the present disclosure.', '; FIG.', '4 compares the rheological properties of diesel-based emulsion drilling fluids after exposure to cement slurries.', 'The yield point of a drilling fluid exposed to a cement slurry containing oil-absorbent particles was larger than that of a drilling fluid exposed to a comparative slurry that did not contain absorbent particles.', "The crossover points (stress) where the loss modulus was equal to the storage modulus were the fluids' yield points.", '; FIG.', '5 depicts pressure test results for a conventional cement slurry and a cement slurry containing oil-absorbing particles.', '; FIG.', '6 depicts the viscosities of oils containing various oil-absorbent polymers.']

USD1006820

Electronic device with display screen and graphical user interface

Jul 10, 2020

Zhen Li, Adelle Knight, Sacha Brants-Menard

SCHLUMBERGER TECHNOLOGY CORPORATION

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['No Abstract Available']

['Description\n\n\n\n\n\n\n \nThe patent or application file contains at least one drawing executed in color.', 'Copies of this patent or patent application publication with color drawing(s) will be provided by the Office upon request and payment of the necessary fee.\n \nFIG.', '1\n is a view of an electronic device with display screen and graphical user interface showing a first image of a notification color palette.', 'The claimed color in \nFIG.', '1\n is Red having a Hex Value of #DA3A3A.\n \nFIG.', '2\n is a second image thereof.', 'The claimed color in \nFIG.', '2\n is Yellow having a Hex Value of #FFDF22.\n \nFIG.', '3\n is a third image thereof.', 'The claimed color in \nFIG.', '3\n is Green having a Hex Value of #34836F; and,\n \nFIG.', '4\n is fourth image thereof.', 'The claimed color in \nFIG.', '4\n is Blue Grey having a Hex Value of #5A7793.', 'The appearance of the graphical user interface sequentially transitions between the images shown in \nFIGS.', '1\n, \n2\n, \n3\n, and \n4\n.', 'The process or period in which one image transitions to another image forms no part of the claimed design.', 'The even-dashed broken lines showing the electronic device with display screen and portions of the graphical user interface, including all text and icons shown outside the dot-dashed broken lines, illustrate portions of the article of manufacture.', 'The dot-dashed broken lines illustrate the bounds of the claimed design.', 'Text inside the dot-dashed broken lines is shown in broken lines, and forms no part of the claimed design.', 'None of the broken lines form part of the claimed design.']

['The ornamental design for an electronic device with display screen and graphical user interface, as shown and described.']

['FIG.', '1 is a view of an electronic device with display screen and graphical user interface showing a first image of a notification color palette.', 'The claimed color in FIG.', '1 is Red having a Hex Value of #DA3A3A.; FIG.', '2 is a second image thereof.', 'The claimed color in FIG.', '2 is Yellow having a Hex Value of #FFDF22.; FIG.', '3 is a third image thereof.', 'The claimed color in FIG.', '3 is Green having a Hex Value of #34836F; and,; FIG.', '4 is fourth image thereof.', 'The claimed color in FIG.', '4 is Blue Grey having a Hex Value of #5A7793.']

US11920422

Riser collet connector systems and methods

Aug 27, 2021

Harold Tenorio, John Zahl, Jon Tyler, Ross Stevenson

SCHLUMBERGER TECHNOLOGY CORPORATION

Combined Search and Exam Report issued in United Kingdom Patent Application No. GB2212516.5 dated Jan. 25, 2023, 7 pages.

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['A connector system includes a first riser joint configured to form part of a riser.', 'The first riser joint includes a pin.', 'The connector system also includes a connector configured to couple to a wellhead assembly.', 'The connector includes multiple collet segments that are configured to move radially-inwardly to engage the pin of the first riser joint.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThis section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'Natural resources, such as oil and gas, are used as fuel to power vehicles, heat homes, and generate electricity.', 'Once a desired resource is discovered below the surface of the earth, a drilling system is often employed to access the desired resource.', 'A subsea drilling system may include a riser that extends between a wellhead assembly at a sea floor and a platform (e.g., drilling rig or surface vessel) at a sea surface.', 'The riser is fluidly coupled to the wellhead assembly to enable the riser to carry fluid (e.g., drilling mud) from the wellhead assembly toward the platform.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein:\n \nFIG.', '1\n is a schematic diagram of a subsea drilling system, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\n is a perspective view of a portion of a riser that may be used in the subsea drilling system, in accordance with an embodiment of the present disclosure;\n \nFIG.', '3\n is a cross-sectional perspective view of the portion of the riser, in accordance with an embodiment of the present disclosure;\n \nFIG.', '4\n is a cross-sectional perspective view of the portion of the riser of and a connector of a lower marine riser package (LMRP), wherein the connector is in an open configuration, in accordance with an embodiment of the present disclosure;\n \nFIG.', '5\n is a cross-sectional perspective view of the portion of the riser of and the connector of the LMRP, wherein the connector is in a closed configuration, in accordance with an embodiment of the present disclosure; and\n \nFIG.', '6\n is a flow diagram of a method of coupling the riser to the LMRP via the connector, in accordance with an embodiment of the present disclosure.', 'DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS\n \nOne or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only exemplary of the present disclosure.', 'Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'The present disclosure is generally directed to a connector system that is configured to couple a riser of a subsea drilling system to a wellhead assembly (e.g., to a lower marine riser package [LMRP] of the wellhead assembly).', 'For example, the connector system may include a pin (e.g., pin section; extension) at a first end (e.g., distal end) of the riser, and a connector (e.g., collet connector) coupled to the wellhead assembly.', 'The pin may be inserted into the connector, and movable components (e.g., collet segments) of the connector may move (e.g., radially-inwardly) to engage the pin at the first end of the riser.', 'Advantageously, the pin at the first end of the riser may stab into the connector to efficiently form a connection between the riser and the wellhead assembly, and the pin at the first end of the riser may be withdrawn from the connector to efficiently break up the connection between the riser and the wellhead assembly.', 'While certain embodiments disclosed herein relate to the connector system to couple the riser to the wellhead assembly in off-shore (e.g., subsea) systems, it should be understood that the connector system may be adapted to couple other tubular components to one another in off-shore systems and/or in on-shore (e.g., land-based) systems.', 'FIG.', '1\n is an embodiment of a subsea drilling system \n10\n.', 'To facilitate discussion, the subsea drilling system \n10\n and its components may be described with reference to an axial axis or direction \n4\n, a radial axis or direction \n6\n, and a circumferential axis or direction \n8\n.', 'As shown, the subsea drilling system \n10\n includes an offshore drilling rig or platform \n12\n at a sea surface \n14\n and a wellhead assembly \n16\n positioned at a sea floor \n18\n.', 'The wellhead assembly \n16\n includes a wellhead \n20\n, a blowout preventer (BOP) stack \n22\n, and a lower marine riser package (LMRP) \n24\n.', 'The BOP stack \n22\n may include one or more ram BOPs and the LMRP \n24\n may include one or more annular BOPs.', 'The LMRP \n24\n may also include or be coupled to a joint \n26\n (e.g., flex joint), which may include or be coupled to (e.g., via fasteners, such as threaded fasteners) a connector \n28\n (e.g., collet connector).', 'The connector \n28\n may be configured to receive and to couple (e.g., physically and fluidly couple) to a riser \n30\n (e.g., a drilling riser; tubular structure), which extends from the connector \n28\n toward the platform \n12\n.', 'Drilling operations may be carried out by a drill string \n32\n (e.g., tubular string) that extends from the platform \n12\n, through the riser \n30\n, through the connector \n28\n, through the wellhead assembly \n16\n, and into a wellbore \n34\n.', 'During drilling operations, drilling mud may flow through the drill string \n32\n, and the drilling mud may exit through openings at a distal end of the drill string \n32\n to facilitate drilling the wellbore \n34\n.', 'The drilling mud and cuttings from the wellbore \n34\n may then flow toward the platform \n12\n through an annular space defined between the drill string \n32\n and the riser \n30\n.', 'As shown, the riser \n30\n may be formed from multiple riser joints that are stacked end-to-end and that are coupled to one another via fasteners that extend through flanges.', 'For example, the riser \n30\n may include a first riser joint \n36\n that contacts and connects to the connector \n28\n (e.g., stabs into the connector \n28\n), a second riser joint \n38\n that connects to the first riser joint \n36\n via fasteners that extend through flanges \n40\n at adjacent ends of the first riser joint \n36\n and the second riser joint \n38\n, a third riser joint \n42\n that connects to the second riser joint \n38\n via fasteners that extend through flanges \n40\n at adjacent ends of the second riser joint \n38\n and the third riser joint \n42\n, and so on.', 'As shown, the first riser joint \n36\n and the connector \n28\n may also include flanges \n40\n that are positioned to support the first riser joint \n36\n at the connector \n28\n and/or facilitate connection of auxiliary lines (e.g., fluid control lines) that extend along the riser \n30\n.', 'In \nFIG. \n1\n, only some of the riser joints are shown for image clarity.', 'It is presently recognized that it would be advantageous to provide a collet connection between the connector \n28\n and the riser \n30\n to enable efficient coupling and decoupling operations.', 'As discussed in detail herein, the collet connection may be formed between movable components (e.g., collet segments) of the connector \n28\n and a pin (e.g., annular pin; extension) at a first end (e.g., distal end) of the riser \n30\n.', 'FIGS.', '2\n and \n3\n are a perspective view and a cross-sectional perspective view, respectively, of an embodiment of a portion of the riser \n30\n.', 'In particular, the portion of the riser \n30\n includes a portion of the first riser joint \n36\n that is configured to connect to the connector \n28\n of \nFIG.', '1\n.', 'The first riser joint \n36\n forms a first end \n48\n (e.g., distal end) of the riser \n30\n, and the first riser joint \n36\n extends from a first end \n50\n (e.g., distal end) to a second end (e.g., proximal end that connects to the second riser joint \n38\n shown in \nFIG.', '1\n).', 'The first riser joint \n36\n may include the flange \n40\n, a pin \n52\n (e.g., pin section), and a main body \n54\n (e.g., main riser section).', 'The main body \n54\n may extend from the second end of the first riser joint \n36\n to the flange \n40\n.', 'The main body \n54\n may be an upper tubular section with a main body diameter \n56\n, and the flange \n40\n may be a radially-expanded section with a flange diameter \n58\n that is greater than the main body diameter \n56\n.', 'As shown, multiple openings are distributed circumferentially about the flange \n40\n to support auxiliary lines \n60\n (e.g., fluid control lines).', 'The pin \n52\n may be a lower tubular section with a pin diameter \n62\n that is less than the flange diameter \n58\n.', 'The pin diameter \n62\n may be the same as or different than (e.g., larger or smaller) the main body diameter \n56\n.', 'The pin \n52\n may also have a pin height \n64\n that is greater (e.g., at least 2, 3, 4, 5, 10, or more times greater) than a flange height \n66\n of the flange \n40\n.', 'The pin height \n64\n may be the same as or different than (e.g., greater or smaller) a main body height of the main body \n54\n (e.g., from the flange \n40\n and the second end of the first riser joint \n36\n).', 'For example, the pin height \n64\n may be at least 2, 3, 4, 5, 10, or more times greater than the main body height, or the main body height may be no more than 2, 3, 4, 5, 10, or more times greater than the pin height \n64\n)', 'The pin \n52\n may include one or more annular grooves \n70\n formed in a radially-outer surface \n72\n of the pin \n52\n proximate to (e.g., at or near) the first end \n50\n of the first riser joint \n36\n.', 'The one or more grooves \n70\n (e.g., annular grooves) may facilitate coupling the first riser joint \n36\n to the connector \n28\n of \nFIG.', '1\n.', 'It should be appreciated that the one or more grooves \n70\n may have any suitable position and/or arrangement to facilitate coupling the first riser joint \n36\n to the connector \n28\n of \nFIG.', '1\n.', 'It should also be appreciated that the flange \n40\n, the pin \n52\n, and/or the main body \n54\n may be formed as one-piece (e.g., via additive manufacturing) and/or may be coupled to one another in any of a variety of manners (e.g., welds).', 'Furthermore, only the first riser joint \n36\n may include the pin \n52\n (e.g., the other riser joints, such as the second riser joint and the third riser joint, may not include the pin \n52\n that extends vertically below the flange \n40\n).\n \nFIG.', '4\n is a cross-sectional perspective view of the portion of the riser \n30\n (e.g., the portion of the first riser joint \n36\n) and the connector \n28\n of the LMRP \n24\n, wherein the connector \n28\n is in an open configuration (e.g., unlocked configuration).', 'As shown, the connector \n28\n may be in the open configuration as the first riser joint \n36\n moves toward (e.g., is lowered toward) the connector \n28\n.', 'In the open configuration, collet segments \n80\n of the connector \n28\n are in an expanded position (e.g., radially-expanded position) that enables the collet segments \n80\n to be positioned about and/or to receive the pin \n52\n of the first riser joint \n36\n within an opening defined by the collet segments \n80\n.', 'Furthermore, in the open configuration, the connector \n28\n does not engage and/or is not locked to the pin \n52\n of the first riser joint \n36\n.', 'As shown, the connector \n28\n includes a connector body \n82\n that extends from a first end \n84\n (e.g., distal end) to a second end \n86\n (e.g., proximal end).', 'The connector body \n82\n may also include the flange \n40\n at the second end \n86\n, a neck \n88\n (e.g., neck section) with a cylindrical neck portion \n90\n and a tapered neck portion \n92\n, and a collet housing \n94\n (e.g., collet section).', 'The flange \n40\n may be a radially-expanded section with multiple openings distributed circumferentially about the flange \n40\n to support the auxiliary lines \n60\n and/or to support line connectors \n98\n that are configured to couple (e.g., fluidly couple; via a stab connection) to the auxiliary lines \n60\n.', 'The cylindrical neck portion \n90\n of the neck \n88\n may have an inner diameter that is larger (e.g., slightly larger) than an outer diameter of the pin \n52\n so as to align/guide the pin \n52\n into the opening defined by the collet segments \n80\n and/or to block radial movement of the pin \n52\n after insertion of the pin \n52\n into the connector \n28\n.', 'The tapered neck portion \n92\n may taper radially outwardly to join the cylindrical neck portion \n90\n to the collet housing \n94\n, which has a collet housing diameter that is greater than a cylindrical neck portion diameter of the cylindrical neck portion \n90\n.', 'The collet housing \n94\n includes an outer wall \n100\n (e.g., annular wall; outer sleeve) and an inner wall \n102\n (e.g., annular wall; inner sleeve).', 'An annular space \n104\n is defined between the outer wall \n100\n and the inner wall \n102\n.', 'As shown, lower portions \n106\n of the collet segments \n80\n are positioned to form a ring (e.g., segmented ring) in the annular space \n104\n, while upper portions \n108\n of the collet segments \n80\n are positioned vertically above the inner wall \n102\n to enable the upper portions \n108\n of the collet segments \n80\n to engage the one or more grooves \n70\n of the first riser joint \n36\n.', 'A piston \n110\n (e.g., annular piston) is also positioned in the annular space \n104\n, and upward movement of the piston \n110\n within the collet housing \n94\n (e.g., relative to the collet segments \n80\n) causes the piston \n110\n to drive the upper portions \n108\n of the collet segments \n80\n radially-inwardly to adjust the collet segments \n80\n from the expanded position to a collapsed position (e.g., radially-collapsed position) to enable the upper portions \n108\n of the collet segments \n80\n to engage the pin \n52\n of the first riser joint \n36\n.', 'Similarly, downward movement of the piston \n110\n within the collet housing \n94\n (e.g., relative to the collet segments \n80\n) causes the piston \n110\n to drive the upper portions \n108\n of the collet segments \n80\n radially-outwardly to adjust the collet segments \n80\n from the collapsed position to the expanded position to enable the upper portions \n108\n of the collet segments \n80\n to receive the pin \n52\n of the first riser joint \n36\n and/or to enable withdrawal of the pin \n52\n of the first riser joint \n36\n from the connector \n28\n.', 'To adjust the piston \n110\n upward within the collet housing \n94\n to thereby drive the upper portions \n108\n of the collet segments \n80\n radially-inwardly, a fluid may be provided to a first sealed space \n112\n within the annular space \n104\n.', 'To drive the piston \n110\n downward within the collet housing \n94\n to thereby drive the upper portions \n108\n of the collet segments \n80\n radially-outwardly, a fluid may be provided to a second sealed space \n114\n withing the annular space \n104\n.', 'The fluid may be provided via a fluid supply of the LMRP \n24\n or the BOP stack \n22\n of \nFIG.', '1\n.', 'FIG.', '5\n is a cross-sectional perspective view of the portion of the riser \n30\n (e.g., the portion of the first riser joint \n36\n) and the connector \n28\n of the LMRP \n24\n, wherein the connector \n28\n is in a closed configuration (e.g., locked configuration).', 'In operation, the connector \n28\n may be adjusted from the open configuration of \nFIG.', '4\n to the closed configuration \nFIG.', '5\n after the first riser joint \n36\n reaches the opening defined by the collet segments \n80\n.', 'In the closed configuration, the collet segments \n80\n are in the collapsed position that enables the collet segments \n80\n to contact and engage the pin \n52\n of the first riser joint \n36\n.', 'In particular, in the closed configuration, respective radially-inner surfaces \n120\n of the upper portions \n108\n of the collet segments \n80\n contact and engage the one or more grooves \n70\n formed in the radially-outer surface \n72\n of the pin \n52\n of the first riser joint \n36\n, thereby locking the connector \n28\n to the first riser joint \n36\n and blocking movement of the connector \n28\n relative to the first riser joint \n36\n.', 'As noted herein, upward movement of the piston \n110\n within the collet housing \n94\n causes the piston \n110\n to drive the upper portions \n108\n of the collet segments \n80\n radially-inwardly to adjust the collet segments \n80\n from the expanded position to the collapsed position to enable the upper portions \n108\n of the collet segments \n80\n to engage the pin \n52\n of the first riser joint \n36\n.', 'Similarly, downward movement of the piston \n110\n within the collet housing \n94\n causes the piston \n110\n to drive the upper portions \n108\n of the collet segments \n80\n radially-outwardly to adjust the collet segments \n80\n from the collapsed position to the expanded position to enable the upper portions \n108\n of the collet segments \n80\n to receive the pin \n52\n of the first riser joint \n36\n and/or to enable withdrawal of the pin \n52\n of the first riser joint \n36\n from the connector \n28\n.', 'To adjust the piston \n110\n upward within the collet housing \n94\n to thereby drive the upper portions \n108\n of the collet segments \n80\n radially-inwardly, the fluid may be provided to the first sealed space \n112\n within the annular space \n104\n.', 'To drive the piston \n110\n downward within the collet housing \n94\n to thereby drive the upper portions \n108\n of the collet segments \n80\n radially-outwardly, the fluid may be provided to the second sealed space \n114\n withing the annular space \n104\n.', 'As shown, a first vertical distance separates the flange \n40\n of the first riser joint \n36\n and the one or more grooves \n70\n formed in the radially-outer surface \n72\n of the pin \n52\n of the first riser joint \n36\n, and a second vertical distance separates the flange \n40\n of the connector \n28\n and the upper portions \n108\n of the collet segments \n80\n.', 'The first vertical distance and the second vertical distance are designed to facilitate vertical alignment between the one or more grooves \n70\n formed in the radially-outer surface \n72\n of the pin \n52\n of the first riser joint \n36\n and the upper portions \n108\n of the collet segments \n80\n.', 'In particular, when the flange \n40\n of the first riser joint \n36\n contacts the flange \n40\n of the connector \n28\n (e.g., at least along radially-inner edges or portions of the flanges \n40\n), the one or more grooves \n70\n formed in the radially-outer surface \n72\n of the pin \n52\n of the first riser joint \n36\n are in vertical alignment with the upper portions \n108\n of the collet segments \n80\n.', 'Then, the transition of the collet segments \n80\n to the collapsed position causes the collet segments \n80\n to contact and engage the pin \n52\n of the first riser joint \n36\n.', 'As shown, the auxiliary lines \n60\n supported by the flange \n40\n of the first riser joint \n36\n may also be coupled to the line connectors \n98\n supported by the flange \n40\n of the connector \n28\n.', 'In some embodiments, the flange \n40\n of the first riser joint \n36\n and the flange \n40\n of the connector \n28\n are not fastened to one another via any fasteners (e.g., via threaded fasteners, such as bolts, that extend through respective openings in the flanges \n40\n) while the connection is formed between the first riser joint \n36\n and the connector \n28\n.\n \nFIG.', '6\n is a flow diagram of an embodiment of a method \n130\n for joining the riser \n30\n to the LMRP \n24\n via the connector \n28\n.', 'The method \n130\n includes various steps represented by blocks.', 'It should be noted that some or all of the steps of the method \n130\n may be performed as an automated procedure by an automated system (e.g., an ROV or an AOV system; a controller on the platform \n12\n and/or on the wellhead assembly \n16\n) and/or some or all of the steps of the method \n130\n may be performed manually by an operator (e.g., via controlling the ROV or the AUV; via control inputs to the controller on the platform \n12\n and/or the wellhead assembly \n16\n).', 'Although the flow chart illustrates the steps in a certain sequence, it should be understood that the steps may be performed in any suitable order and certain steps may be carried out simultaneously, where appropriate.', 'Further, certain steps or portions of the method \n130\n may be omitted and other steps may be added.', 'In step \n132\n, the first riser joint \n36\n of the riser \n30\n may be lowered toward the connector \n28\n that is coupled to or included as part of the LMRP \n24\n.', 'As the first riser joint \n36\n of the riser \n30\n is lowered toward the connector \n28\n, the collet segments \n80\n of the connector \n28\n may be in the expanded position to set the connector \n28\n in the open configuration that enables the connector \n28\n to receive the pin \n52\n of the first riser joint \n36\n of the riser \n30\n.', 'In step \n134\n, the pin \n52\n of the first riser joint \n36\n of the riser \n30\n may be inserted into (e.g., stabbed into) the opening defined by the collet segments \n80\n of the connector \n28\n.', 'As noted herein, when the flange \n40\n of the first riser joint \n36\n contacts the flange \n40\n of the connector \n28\n, the one or more grooves \n70\n formed in the radially-outer surface \n72\n of the pin \n52\n of the first riser joint \n36\n may be in vertical alignment with the upper portions \n108\n of the collet segments \n80\n of the connector \n28\n.', 'In step \n136\n, the fluid may be provided to the first sealed space \n112\n to cause upward movement of the piston \n110\n within the collet housing \n94\n.', 'The upward movement of the piston \n110\n within the collet housing \n94\n causes the piston \n110\n to drive the upper portions \n108\n of the collet segments \n80\n radially-inwardly to adjust the collet segments \n80\n from the expanded position to the collapsed position to enable the upper portions \n108\n of the collet segments \n80\n to engage the pin \n52\n of the first riser joint \n36\n.', 'In this way, the connector \n28\n may reach the closed configuration in which the connector \n28\n is locked to the pin \n52\n of the first riser joint \n36\n.', 'In step \n138\n, at some later time (e.g., for maintenance operations), the fluid may be provided to the second sealed space \n114\n to cause downward movement of the piston \n110\n within the collet housing \n94\n.', 'The downward movement of the piston \n110\n within the collet housing \n94\n causes the piston \n110\n to drive the upper portions \n108\n of the collet segments \n80\n radially-outwardly to adjust the collet segments \n80\n from the collapsed position to the expanded position to enable withdrawal of the pin \n52\n of the first riser joint \n36\n from the connector \n28\n.', 'In step \n140\n, the first riser joint \n36\n may be withdrawn from the connector \n28\n.', 'Advantageously, the first riser joint \n36\n and the connector \n28\n may form a connector system that enables efficient coupling and decoupling between the riser \n30\n and the LMRP \n24\n.', 'The connection between the first riser joint \n36\n and the connector \n28\n may be a sealed connection that fluidly couples the riser \n30\n and a bore that extends through the wellhead assembly \n16\n.', 'The connection between the first riser joint \n36\n and the connector \n28\n may also enable at least some of the riser \n30\n and at least some of the wellhead assembly \n16\n to be moved or transported together relative to the wellhead \n20\n.', 'For example, the first riser joint \n36\n may be coupled to the LMRP \n24\n and the BOP stack \n22\n under a rotary table of a moon pool of the platform \n12\n, and then the first riser joint \n36\n, the LMRP \n24\n, and the BOP stack \n22\n may be lowered toward the wellhead \n20\n together as one unit.', 'It should be appreciated that the connector \n28\n may have any of a variety of configurations, and the collet segments \n80\n may be driven via an actuator assembly having any of a variety of configurations.', 'For example, instead of the piston \n110\n being driven upwardly within the collet housing \n94\n upon supply of the fluid to the first sealed space \n112\n and downwardly within the collet housing \n94\n upon supply of the fluid to the second sealed space \n114\n, the piston \n110\n may be driven downwardly within the collet housing \n94\n upon supply of the fluid to the second sealed space \n114\n and upwardly within the collet housing \n94\n upon release of the fluid from the second sealed space \n114\n.', 'As another example, the collet segments \n80\n may be biased toward the closed position (e.g., normally closed), but may be driven radially-outwardly via contact with the pin \n52\n of the first riser joint \n36\n to receive the pin \n52\n as the pin \n52\n moves into the connector \n28\n.', 'While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein.', 'However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed.', 'Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims.', 'The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical.', 'Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function]. . . ”', 'or “step for [perform]ing [a function]. . .', '”, it is intended that such elements are to be interpreted under 35 U.S.C. 112(f).', 'However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. 112(f).']

['1.', 'A connector system, comprising:\na first riser joint configured to form part of a riser and comprising a pin; and\na connector configured to couple to a wellhead assembly and comprising a plurality of collet segments that are configured to move radially-inwardly to engage the pin of the first riser joint,\nwherein the connector further comprises: a connector body comprising: a collet housing; a tapered neck portion; and a cylindrical neck portion, wherein the tapered neck portion tapers radially outwardly to join the cylindrical neck portion to the collet housing, the cylindrical neck portion having an inner diameter that is larger than an outer diameter of the pin, wherein the collet housing comprises: an outer wall; an inner wall; and an annular space defined between the outer wall and the inner wall, the connector further comprising: a piston configured to move vertically within the collet housing to drive the plurality of collet segments to move radially-inwardly to engage the pin of the first riser joint, wherein first portions of the plurality of collet segments are positioned to form a ring in the annular space of the collet housing.', '2.', 'The connector system of claim 1, wherein the first riser joint comprises:\na main body; and\na first riser joint flange positioned between the main body and the pin along a vertical axis of the first riser joint.', '3.', 'The connector system of claim 2, wherein the connector comprises a connector flange that is configured to contact the first riser joint flange while the plurality of collet segments engage the pin of the first riser joint.', '4.', 'The connector system of claim 2, wherein a pin height of the pin along the vertical axis is at least two times a flange height of the first riser joint flange along the vertical axis.', '5.', 'The connector system of claim 1, wherein the first riser joint is configured to support one or more auxiliary lines, and the connector comprises a connector flange that supports one or more line connectors that are configured to couple to the one or more auxiliary lines.', '6.', 'The connector system of claim 5, wherein the one or more line connectors are configured to couple to the one or more auxiliary lines via respective stab connections.', '7.', 'The connector system of claim 1, wherein second portions of the plurality of collet segments are positioned vertically above the inner wall to enable the second portions of the plurality of collet segments to engage the pin of the first riser joint.', '8.', 'A subsea drilling system, comprising:\na riser that extends between a platform at a sea surface and a wellhead assembly at a sea floor, wherein a distal end of the riser comprises a pin; and\na connector coupled to the wellhead assembly, wherein the connector comprises: a plurality of collet segments that are configured to move radially-inwardly to engage the pin to enable the connector to couple the riser to the wellhead assembly; a connector body comprising: a collet housing; a tapered neck portion; and a cylindrical neck portion, wherein the tapered neck portion tapers radially outwardly to join the cylindrical neck portion to the collet housing, the cylindrical neck portion having an inner diameter that is larger than an outer diameter of the pin; wherein the collet housing comprises: an outer wall; an inner wall; and an annular space defined between the outer wall and the inner wall, the connector further comprising: a piston configured to move vertically within the collet housing to drive the plurality of collet segments to move radially-inwardly to engage the pin, wherein first portions of the plurality of collet segments are positioned to form a ring in the annular space of the collet housing.\n\n\n\n\n\n\n9.', 'The subsea drilling system of claim 8, wherein the riser comprises a plurality of riser joints that are stacked end-to-end, and the plurality of riser joints comprises a first riser joint that forms the distal end of the riser and that comprises the pin.', '10.', 'The subsea drilling system of claim 8, wherein the connector is coupled to a lower marine riser package (LMRP) of the wellhead assembly.', '11.', 'The subsea drilling system of claim 8, wherein the riser comprises a riser flange that is separated from the distal end of the riser along a vertical axis of the riser.', '12.', 'The subsea drilling system of claim 11, wherein the connector comprises a connector flange that is configured to contact the riser flange while the plurality of collet segments engage the pin.', '13.', 'The subsea drilling system of claim 12, wherein the riser and the wellhead assembly are connected only via engagement between the plurality of collet segments and the pin, and the connector flange and the riser flange are not coupled to one another via threaded fasteners.', '14.', 'The subsea drilling system of claim 11, wherein a pin height of the pin along the vertical axis is at least two times a flange height of the riser flange along the vertical axis.', '15.', 'The subsea drilling system of claim 8, wherein second portions of the plurality of collet segments are positioned vertically above the inner wall to enable the second portions of the plurality of collet segments to engage the pin.', '16.', 'A method of coupling a riser and a wellhead assembly, the method comprising:\nmoving a first riser joint of the riser toward a connector coupled to a portion of the wellhead assembly, the connector comprising: a connector body comprising: a collet housing; a tapered neck portion; and a cylindrical neck portion, wherein the tapered neck portion tapers radially outwardly to join the cylindrical neck portion to the collet housing;\ninserting a pin of the first riser joint of the riser into an opening defined by a plurality of collet segments of the connector, the cylindrical neck portion having an inner diameter that is larger than an outer diameter of the pin so as to align and guide the pin into the opening defined by the plurality of collet segments of the connector; and\ndriving the plurality of collet segments to move radially-inwardly to engage the pin of the first riser joint of the riser to form a connection between the riser and the wellhead assembly,\nthe method further comprising: providing a fluid to a sealed space within collet housing of the connector to drive a piston to move within the collet housing, the collet housing comprising: an outer wall; an inner wall; and an annular space defined between the outer wall and the inner wall, wherein first portions of the plurality of collet segments are positioned to form a ring in the annular space of the collet housing, wherein contact between the piston and the plurality of collet segments as the piston moves within the collet housing causes the plurality of collet segments to move radially-inwardly.\n\n\n\n\n\n\n17.', 'The method of claim 16, comprising moving the first riser joint of the riser toward the connector until respective flanges of the first riser joint and the connector contact one another to thereby align the pin of the first riser joint of the riser with the opening defined by the plurality of collet segments of the connector.', '18.', 'The method of claim 16, comprising driving the plurality of collet segments to move radially-outwardly to disengage from the pin of the first riser joint of the riser to break up the connection between the riser and the wellhead assembly.\n\n\n\n\n\n\n19.', 'The method of claim 18, comprising withdrawing the pin of the first riser joint of the riser to separate the riser from the wellhead assembly.', '20.', 'The method of claim 16, wherein second portions of the plurality of collet segments are positioned vertically above the inner wall to enable the second portions of the plurality of collet segments to engage the pin of the first riser joint of the riser.']

['FIG.', '1 is a schematic diagram of a subsea drilling system, in accordance with an embodiment of the present disclosure;; FIG.', '2 is a perspective view of a portion of a riser that may be used in the subsea drilling system, in accordance with an embodiment of the present disclosure;; FIG.', '3 is a cross-sectional perspective view of the portion of the riser, in accordance with an embodiment of the present disclosure;; FIG.', '4 is a cross-sectional perspective view of the portion of the riser of and a connector of a lower marine riser package (LMRP), wherein the connector is in an open configuration, in accordance with an embodiment of the present disclosure;; FIG.', '5 is a cross-sectional perspective view of the portion of the riser of and the connector of the LMRP, wherein the connector is in a closed configuration, in accordance with an embodiment of the present disclosure; and; FIG.', '6 is a flow diagram of a method of coupling the riser to the LMRP via the connector, in accordance with an embodiment of the present disclosure.; FIG.', '1 is an embodiment of a subsea drilling system 10.', 'To facilitate discussion, the subsea drilling system 10 and its components may be described with reference to an axial axis or direction 4, a radial axis or direction 6, and a circumferential axis or direction 8.', 'As shown, the subsea drilling system 10 includes an offshore drilling rig or platform 12 at a sea surface 14 and a wellhead assembly 16 positioned at a sea floor 18.', 'The wellhead assembly 16 includes a wellhead 20, a blowout preventer (BOP) stack 22, and a lower marine riser package (LMRP) 24.', 'The BOP stack 22 may include one or more ram BOPs and the LMRP 24 may include one or more annular BOPs.', 'The LMRP 24 may also include or be coupled to a joint 26 (e.g., flex joint), which may include or be coupled to (e.g., via fasteners, such as threaded fasteners) a connector 28 (e.g., collet connector).; FIGS. 2 and 3 are a perspective view and a cross-sectional perspective view, respectively, of an embodiment of a portion of the riser 30.', 'In particular, the portion of the riser 30 includes a portion of the first riser joint 36 that is configured to connect to the connector 28 of FIG.', '1.', 'The first riser joint 36 forms a first end 48 (e.g., distal end) of the riser 30, and the first riser joint 36 extends from a first end 50 (e.g., distal end) to a second end (e.g., proximal end that connects to the second riser joint 38 shown in FIG. 1).', '; FIG.', '4 is a cross-sectional perspective view of the portion of the riser 30 (e.g., the portion of the first riser joint 36) and the connector 28 of the LMRP 24, wherein the connector 28 is in an open configuration (e.g., unlocked configuration).', 'As shown, the connector 28 may be in the open configuration as the first riser joint 36 moves toward (e.g., is lowered toward) the connector 28.', 'In the open configuration, collet segments 80 of the connector 28 are in an expanded position (e.g., radially-expanded position) that enables the collet segments 80 to be positioned about and/or to receive the pin 52 of the first riser joint 36 within an opening defined by the collet segments 80.', 'Furthermore, in the open configuration, the connector 28 does not engage and/or is not locked to the pin 52 of the first riser joint 36.; FIG.', '5 is a cross-sectional perspective view of the portion of the riser 30 (e.g., the portion of the first riser joint 36) and the connector 28 of the LMRP 24, wherein the connector 28 is in a closed configuration (e.g., locked configuration).', 'In operation, the connector 28 may be adjusted from the open configuration of FIG.', '4 to the closed configuration FIG.', '5 after the first riser joint 36 reaches the opening defined by the collet segments 80.; FIG.', '6 is a flow diagram of an embodiment of a method 130 for joining the riser 30 to the LMRP 24 via the connector 28.', 'The method 130 includes various steps represented by blocks.', 'It should be noted that some or all of the steps of the method 130 may be performed as an automated procedure by an automated system (e.g., an ROV or an AOV system; a controller on the platform 12 and/or on the wellhead assembly 16) and/or some or all of the steps of the method 130 may be performed manually by an operator (e.g., via controlling the ROV or the AUV; via control inputs to the controller on the platform 12 and/or the wellhead assembly 16).', 'Although the flow chart illustrates the steps in a certain sequence, it should be understood that the steps may be performed in any suitable order and certain steps may be carried out simultaneously, where appropriate.', 'Further, certain steps or portions of the method 130 may be omitted and other steps may be added.']

US11939859

Performance based condition monitoring

Oct 2, 2018

Geir Kroslid, Johan Lindal Haug

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent application PCT/US2018/053865 dated Apr. 1, 2019, 12 pages.; International Preliminary Report on Patentability issued in International Patent application PCT/US2018/053865, dated Apr. 8, 2020, 8 pages.; International Search Report and Written Opinion issued in International Patent application PCT/US2022/048826 dated Mar. 15, 2023, 12 pages.

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WO-2016060649; April 2016; WO; WO-2017051032; March 2017; WO

['Systems and methods for utilizing performance based condition monitoring to determine health condition of wellsite equipment.', 'A method may include operating a piece of equipment at an oil and gas wellsite by performing a plurality actions by a component of the piece of equipment, and generating a plurality of sensor measurements, wherein each sensor measurement is indicative of a corresponding action.', 'The method may further include receiving the plurality of sensor measurements by a processing system, calculating a condition indicator for each component based on a corresponding sensor measurement, recording each condition indicator over a period of time, and determining condition of the piece of equipment based on at least one of the condition indicators recorded over time.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority to and the benefit of U.S. Provisional Application No. 62/566,889, titled “PERFORMANCE CONDITION MONITORING,” filed Oct. 2, 2017, the entire disclosure of which is hereby incorporated herein by reference.', 'BACKGROUND OF THE DISCLOSURE\n \nWells are generally drilled into the ground or ocean bed to recover natural deposits of oil, gas, and other materials that are trapped in subterranean formations.', 'Well construction operations (e.g., drilling operations) may be performed at a wellsite by a drilling system having various surface and subterranean equipment operating in a coordinated manner.', 'A drilling system may utilize a drill bit attached to the lower end of a drill string to drill a well.', 'Drilling fluid may be pumped from a wellsite surface down through the drill string to the drill bit.', 'The drilling fluid lubricates and cools the drill bit, and may additionally carry drill cuttings from the wellbore back to the wellsite surface.', 'Wellsite equipment may be grouped into various subsystems, wherein each subsystem performs a different operation controlled by a corresponding local and/or a remotely located controller.', 'Condition monitoring is a process of monitoring equipment condition indicators for changes to identify future faults, failures, breakdowns, and other maintenance problems associated with equipment.', 'Condition monitoring is increasingly utilized in the oil and gas industry as part of predictive maintenance of wellsite (e.g., drilling) equipment.', 'Condition monitoring utilizes condition data generated by peripheral (e.g., add-on) sensors and instruments to gain more insight to the future maintenance problems.', 'Condition data, such as vibration data, acoustic data, thermographic (e.g., infrared signature) data, is used solely to indicate condition of equipment.', 'Condition monitoring also includes analyzing operational data to determine amount of equipment usage and compare the determined equipment usage to expected operational lifetime specifications and/or calculations.', 'However, current condition monitoring products do not provide adequate operational efficiency measurements and analytics for wellsite operations.', 'Such products may provide drill rig state detection, calculations of operational key performance indicators (KPIs), and customized dashboards and reporting tools.', 'Common to such performance monitoring products and services is a top-down monitoring approach, which focuses on performance of an entire piece of equipment and/or system and how such piece of equipment and/or system as a whole contributes to the overall process or operation being performed at the wellsite.', 'For example, drilling operational KPIs help monitor general functionality and/or detect broad operational problems, such as related to performance, non-productive time, and invisible lost time.', 'Such general performance monitoring is capable of determining a reduction in performance on a machine or system level, with limited insight to contextual or specific factors causing such reduction in performance.', 'Thus, current condition monitoring products cannot detect performance reductions affecting a portion or component of a piece of equipment or a small reduction affecting general performance of the piece of equipment.', 'Certain reductions in performance may be recognized by analyzing operational the KPIs of the rig, which may trigger an alarm within the control system.', 'However, alarm thresholds are typically designed with flexibility to handle variations in climate and operational conditions.', 'Thus, current condition monitoring systems will not trigger an alarm unless a decrease in overall performance of equipment is substantial.', 'Furthermore, current condition monitoring products rely on high quantities of peripheral sensors and instrumentation to monitor condition related parameters, such as oil quality, equipment vibration, acoustic emission, temperature, thermography, and electrical current signature.', 'Implementing such products has a high investment cost and mandates expertise to analyze data generated by the peripheral sensors to forecast equipment faults.', 'SUMMARY OF THE DISCLOSURE', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure introduces a computer program product that includes a non-transitory, computer-readable medium including instructions that, when executed by a processor of a processing system, cause the processing system to receive sensor measurements each generated by a corresponding sensor of a piece of equipment at an oil and gas wellsite.', 'The piece of equipment includes actuators each operable to facilitate a corresponding action performed by a component of the piece of equipment.', 'Each sensor measurement is indicative of a corresponding action.', 'The instructions also cause the processing system to calculate a condition indicator for each sensor based on a corresponding sensor measurement, record each condition indicator over a period of time, and determine condition of the piece of equipment based on at least one of the condition indicators recorded over time.', 'The present disclosure also introduces a method including operating a piece of equipment, at an oil and gas wellsite, by performing actions by a component of the piece of equipment, and generating sensor measurements each indicative of a corresponding action.', 'The method also includes receiving the sensor measurements by a processing system, calculating a condition indicator for each component based on a corresponding sensor measurement, recording each condition indicator over a period of time, and determining condition of the piece of equipment based on at least one of the condition indicators recorded over time.', 'The present disclosure also introduces a system including a piece of equipment at an oil and gas wellsite and a processing system including a processor and a memory storing a computer program code.', 'The piece of equipment includes actuators each operable to facilitate a corresponding action by a component of the piece of equipment, and sensors each operable to generate a signal indicative of an operational parameter associated with a corresponding action.', 'When executed, the computer program code causes the processing system to determine a condition indicator for each action based on a corresponding signal, record each condition indicator over a period of time, and determine condition of the piece of equipment based on at least one of the condition indicators recorded over time.', 'These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the material herein and/or practicing the principles described herein.', 'At least some aspects of the present disclosure may be achieved via means recited in the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is understood from the following detailed description when read with the accompanying figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '2\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '3\n is a flow-chart diagram of at least a portion of a process according to one or more aspects of the present disclosure.\n \nFIG.', '4\n is a flow-chart diagram of at least a portion of a process according to one or more aspects of the present disclosure.\n \nFIG.', '5\n is a flow-chart diagram of at least a portion of a process according to one or more aspects of the present disclosure.\n \nFIG.', '6\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '7\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '8\n is a graph related to one or more aspects of the present disclosure.\n \nFIG.', '9\n is a graph related to one or more aspects of the present disclosure.\n \nFIG.', '10\n is a flow-chart diagram of at least a portion of a method according to one or more aspects of the present disclosure.', 'DETAILED DESCRIPTION', 'It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments.', 'Specific examples of components and arrangements are described below to simplify the present disclosure.', 'These are, of course, merely examples and are not intended to be limiting.', 'In addition, the present disclosure may repeat reference numerals and/or letters in the various examples.', 'This repetition is for simplicity and clarity, and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.\n \nFIG.', '1\n is a schematic view of at least a portion of an example implementation of a well construction system \n100\n according to one or more aspects of the present disclosure.', 'The well construction system \n100\n represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'Although the well construction system \n100\n is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', 'The well construction system \n100\n is depicted in relation to a wellbore \n102\n formed by rotary and/or directional drilling from a wellsite surface \n104\n and extending into a subterranean formation \n106\n.', 'The well construction system \n100\n includes surface equipment \n110\n located at the wellsite surface \n104\n and a drill string \n120\n suspended within the wellbore \n102\n.', 'The surface equipment \n110\n may include a mast, a derrick, and/or another support structure \n112\n disposed over a rig floor \n114\n.', 'The drill string \n120\n may be suspended within the wellbore \n102\n from the support structure \n112\n.', 'The support structure \n112\n and the rig floor \n114\n are collectively supported over the wellbore \n102\n by legs and/or other support structures (not shown).', 'The drill string \n120\n may comprise a bottom-hole assembly (BHA) \n124\n and means \n122\n for conveying the BHA \n124\n within the wellbore \n102\n.', 'The conveyance means \n122\n may comprise drill pipe, heavy-weight drill pipe (HWDP), wired drill pipe (WDP), tough logging condition (TLC) pipe, coiled tubing, and/or other means for conveying the BHA \n124\n within the wellbore \n102\n.', 'A downhole end of the BHA \n124\n may include or be coupled to a drill bit \n126\n.', 'Rotation of the drill bit \n126\n and the weight of the drill string \n120\n collectively operate to form the wellbore \n102\n.', 'The drill bit \n126\n may be rotated from the wellsite surface \n104\n and/or via a downhole mud motor (not shown) connected with the drill bit \n126\n.', 'The BHA \n124\n may also include various downhole tools \n180\n, \n182\n, \n184\n.', 'One or more of such downhole tools \n180\n, \n182\n, \n184\n may be or comprise an acoustic tool, a density tool, a directional drilling tool, an electromagnetic (EM) tool, a formation sampling tool, a formation testing tool, a gravity tool, a monitoring tool, a neutron tool, a nuclear tool, a photoelectric factor tool, a porosity tool, a reservoir characterization tool, a resistivity tool, a rotational speed sensing tool, a sampling-while-drilling (SWD) tool, a seismic tool, a surveying tool, a torsion sensing tool, and/or other measuring-while-drilling (MWD) or logging-while-drilling (LWD) tools.', 'One or more of the downhole tools \n180\n, \n182\n, \n184\n may be or comprise an MWD or LWD tool comprising a sensor package \n186\n operable for the acquisition of measurement data pertaining to the BHA \n124\n, the wellbore \n102\n, and/or the formation \n106\n.', 'One or more of the downhole tools \n180\n, \n182\n, \n184\n and/or another portion of the BHA \n124\n may also comprise a telemetry device \n187\n operable for communication with the surface equipment \n110\n, such as via mud-pulse telemetry.', 'One or more of the downhole tools \n180\n, \n182\n, \n184\n and/or another portion of the BHA \n124\n may also comprise a downhole processing device \n188\n operable to receive, process, and/or store information received from the surface equipment \n110\n, the sensor package \n186\n, and/or other portions of the BHA \n124\n.', 'The processing device \n188\n may also store executable computer programs (e.g., program code instructions), including for implementing one or more aspects of the operations described herein.', 'The support structure \n112\n may support a driver, such as a top drive \n116\n, operable to connect (perhaps indirectly) with an uphole end of the conveyance means \n122\n, and to impart rotary motion \n117\n and vertical motion \n135\n to the drill string \n120\n and the drill bit \n126\n.', 'However, another driver, such as a kelly and rotary table (neither shown), may be utilized instead of or in addition to the top drive \n116\n to impart the rotary motion \n117\n.', 'The top drive \n116\n and the connected drill string \n120\n may be suspended from the support structure \n112\n via hoisting equipment, which may include a traveling block \n118\n, a crown block (not shown), and a draw works \n119\n storing a support cable or line \n123\n.', 'The crown block may be connected to or otherwise supported by the support structure \n112\n, and the traveling block \n118\n may be coupled with the top drive \n116\n, such as via a hook.', 'The draw works \n119\n may be mounted on or otherwise supported by the rig floor \n114\n.', 'The crown block and traveling block \n118\n comprise pulleys or sheaves around which the support line \n123\n is reeved to operatively connect the crown block, the traveling block \n118\n, and the draw works \n119\n (and perhaps an anchor).', 'The draw works \n119\n may thus selectively impart tension to the support line \n123\n to lift and lower the top drive \n116\n, resulting in the vertical motion \n135\n.', 'The draw works \n119\n may comprise a drum, a frame, and a prime mover (e.g., an engine or motor) (not shown) operable to drive the drum to rotate and reel in the support line \n123\n, causing the traveling block \n118\n and the top drive \n116\n to move upward.', 'The draw works \n119\n may be operable to release the support line \n123\n via a controlled rotation of the drum, causing the traveling block \n118\n and the top drive \n116\n to move downward.', 'The top drive \n116\n may comprise a grabber, a swivel (neither shown), a tubular handling assembly links \n127\n terminating with an elevator \n129\n, and a drive shaft \n125\n operatively connected with a prime mover (not shown), such as via a gear box or transmission (not shown).', 'The drill string \n120\n may be mechanically coupled to the drive shaft \n125\n with or without a sub saver between the drill string \n120\n and the drive shaft \n125\n.', 'The prime mover may be selectively operated to rotate the drive shaft \n125\n and the drill string \n120\n coupled with the drive shaft \n125\n.', 'Hence, during drilling operations, the top drive \n116\n in conjunction with operation of the draw works \n119\n may advance the drill string \n120\n into the formation \n106\n to form the wellbore \n102\n.', 'The tubular handling assembly links \n127\n and the elevator \n129\n of the top drive \n116\n may handle tubulars (e.g., drill pipes, drill collars, casing joints, etc.) that are not mechanically coupled to the drive shaft \n125\n.', 'For example, when the drill string \n120\n is being tripped into or out of the wellbore \n102\n, the elevator \n129\n may grasp the tubulars of the drill string \n120\n such that the tubulars may be raised and/or lowered via the hoisting equipment mechanically coupled to the top drive \n116\n.', 'The grabber may include a clamp that clamps onto a tubular when making up and/or breaking out a connection of a tubular with the drive shaft \n125\n.', 'The top drive \n116\n may have a guide system (not shown), such as rollers that track up and down a guide rail on the support structure \n112\n.', 'The guide system may aid in keeping the top drive \n116\n aligned with the wellbore \n102\n, and in preventing the top drive \n116\n from rotating during drilling by transferring reactive torque to the support structure \n112\n.', 'The well construction system \n100\n may further include a well control system for maintaining well pressure control.', 'For example, the drill string \n120\n may be conveyed within the wellbore \n102\n through various blowout preventer (BOP) equipment disposed at the wellsite surface \n104\n on top of the wellbore \n102\n and perhaps below the rig floor \n114\n.', 'The BOP equipment may be operable to control pressure within the wellbore \n102\n via a series of pressure barriers (e.g., rams) between the wellbore \n102\n and the wellsite surface \n104\n.', 'The BOP equipment may include a BOP stack \n130\n, an annular preventer \n132\n, and/or a rotating control device (RCD) \n138\n mounted above the annular preventer \n132\n.', 'The BOP equipment \n130\n, \n132\n, \n138\n may be mounted on top of a wellhead \n134\n.', 'The well control system may further include a BOP control unit \n137\n (i.e., a BOP closing unit) operatively connected with the BOP equipment \n130\n, \n132\n, \n138\n and operable to actuate, drive, operate or otherwise control the BOP equipment \n130\n, \n132\n, \n138\n.', 'The BOP control unit \n137\n may be or comprise a hydraulic fluid power unit fluidly connected with the BOP equipment \n130\n, \n132\n, \n138\n and selectively operable to hydraulically drive various portions (e.g., rams, valves, seals) of the BOP equipment \n130\n, \n132\n, \n138\n.', 'The well construction system \n100\n may further include a drilling fluid circulation system operable to circulate fluids between the surface equipment \n110\n and the drill bit \n126\n during drilling and other operations.', 'For example, the drilling fluid circulation system may be operable to inject a drilling fluid from the wellsite surface \n104\n into the wellbore \n102\n via an internal fluid passage \n121\n extending longitudinally through the drill string \n120\n.', 'The drilling fluid circulation system may comprise a pit, a tank, and/or other fluid container \n142\n holding the drilling fluid (i.e., mud) \n140\n, and a pump \n144\n operable to move the drilling fluid \n140\n from the container \n142\n into the fluid passage \n121\n of the drill string \n120\n via a fluid conduit \n146\n extending from the pump \n144\n to the top drive \n116\n and an internal passage extending through the top drive \n116\n.', 'The fluid conduit \n146\n may comprise one or more of a pump discharge line, a stand pipe, a rotary hose, and a gooseneck (not shown) connected with a fluid inlet of the top drive \n116\n.', 'The pump \n144\n and the container \n142\n may be fluidly connected by a fluid conduit \n148\n, such as a suction line.', 'During drilling operations, the drilling fluid may continue to flow downhole through the internal passage \n121\n of the drill string \n120\n, as indicated by directional arrow \n158\n.', 'The drilling fluid may exit the BHA \n124\n via ports \n128\n in the drill bit \n126\n and then circulate uphole through an annular space \n108\n (“annulus”) of the wellbore \n102\n defined between an exterior of the drill string \n120\n and the wall of the wellbore \n102\n, such flow being indicated by directional arrows \n159\n.', 'In this manner, the drilling fluid lubricates the drill bit \n126\n and carries formation cuttings uphole to the wellsite surface \n104\n.', 'The returning drilling fluid may exit the annulus \n108\n via the RCD \n138\n and/or via a spool, a wing valve, a bell nipple, or another ported adapter \n136\n, which may be located below one or more portions of the BOP stack \n130\n.', 'The drilling fluid exiting the annulus \n108\n via the RCD \n138\n may be directed into a fluid conduit \n160\n (e.g., a drilling pressure control line), and may pass through various wellsite equipment fluidly connected along the conduit \n160\n prior to being returned to the container \n142\n for recirculation.', 'For example, the drilling fluid may pass through a choke manifold \n162\n (e.g., a drilling pressure control choke manifold) connected along the conduit \n160\n.', 'The choke manifold \n162\n may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow through and out of the choke manifold \n162\n.', 'Backpressure may be applied to the annulus \n108\n by variably restricting flow of the drilling fluid or other fluids flowing through the choke manifold \n162\n.', 'The greater the restriction to flow through the choke manifold \n162\n, the greater the backpressure applied to the annulus \n108\n.', 'The drilling fluid may also or instead exit the annulus \n108\n via the ported adapter \n136\n and into a fluid conduit \n171\n (e.g., rig choke line), and may pass through various equipment fluidly connected along the conduit \n171\n prior to being returned to the container \n142\n for recirculation.', 'For example, the drilling fluid may pass through a choke manifold \n173\n (e.g., a rig choke manifold) connected along the conduit \n171\n.', 'The choke manifold \n173\n may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow through the choke manifold \n173\n.', 'Backpressure may be applied to the annulus \n108\n by variably restricting flow of the drilling fluid or other fluids flowing through the choke manifold \n173\n.', 'Before being returned to the container \n142\n, the drilling fluid returning to the wellsite surface \n104\n may be cleaned and/or reconditioned via drilling fluid reconditioning equipment \n170\n, which may include one or more of liquid gas separators, shale shakers, centrifuges, and other drilling fluid cleaning equipment.', 'The liquid gas separators may remove formation gasses entrained in the drilling fluid discharged from the wellbore \n102\n and the shale shakers may separate and remove solid particles \n141\n (e.g., drill cuttings) from the drilling fluid.', 'The drilling fluid reconditioning equipment \n170\n may further comprise equipment operable to remove additional gas and finer formation cuttings from the drilling fluid and/or modify physical properties or characteristics (e.g., rheology) of the drilling fluid.', 'For example, the drilling fluid reconditioning equipment \n170\n may include a degasser, a desander, a desilter, a mud cleaner, and/or a decanter, among other examples.', 'Intermediate tanks/containers (not shown) may be utilized to hold the drilling fluid while the drilling fluid progresses through the various stages or portions of the drilling fluid reconditioning equipment \n170\n.', 'The cleaned/reconditioned drilling fluid may be transferred to the fluid container \n142\n, the solid particles \n141\n removed from the drilling fluid may be transferred to a solids container \n143\n (e.g., a reserve pit), and/or the removed gas may be transferred to a flare stack \n172\n via a conduit \n174\n (e.g., a flare line) to be burned or to a container (not shown) for storage and removal from the wellsite.', 'The surface equipment \n110\n may include tubular handling equipment operable to store, move, connect, and disconnect tubulars (e.g., drill pipes) to assemble and disassemble the conveyance means \n122\n of the drill string \n120\n during drilling operations.', 'For example, a catwalk \n131\n may be utilized to convey tubulars from a ground level, such as along the wellsite surface \n104\n, to the rig floor \n114\n, permitting the tubular handling assembly links \n127\n to grab and lift the tubulars above the wellbore \n102\n for connection with previously deployed tubulars.', 'The catwalk \n131\n may have a horizontal portion and an inclined portion that extends between the horizontal portion and the rig floor \n114\n.', 'The catwalk \n131\n may comprise a skate \n133\n movable along a groove (not shown) extending longitudinally along the horizontal and inclined portions of the catwalk \n131\n.', 'The skate \n133\n may be operable to convey (e.g., push) the tubulars along the catwalk \n131\n to the rig floor \n114\n.', 'The skate \n133\n may be driven along the groove by a drive system (not shown), such as a pulley system or a hydraulic system.', 'Additionally, one or more racks (not shown) may adjoin the horizontal portion of the catwalk \n131\n.', 'The racks may have a spinner unit for transferring tubulars to the groove of the catwalk \n131\n.', 'An iron roughneck \n151\n may be positioned on the rig floor \n114\n.', 'The iron roughneck \n151\n may comprise a torqueing portion \n153\n, such as may include a spinner and a torque wrench comprising a lower tong and an upper tong.', 'The torqueing portion \n153\n of the iron roughneck \n151\n may be moveable toward and at least partially around the drill string \n120\n, such as may permit the iron roughneck \n151\n to make up and break out connections of the drill string \n120\n.', 'The torqueing portion \n153\n may also be moveable away from the drill string \n120\n, such as may permit the iron roughneck \n151\n to move clear of the drill string \n120\n during drilling operations.', 'The spinner of the iron roughneck \n151\n may be utilized to apply low torque to make up and break out threaded connections between tubulars of the drill string \n120\n, and the torque wrench may be utilized to apply a higher torque to tighten and loosen the threaded connections.', 'Reciprocating slips \n161\n may be located on the rig floor \n114\n, such as may accommodate therethrough the downhole tubulars during make up and break out operations and during the drilling operations.', 'The reciprocating slips \n161\n may be in an open position during drilling operations to permit advancement of the drill string \n120\n therethrough, and in a closed position to clamp an upper end of the conveyance means \n122\n (e.g., assembled tubulars) to thereby suspend and prevent advancement of the drill string \n120\n within the wellbore \n102\n, such as during the make up and break out operations.', 'During drilling operations, the hoisting equipment lowers the drill string \n120\n while the top drive \n116\n rotates the drill string \n120\n to advance the drill string \n120\n downward within the wellbore \n102\n and into the formation \n106\n.', 'During the advancement of the drill string \n120\n, the reciprocating slips \n161\n are in an open position, and the iron roughneck \n151\n is moved away or is otherwise clear of the drill string \n120\n.', 'When the upper portion of the tubular in the drill string \n120\n that is made up to the drive shaft \n125\n is near the reciprocating slips \n161\n and/or the rig floor \n114\n, the top drive \n116\n ceases rotating and the reciprocating slips \n161\n close to clamp the tubular made up to the drive shaft \n125\n.', 'The grabber of the top drive \n116\n then clamps the upper portion of the tubular made up to the drive shaft \n125\n, and the drive shaft \n125\n rotates in a direction reverse from the drilling rotation to break out the connection between the drive shaft \n125\n and the made up tubular.', 'The grabber of the top drive \n116\n may then release the tubular of the drill string \n120\n.', 'Multiple tubulars may be loaded on the rack of the catwalk \n131\n and individual tubulars (or stands of two or three tubulars) may be transferred from the rack to the groove in the catwalk \n131\n, such as by the spinner unit.', 'The tubular positioned in the groove may be conveyed along the groove by the skate \n133\n until an end of the tubular projects above the rig floor \n114\n.', 'The elevator \n129\n of the top drive \n116\n then grasps the protruding end, and the draw works \n119\n is operated to lift the top drive \n116\n, the elevator \n129\n, and the new tubular.', 'The hoisting equipment then raises the top drive \n116\n, the elevator \n129\n, and the tubular until the tubular is aligned with the upper portion of the drill string \n120\n clamped by the slips \n161\n.', 'The iron roughneck \n151\n is moved toward the drill string \n120\n, and the lower tong of the torqueing portion \n153\n clamps onto the upper portion of the drill string \n120\n.', 'The spinning system rotates the new tubular (e.g., a threaded male end) into the upper portion of the drill string \n120\n (e.g., a threaded female end).', 'The upper tong then clamps onto the new tubular and rotates with high torque to complete making up the connection with the drill string \n120\n.', 'In this manner, the new tubular becomes part of the drill string \n120\n.', 'The iron roughneck \n151\n then releases and moves clear of the drill string \n120\n.', 'The grabber of the top drive \n116\n may then clamp onto the drill string \n120\n.', 'The drive shaft \n125\n (e.g., a threaded male end) is brought into contact with the drill string \n120\n (e.g., a threaded female end) and rotated to make up a connection between the drill string \n120\n and the drive shaft \n125\n.', 'The grabber then releases the drill string \n120\n, and the reciprocating slips \n161\n are moved to the open position.', 'The drilling operations may then resume.', 'The tubular handling equipment may further include a pipe handling manipulator (PHM) \n163\n disposed in association with a fingerboard \n165\n.', 'Although the PHM \n163\n and the fingerboard \n165\n are shown supported on the rig floor \n114\n, one or both of the PHM \n163\n and fingerboard \n165\n may be located on the wellsite surface \n104\n or another area of the well construction system \n100\n.', 'The fingerboard \n165\n provides storage (e.g., temporary storage) of tubulars (or stands of two or three tubulars) \n111\n during various operations, such as during and between tripping out and tripping in the drill string \n120\n.', 'The PHM \n163\n may be operable to transfer the tubulars \n111\n between the fingerboard \n165\n and the drill string \n120\n (i.e., space above the suspended drill string \n120\n).', 'For example, the PHM \n163\n may include arms \n167\n terminating with clamps \n169\n, such as may be operable to grasp and/or clamp onto one of the tubulars \n111\n.', 'The arms \n167\n of the PHM \n163\n may extend and retract, and/or at least a portion of the PHM \n163\n may be rotatable and/or movable toward and away from the drill string \n120\n, such as may permit the PHM \n163\n to transfer the tubular \n111\n between the fingerboard \n165\n and the drill string \n120\n.', 'To trip out the drill string \n120\n, the top drive \n116\n is raised, the reciprocating slips \n161\n are closed around the drill string \n120\n, and the elevator \n129\n is closed around the drill string \n120\n.', 'The grabber of the top drive \n116\n clamps the upper portion of the tubular made up to the drive shaft \n125\n.', 'The drive shaft \n125\n then rotates in a direction reverse from the drilling rotation to break out the connection between the drive shaft \n125\n and the drill string \n120\n.', 'The grabber of the top drive \n116\n then releases the tubular of the drill string \n120\n, and the drill string \n120\n is suspended by (at least in part) the elevator \n129\n.', 'The iron roughneck \n151\n is moved toward the drill string \n120\n.', 'The lower tong clamps onto a lower tubular below a connection of the drill string \n120\n, and the upper tong clamps onto an upper tubular above that connection.', 'The upper tong then rotates the upper tubular to provide a high torque to break out the connection between the upper and lower tubulars.', 'The spinning system then rotates the upper tubular to separate the upper and lower tubulars, such that the upper tubular is suspended above the rig floor \n114\n by the elevator \n129\n.', 'The iron roughneck \n151\n then releases the drill string \n120\n and moves clear of the drill string \n120\n.', 'The PHM \n163\n may then move toward the drill string \n120\n to grasp the tubular suspended from the elevator \n129\n.', 'The elevator \n129\n then opens to release the tubular.', 'The PHM \n163\n then moves away from the drill string \n120\n while grasping the tubular with the clamps \n169\n, places the tubular in the fingerboard \n165\n, and releases the tubular for storage in the fingerboard \n165\n.', 'This process is repeated until the intended length of drill string \n120\n is removed from the wellbore \n102\n.', 'The surface equipment \n110\n of the well construction system \n100\n may also comprise a control center \n190\n from which various portions of the well construction system \n100\n, such as the top drive \n116\n, the hoisting system, the tubular handling system, the drilling fluid circulation system, the well control system, the BHA \n124\n, among other examples, may be monitored and controlled.', 'The control center \n190\n may be located on the rig floor \n114\n or another location of the well construction system \n100\n, such as the wellsite surface \n104\n.', 'The control center \n190\n may comprise a facility \n191\n (e.g., a room, a cabin, a trailer, etc.) containing a control workstation \n197\n, which may be operated by a human wellsite operator \n195\n to monitor and control various wellsite equipment or portions of the well construction system \n100\n.', 'The control workstation \n197\n may comprise or be communicatively connected with a processing device \n192\n (e.g., a controller, a computer, etc.), such as may be operable to receive, process, and output information to monitor operations of and provide control to one or more portions of the well construction system \n100\n.', 'For example, the processing device \n192\n may be communicatively connected with the various surface and downhole equipment described herein, and may be operable to receive signals from and transmit signals to such equipment to perform various operations described herein.', 'The processing device \n192\n may store executable program code, instructions, and/or operational parameters or set-points, including for implementing one or more aspects of methods and operations described herein.', 'The processing device \n192\n may be located within and/or outside of the facility \n191\n.', 'The control workstation \n197\n may be operable for entering or otherwise communicating control commands to the processing device \n192\n by the wellsite operator \n195\n, and for displaying or otherwise communicating information from the processing device \n192\n to the wellsite operator \n195\n.', 'The control workstation \n197\n may comprise a plurality of human-machine interface (HMI) devices, including one or more input devices \n194\n (e.g., a keyboard, a mouse, a joystick, a touchscreen, etc.) and one or more output devices \n196\n (e.g., a video monitor, a touchscreen, a printer, audio speakers, etc.).', 'Communication between the processing device \n192\n, the input and output devices \n194\n, \n196\n, and the various wellsite equipment may be via wired and/or wireless communication means.', 'However, for clarity and ease of understanding, such communication means are not depicted, and a person having ordinary skill in the art will appreciate that such communication means are within the scope of the present disclosure.', 'Well construction systems within the scope of the present disclosure may include more or fewer components than as described above and depicted in \nFIG.', '1\n.', 'Additionally, various equipment and/or subsystems of the well construction system \n100\n shown in \nFIG.', '1\n may include more or fewer components than as described above and depicted in \nFIG. \n1\n.', 'For example, various engines, motors, hydraulics, actuators, valves, and/or other components not explicitly described herein may be included in the well construction system \n100\n, and are within the scope of the present disclosure.', 'The well construction system \n100\n also includes stationary and/or mobile video cameras \n198\n disposed or utilized at various locations within the well construction system \n100\n.', 'The video cameras \n198\n capture videos of various portions, equipment, or subsystems of the well construction system \n100\n, and perhaps the wellsite operators \n195\n and the actions they perform, during or otherwise in association with the wellsite operations, including while performing repairs to the well construction system \n100\n during a breakdown.', 'For example, the video cameras \n198\n may capture digital images (or video frames) of the entire well construction system \n100\n and/or specific portions of the well construction system \n100\n, such as the top drive \n116\n, the iron roughneck \n151\n, the PHM \n163\n, the fingerboard \n165\n, and/or the catwalk \n131\n, among other examples.', 'The video cameras \n198\n generate corresponding video signals (i.e., feeds) comprising or otherwise indicative of the captured digital images.', 'The video cameras \n198\n may be in signal communication with the processing device \n192\n, such as may permit the video signals to be processed and transmitted to the control workstation \n197\n and, thus, permit the wellsite operators \n195\n to view various portions or components of the well construction system \n100\n on one or more of the output devices \n196\n.', 'The processing device \n192\n or another portion of the control workstation \n197\n may be operable to record the video signals generated by the video cameras \n198\n.', 'The present disclosure further provides various implementations of systems and/or methods for controlling one or more portions of the well construction system \n100\n. \nFIG.', '2\n is a schematic view of at least a portion of an example implementation of a monitoring and control system \n200\n for monitoring and controlling various equipment, portions, and subsystems of the well construction system \n100\n according to one or more aspects of the present disclosure.', 'The following description refers to \nFIGS.', '1\n and \n2\n, collectively.', 'The control system \n200\n may be in real-time communication with and utilized to monitor and/or control various portions, components, and equipment of the well construction system \n100\n described herein.', 'The equipment of the well construction system \n100\n may be grouped into several subsystems, each operable to perform a corresponding operation and/or a portion of the well construction operations described herein.', 'The subsystems may include a rig control (RC) system \n211\n, a fluid circulation (FC) system \n212\n, a managed pressure drilling control (MPDC) system \n213\n, a choke pressure control (CPC) system \n214\n, a well pressure control (WC) system \n215\n, and a closed-circuit television (CCTV) system \n216\n.', 'The control workstation \n197\n may be utilized to monitor, configure, control, and/or otherwise operate one or more of the well construction subsystems \n211\n-\n216\n.', 'The RC system \n211\n may include the support structure \n112\n, the drill string hoisting system or equipment (e.g., the draw works \n119\n and the top drive \n116\n), drill string drivers (e.g., the top drive \n116\n and/or the rotary table and kelly), the reciprocating slips \n161\n, the drill pipe handling system or equipment (e.g., the catwalk \n131\n, the PHM \n163\n, the fingerboard \n165\n, and the iron roughneck \n151\n), electrical generators, and other equipment.', 'Accordingly, the RC system \n211\n may perform power generation and drill pipe handling, hoisting, and rotation operations.', 'The RC system \n211\n may also serve as a support platform for drilling equipment and staging ground for rig operations, such as connection make up and break out operations described above.', 'The FC system \n212\n may include the drilling fluid \n140\n, the pumps \n144\n, drilling fluid loading equipment, the drilling fluid reconditioning equipment \n170\n, the flare stack \n172\n, and/or other fluid control equipment.', 'Accordingly, the FC system \n212\n may perform fluid operations of the well construction system \n100\n.', 'The MPDC system \n213\n may include the RCD \n138\n, the choke manifold \n162\n, downhole pressure sensors \n186\n, and/or other equipment.', 'The CPC system \n214\n may comprise the choke manifold \n173\n, and/or other equipment, and the WC system \n215\n may comprise the BOP equipment \n130\n, \n132\n, \n138\n, the BOP control unit \n137\n, and a BOP control station (not shown) for controlling the BOP control unit \n137\n.', 'The CCTV system \n216\n may include the video cameras \n198\n and corresponding actuators (e.g., motors) for moving or otherwise controlling direction of the video cameras \n198\n.', 'The CCTV system \n216\n may be utilized to capture real-time video of various portions or subsystems \n211\n-\n215\n of the well construction system \n100\n and display video signals from the video cameras \n198\n on the video output devices \n196\n to display in real-time the various portions or subsystems \n211\n-\n215\n.', 'Each of the well construction subsystems \n211\n-\n216\n may further comprise various communication equipment (e.g., modems, network interface cards, etc.) and communication conductors (e.g., cables), communicatively connecting the equipment (e.g., sensors and actuators) of each subsystem \n211\n-\n216\n with the control workstation \n197\n and/or other equipment.', 'Although the wellsite equipment listed above and shown in \nFIG.', '1\n is associated with certain wellsite subsystems \n211\n-\n216\n, such associations are merely examples that are not intended to limit or prevent such wellsite equipment from being associated with two or more wellsite subsystems \n211\n-\n216\n and/or different wellsite subsystems \n211\n-\n216\n.', 'The control system \n200\n may also include various local controllers \n221\n-\n226\n associated with corresponding subsystems \n211\n-\n216\n and/or individual pieces of equipment of the well construction system \n100\n.', 'As described above, each well construction subsystem \n211\n-\n216\n includes various wellsite equipment comprising corresponding actuators \n241\n-\n246\n for performing operations of the well construction system \n100\n.', 'Each subsystem \n211\n-\n216\n further includes various sensors \n231\n-\n236\n operable to generate sensor data indicative of operational performance and/or status of the wellsite equipment of each subsystem \n211\n-\n216\n.', 'Although the sensors \n231\n-\n236\n and actuators \n241\n-\n246\n are each shown as a single block, it is to be understood that each sensor \n231\n-\n236\n and actuator \n241\n-\n246\n may be or comprise a plurality of sensors and actuators, whereby each actuator performs a corresponding action of a piece of equipment or subsystem \n211\n-\n216\n and each sensor generates corresponding sensor data indicative of the action performed by a corresponding actuator or of other operational parameter of the piece of equipment or subsystem \n211\n-\n216\n.', 'The local controllers \n221\n-\n226\n, the sensors \n231\n-\n236\n, and the actuators \n241\n-\n246\n may be communicatively connected with a processing device \n202\n.', 'For example, the local controllers may be in communication with the sensors \n231\n-\n236\n and actuators \n241\n-\n246\n of the corresponding subsystems \n211\n-\n216\n via local communication networks (e.g., field buses, not shown) and the processing device \n202\n may be in communication with the subsystems \n211\n-\n216\n via a communication network \n209\n (e.g., data bus, a wide-area-network (WAN), a local-area-network (LAN), etc.).', 'The sensor data (e.g., electronic signals, information, and/or measurements, etc.) generated by the sensors \n231\n-\n236\n of the subsystems \n211\n-\n216\n may be made available for use by processing device \n202\n and/or the local controllers \n221\n-\n226\n.', 'Similarly, control commands (e.g., signals, information, etc.) generated by the processing device \n202\n and/or the local controllers \n221\n-\n226\n may be automatically communicated to the various actuators \n241\n-\n246\n of the subsystems \n211\n-\n216\n, perhaps pursuant to predetermined programming, such as to facilitate well construction operations and/or other operations described herein.', 'The processing device \n202\n may be or comprise the processing device \n192\n shown in \nFIG.', '1\n.', 'Accordingly, the processing device \n202\n may be communicatively connected with or form a portion of the workstation \n197\n and/or may be at least partially located within the control center \n190\n.', 'The sensors \n231\n-\n236\n and actuators \n241\n-\n246\n may be monitored and/or controlled by the processing device \n202\n.', 'For example, the processing device \n202\n may be operable to receive the sensor data from the sensors \n231\n-\n236\n of the wellsite subsystems \n211\n-\n216\n in real-time, and to provide real-time control commands to the actuators \n241\n-\n246\n of the subsystems \n211\n-\n216\n based on the received sensor data.', 'However, certain operations of the actuators \n241\n-\n246\n may be controlled by the local controllers \n221\n-\n226\n, which may control the actuators \n241\n-\n246\n based on sensor data received from the sensors \n231\n-\n236\n and/or based on control commands received from the processing device \n202\n.', 'The processing devices \n188\n, \n192\n, \n202\n, the local controllers \n221\n-\n226\n, and other controllers or processing devices of the well construction system \n100\n may be operable to receive program code instructions and/or sensor data from sensors (e.g., sensors \n231\n-\n236\n), process such information, and/or generate control commands to operate controllable equipment (e.g., actuators \n241\n-\n246\n) of the well construction system \n100\n.', 'Accordingly, the processing devices \n188\n, \n192\n, \n202\n, the local controllers \n221\n-\n226\n, and other controllers or processing devices of the well construction system \n100\n may individually or collectively be referred to hereinafter as equipment controllers.', 'Equipment controllers within the scope of the present disclosure can include, for example, programmable logic controllers (PLCs), industrial computers (IPCs), personal computers (PCs), soft PLCs, variable frequency drives (VFDs) and/or other controllers or processing devices operable to receive sensor data and/or control commands and cause operation of controllable equipment based on such sensor data and/or control commands.', 'The various pieces of wellsite equipment described above and shown in \nFIGS.', '1\n and \n2\n may each comprise one or more hydraulic and/or electrical actuators, which when actuated, may cause corresponding components or portions of the piece of equipment to perform intended actions (e.g., work, tasks, movements, operations, etc.).', 'Each piece of equipment may further comprise a plurality of sensors, whereby one or more sensors may be associated with a corresponding actuator or another component of the piece of equipment and communicatively connected with an equipment controller.', 'Each sensor may be operable to generate sensor data (e.g., electrical sensor signals or measurements) indicative of an operational (e.g., mechanical, physical) status of the corresponding actuator or component, thereby permitting the operational status of the actuator to be monitored by the equipment controller.', 'The sensor data may be utilized by the equipment controller as feedback data, permitting operational control of the piece of equipment and coordination with other equipment.', 'Such sensor data may be indicative of performance of each individual actuator and, collectively, of the entire piece of wellsite equipment.', 'The present disclosure is further directed to performance based condition monitoring, which utilizes sensor data indicative of actions performed or otherwise caused by actuators of a piece of wellsite equipment to generate performance based condition indicators, which in turn, may be utilized as a basis for determining condition (e.g., operational health, operational life, maintenance condition, etc.) of the piece of wellsite equipment.', 'Performance based condition indicators may be indicative of condition of each actuator and/or other components facilitating each action performed by the piece of equipment.', 'Performance based condition indicators may be utilized as a basis for predicting developing faults (i.e., operational problems, breakdowns, failures) before such faults have manifested themselves through visual and/or physical detection by a wellsite operator or a full stop (i.e., failure) of the wellsite equipment.', 'When a fault has progressed to a point at which it is detectable via audible noise or excessive temperature (e.g., too hot to touch), the equipment is approaching point of failure.', 'Performance based condition monitoring according to one or more aspects of the present disclosure utilizes a bottom-up approach, which focuses on sensor data indicative of detailed operational parameters (e.g., physical states) of individual actuators or other components causing or otherwise associated with each action performed by a piece of equipment.', 'The sensor data may then be utilized to predict or determine the condition of the piece of wellsite equipment.', 'For example, the performance based condition monitoring may include recording sensor data for each sensor, actuator, and/or action of a piece of equipment, and analyzing or otherwise processing such sensor data to generate performance based condition indicators to predict or determine condition of the piece of equipment.', 'Performance based condition indicators may be calculated or otherwise generated based on sensor data indicative of physical states during each action caused, performed, or otherwise facilitated by a corresponding actuator or another part of a piece of wellsite equipment.', 'Performance based condition monitoring according to one or more aspects of the present disclosure may also consolidate the sensor data by generating the performance based condition indicators associated with a piece of wellsite equipment.', 'Performance based condition indicators may also be determined based on additional condition monitoring data indicative of other operational parameters, factors, conditions, characteristics, and descriptions related to a piece of wellsite equipment and the operations such wellsite equipment performs.', 'FIG.', '3\n is a flow-chart diagram showing an example implementation of a performance based condition monitoring process \n300\n according to one or more aspects of the present disclosure.', 'The condition monitoring data may include sensor data \n302\n, control commands \n304\n, process description data \n306\n, process variance data \n308\n, and process contextual data \n310\n.', 'As described above, sensor data \n302\n may be indicative of physical states of an actuator or another component of a piece of equipment during an action that was caused, performed, or otherwise facilitated by the actuator or another component.', 'The sensor data may be indicative of different points of measurement of the action performed.', 'The sensor data may include, for example, position of a hydraulic cylinder or motor, hydraulic fluid pressure, pressure within an accumulator, flow generated by a pump, force generated by an actuator, and temperature of hydraulic fluid.', 'Performance based condition indicators may also be calculated based on control commands (e.g., control signals, sequence steps, control functions, etc.) generated or outputted by equipment controllers to the individual actuators of the wellsite equipment triggering or causing the intended actions.', 'Use of control commands highlights performance of the actuators in the overall process efficiency, thereby treating the actuator performance independently of operator or process parameters.', 'The sensor signals may be compared to the control commands to determine differences in performance between an action that was intended, as indicated by the control commend, and an action that was actually executed, as indicated by the sensor signal.', 'Control commands may initiate the action.', 'Control commands may include, for example, control signals that are transmitted by an equipment controller (e.g., processing devices \n192\n, \n202\n and local controllers \n221\n-\n226\n shown in \nFIGS. \n1\n and \n2\n) to a mechanical controller, such as a hydraulic valve, to operate a hydraulic actuator, or an electrical controller, such as a relay or VFD, to operate an electrical actuator.', 'Process description data \n306\n may be descriptive or otherwise indicative of an individual action performed by a piece of wellsite equipment and defined by the sensor data.', 'Process description data \n306\n may include, for example, extension of a top drive dolly, charging of hydraulic accumulators, rotation of a draw works drum, and extension of racker main arm.', 'Process variance data \n308\n may be indicative of changed conditions or other factors associated with a piece of equipment that can influence or skew the sensor data while an action is performed.', 'Process variance data \n308\n may be indicative of, for example, weight of a gripper head, cylinder pressure, hydraulic fluid supply pressure, hydraulic fluid temperature, ambient temperature, speed reference, position reference, equipment controller deviation, and control joystick position.', 'Process contextual data \n310\n may be or comprise factors that can cause the sensor data associated with an action to be inaccurate.', 'Process contextual data \n310\n may be or comprise, for example, automatic sequence step, operational mode, trolley position, pipe data, slew position, main arm vertical position, hydraulic position deviation, weight cell reference, weight cell deviation, tubular interlock messages, zone management messages, operation messages, warnings, and alarms.', 'As further shown in \nFIG.', '3\n, the condition monitoring data \n302\n, \n304\n, \n306\n, \n308\n, \n310\n may be received and processed by a processing device \n312\n, which may generate performance based condition indicators \n314\n based on the condition monitoring data.', 'During operations of a piece of equipment, control commands \n304\n may be transmitted from an equipment controller to a mechanical/electrical controller to operate an actuator, thereby triggering or initiating an action.', 'While the action is performed, the control commands \n304\n and the sensor data \n302\n may be received by the processing device \n312\n.', 'The process description data \n306\n, the process variance data \n308\n, and process contextual data \n310\n may also be received by the processing device \n312\n while the action is performed.', 'The condition monitoring data \n306\n, \n308\n, \n310\n may be generated by an equipment controller operating the piece of equipment, other sensors associated with the piece of equipment, and/or from wellsite operators.', 'The process variance data \n308\n may be indicative of changed conditions or other factors that can influence the actions performed by the piece of equipment and, thereby, skew, shift, introduce noise, or otherwise change the sensor data \n302\n.', 'Accordingly, process variance data \n308\n may be utilized by the processing device \n312\n to shift sensor data \n302\n that was changed by the process variance data \n308\n to compensate for the changes in the sensor data \n302\n.', 'Process contextual data \n310\n may be indicative of, for example, a change of state or condition of the piece of equipment that renders sensor data \n302\n invalid.', 'Process contextual data \n310\n may, thus, be utilized by the processing device \n312\n to invalidate certain sensor data \n302\n that may be affected by the state or condition of the piece of equipment.', 'Accordingly, validated sensor data \n302\n may be processed by the processing device \n312\n to generate (e.g., calculate) the performance based condition indicators \n314\n, and invalidated sensor data \n302\n may not be utilized (e.g., may be disregarded) by the processing device \n312\n as a basis for generating the performance based condition indicators \n314\n.', 'Example performance based condition indicators \n314\n generated by the processing device \n312\n may comprise, for example, travel time, acceleration, mean velocity, maximum velocity, control command deviation (variance), control command deviation (amplitude), utilization spectrum, and exposure spectrum, among other examples.', 'The condition monitoring data \n302\n, \n304\n, \n306\n, \n308\n, \n310\n may be generated in real-time at high sampling rates and, thus, be or comprise high resolution data \n316\n using a high bandwidth data transmission and/or processing.', 'The performance based condition indicators \n314\n generated by the processing device \n312\n is or comprises a single measurement, as opposed to five measurements that include the condition monitoring data \n302\n, \n304\n, \n306\n, \n308\n, \n310\n.', 'Furthermore, the performance based condition indicators \n314\n may be calculated by the processing device \n312\n at lower frequencies than the sampling rates of the condition monitoring data \n302\n, \n304\n, \n306\n, \n308\n, \n310\n.', 'The performance based condition indicators \n314\n may, thus, be or comprise condensed (lower resolution) data \n318\n, permitting low bandwidth data transmission and/or processing.', 'The performance based condition indicators \n314\n may be transmitted to and stored in a historian \n320\n (e.g., database, data storage center).', 'The historian \n320\n may be located at the wellsite or at a location remote from the wellsite.', 'Current and historical performance based condition indicators \n314\n may be analyzed systematically or in real-time over a period of time by the processing device \n312\n at the wellsite or another processing device \n322\n located remotely from the wellsite.', 'The processing device \n312\n and/or processing device \n322\n may process the current and historical performance based condition indicators \n314\n to recognize changes or trends in performance (e.g., performance quality degradation) of individual actuators or components.', 'Such trends may be indicative of developing or potential faults, which may be repaired or otherwise addressed before failure or large reductions in performance can manifest.', 'When at least one of the performance based condition indicators \n314\n falls below a predetermined threshold, the processing device \n312\n and/or processing device \n322\n may then generate or output condition information \n324\n indicative of health of the piece of equipment.', 'The processing device \n312\n and/or processing device \n322\n may comprise or store computer program code, which when executed by the processing devices \n312\n, \n322\n may generate, calculate, or output the performance based condition indicators \n314\n and/or the condition information \n324\n based on the performance based condition indicators \n314\n.', 'The computer program code may be or comprise modeling or predictive processes, engines, algorithms, applications, and/or other programs operable to predict or determine condition of a piece of equipment and/or one or more of its components.\n \nFIGS.', '4\n and \n5\n are flow-chart diagrams showing example implementations of processes \n340\n, \n370\n according to one or more aspects of the present disclosure.', 'The process \n340\n shown in \nFIG.', '4\n may comprise generating the high resolution condition monitoring data \n342\n at a drill rig \n344\n and transmitting \n345\n such data \n342\n in real-time via a high bandwidth data pipeline \n346\n to a processing device \n348\n located at a remote (e.g., distant) location \n350\n from the drill rig \n344\n.', 'The data \n342\n may comprise, for example, the condition monitoring data \n302\n, \n304\n, \n306\n, \n308\n, \n310\n described above and shown in \nFIG.', '3\n.', 'The remote location \n350\n may be or comprise an offsite data center and/or server.', 'As shown, the process \n340\n utilizes the high bandwidth data pipeline \n346\n to transmit the high resolution input data \n342\n in real-time over a long distance to the processing device \n348\n, which may process the data \n342\n to generate or output \n352\n performance based condition indicators \n354\n and, thus, condense the data \n342\n at the remote location \n350\n.', 'The performance based condition indicators \n354\n may then be fed \n356\n to and processed by a processing device \n358\n comprising modeling or predictive processes, engines, algorithms, applications and/or other computer programs, which may determine and output \n360\n condition information \n362\n indicative of the condition of the piece of equipment and/or one or more of its components at the drill rig \n344\n.', 'The performance based condition indicators \n354\n may be saved in a database (such the historian \n320\n shown in \nFIG.', '3\n) and accessed by the processing device \n358\n.', 'The processing device \n358\n may be operable to analyze current and historical performance based condition indicators \n354\n systematically or in real-time over a period of time, such as to recognize changes or trends in performance (e.g., execution) of actions caused by individual actuators or components.', 'The recognized changes or trends may be indicative of developing or potential faults, which may be repaired or otherwise addressed before failure or large reductions in performance can manifest.', 'Because both processing devices \n348\n, \n358\n are located at the remote location \n350\n, the performance based condition indicators \n354\n and the condition information \n362\n may be generated or outputted by single processing device.', 'The process \n370\n shown in \nFIG.', '5\n may comprise features of the process \n340\n shown in \nFIG.', '4\n, including where indicated by the same numerals.', 'The process \n370\n may comprise generating the high resolution condition monitoring data \n342\n at a drill rig \n344\n and feeding \n372\n such data \n342\n to the processing device \n348\n, which may process the data \n342\n to generate or output \n352\n performance based condition indicators \n354\n and, thus, condense the data \n342\n at the drill rig \n344\n.', 'The condensed performance based condition indicators \n354\n may then be transmitted \n374\n in real-time via a low bandwidth data pipeline \n376\n to a processing device \n358\n located at a remote location \n350\n from the drill rig \n344\n.', 'The performance based condition indicators \n354\n may then be fed to and processed by a processing device \n358\n comprising modeling or predictive processes, engines, algorithms, applications and/or other computer programs, which may determine and output \n360\n condition information \n362\n indicative of the condition of the piece of equipment and/or one or more of its components at the remote location \n350\n.', 'Generating the condensed performance based condition indicators \n354\n at the drill rig \n344\n facilitates a reduction in data that has to be transmitted to the remote location \n350\n, thereby reducing bandwidth prerequisites between the rig \n344\n and the remote location \n350\n.', 'Reduced bandwidth use may, in turn, reduce transmission interruptions and/or loss of transmitted data.\n \nFIG.', '6\n shows a schematic view of an example implementation of a monitoring and control system \n400\n for monitoring and controlling a piece of equipment \n402\n according to one or more aspects of the present disclosure.', 'The control system \n400\n may be or comprise a portion of a well construction system, such as the well construction system \n100\n shown in \nFIG.', '1\n.', 'The piece of equipment \n402\n may be or comprise a piece of wellsite equipment of a well construction system, such as the well construction system \n100\n shown in \nFIG.', '1\n.', 'For example, the piece of equipment \n402\n may be or comprise a top drive \n116\n, a draw works \n119\n, an iron roughneck \n151\n, a PHM \n163\n, a catwalk \n131\n, a mud pump \n144\n, a BOP control unit \n137\n, a portion of the fluid reconditioning equipment \n170\n, or another piece of pipe handling equipment.', 'The piece of equipment \n402\n may comprise a plurality of actuators \n406\n, each operable to actuate a corresponding member, part, or component \n408\n of the piece of equipment \n402\n to perform a corresponding action (e.g., work, operation, task, process, etc.).', 'The actuators \n406\n may be or comprise hydraulic cylinders, hydraulic motors, and/or electrical motors, among other examples.', 'The components \n408\n may be or comprise arms, grippers, brackets, dollies, trolleys, drums, and wheels, among other examples.', 'The piece of equipment \n402\n may further comprise a plurality of mechanical and/or electrical controllers \n410\n, each selectively operable to power or otherwise operate a corresponding actuator \n406\n to perform an action via a corresponding component \n408\n.', 'The mechanical controllers \n410\n may be or comprise hydraulic valves and pneumatic valves, among other examples, and the electrical controllers \n410\n may be or comprise electrical relays and VFDs, among other examples.', 'The piece of equipment \n402\n may further comprise a plurality of sensors \n412\n, each disposed in association with a corresponding actuator \n406\n and/or component \n408\n, and operable to generate sensor data (e.g., sensor signals, measurements) indicative of physical status (i.e., operational status) caused by the corresponding actuator \n406\n and/or experienced by the component \n408\n.', 'The sensors \n412\n may be or comprise position sensors (e.g., encoders, rotary potentiometers, linear potentiometers, synchros, resolvers, proximity sensors, Hall effect sensors, and/or rotary variable-differential transformers (RVDTs)), pressure sensors, temperature sensors, and force sensors (e.g., load cells), among other examples.', 'The mechanical and/or electrical controllers \n410\n and the sensors \n412\n may be communicatively connected with an equipment controller \n404\n, thereby permitting the equipment controller \n414\n to receive and process the sensor data, and transmit control commands (i.e., control signals) based on the sensor data to the mechanical and/or electrical controllers \n410\n to cause the actuators \n406\n to perform the intended actions.', 'The equipment controller \n404\n may be a local or direct controller (e.g., a PLC) associated with the piece of equipment \n402\n.', 'The equipment controller \n404\n may be communicatively connected to another equipment controller \n414\n, which may be or comprise a coordinated controller (e.g., PC, IPC) operable to store execute machine-readable and executable program code instructions (i.e., computer program code \n416\n) in a memory device of the equipment controller \n414\n.', 'The equipment controller \n414\n may be located at a remote location from the equipment \n402\n and/or the equipment controller \n404\n.', 'The computer program code \n416\n may comprise a performance based condition monitoring application (PBCMA) \n418\n, which when executed, may be operable to receive from the equipment controller \n404\n the sensor data generated by the sensors \n412\n.', 'The performance based condition monitoring application \n418\n may also receive control commands, process description data, process variance data, and process contextual data generated, outputted, and/or utilized by at least one of the equipment controllers \n404\n, \n414\n and/or other sensors associated with the piece of equipment.', 'The performance based condition monitoring application \n418\n may comprise various mathematical algorithms, mathematical functions, logical functions, and other machine functions, such as may comprise mathematical and logical calculations with inputs and outputs.', 'The performance based condition monitoring application \n418\n, which when executed, may be further operable to process the input data and generate performance based condition indicators indicative of condition of the piece of equipment \n402\n based on the input data.', 'The performance based condition indicators may be stored by the equipment controller \n414\n or on an external memory device \n420\n.', 'Current and historical performance based condition indicators may be analyzed systematically or in real-time over a period of time by the performance based condition monitoring application \n418\n to recognize changes or trends in performance of the individual actuators \n406\n and/or components \n408\n.', 'Such trends may be indicative of developing or potential faults, which may be repaired or otherwise addressed before failure or large reductions in performance can manifest.', 'When the performance based condition indicators fall below a predetermined performance threshold, the equipment controller \n414\n may generate or output condition information indicative of health of the piece of equipment to a wellsite operator via an output device.\n \nFIG.', '7\n is a schematic view of at least a portion of an example implementation of a processing system \n500\n (or device) according to one or more aspects of the present disclosure.', 'The processing system \n500\n may be or form at least a portion of one or more equipment controllers and/or other processing systems shown in one or more of the \nFIGS.', '1\n-\n6\n.', 'Accordingly, the following description refers to \nFIGS.', '1\n-\n7\n, collectively.', 'The processing system \n500\n may be or comprise, for example, one or more processors, controllers, special-purpose computing devices, PCs (e.g., desktop, laptop, and/or tablet computers), personal digital assistants, smartphones, IPCs, PLCs, servers, internet appliances, and/or other types of computing devices.', 'The processing system \n500\n may be or form at least a portion of the processing devices \n192\n, \n202\n, \n312\n, \n322\n, \n348\n, \n358\n and/or equipment controllers \n221\n-\n226\n, \n404\n, \n414\n.', 'Although it is possible that the entirety of the processing system \n500\n is implemented within one device, it is also contemplated that one or more components or functions of the processing system \n500\n may be implemented across multiple devices, some or an entirety of which may be at the wellsite and/or remote from the wellsite.', 'The processing system \n500\n may comprise a processor \n512\n, such as a general-purpose programmable processor.', 'The processor \n512\n may comprise a local memory \n514\n, and may execute machine-readable and executable program code instructions \n532\n (i.e., computer program code) present in the local memory \n514\n and/or another memory device.', 'The processor \n512\n may execute, among other things, the program code instructions \n532\n and/or other instructions and/or programs to implement the example methods, processes, and/or operations described herein.', 'The program code instructions \n532\n stored in the local memory \n514\n, when executed by the processor \n512\n of the processing system \n500\n, may cause one or more portions or pieces of wellsite equipment of a well construction system to perform the example methods and/or operations described herein.', 'The processor \n512\n may be, comprise, or be implemented by one or more processors of various types suitable to the local application environment, and may include one or more of general-purpose computers, special-purpose computers, microprocessors, digital signal processors (DSPs), field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), and processors based on a multi-core processor architecture, as non-limiting examples.', 'Examples of the processor \n512\n include one or more INTEL microprocessors, microcontrollers from the ARM and/or PICO families of microcontrollers, embedded soft/hard processors in one or more FPGAs.', 'The processor \n512\n may be in communication with a main memory \n516\n, such as may include a volatile memory \n518\n and a non-volatile memory \n520\n, perhaps via a bus \n522\n and/or other communication means.', 'The volatile memory \n518\n may be, comprise, or be implemented by random access memory (RAM), static random access memory (SRAM), synchronous dynamic random access memory (SDRAM), dynamic random access memory (DRAM), RAMBUS dynamic random access memory (RDRAM), and/or other types of random access memory devices.', 'The non-volatile memory \n520\n may be, comprise, or be implemented by read-only memory, flash memory, and/or other types of memory devices.', 'One or more memory controllers (not shown) may control access to the volatile memory \n518\n and/or non-volatile memory \n520\n.', 'The processing system \n500\n may also comprise an interface circuit \n524\n, which is in communication with the processor \n512\n, such as via the bus \n522\n.', 'The interface circuit \n524\n may be, comprise, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'The interface circuit \n524\n may comprise a graphics driver card.', 'The interface circuit \n524\n may comprise a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).', 'The processing system \n500\n may be in communication with various video cameras, sensors, actuators, equipment controllers, and other devices of the well construction system via the interface circuit \n524\n.', 'The interface circuit \n524\n can facilitate communications between the processing system \n500\n and one or more devices by utilizing one or more communication protocols, such as an Ethernet-based network protocol (such as ProfiNET, OPC, OPC/UA, Modbus TCP/IP, EtherCAT, UDP multicast, Siemens S7 communication, or the like), a proprietary communication protocol, and/or another communication protocol.', 'One or more input devices \n526\n may also be connected to the interface circuit \n524\n.', 'The input devices \n526\n may permit human wellsite operators \n195\n to enter the program code instructions \n532\n, which may be or comprise control commands, operational parameters, and/or operational set-points.', 'The program code instructions \n532\n may further comprise modeling or predictive routines, equations, algorithms, processes, engines, algorithms, applications (e.g., a performance based condition monitoring application), and/or other programs operable to calculate performance based condition indicators and predict or determine condition of a piece of equipment and/or one or more of its components based on the performance based condition indicators, as described herein.', 'The input devices \n526\n may be, comprise, or be implemented by a keyboard, a mouse, a joystick, a touchscreen, a track-pad, a trackball, an isopoint, and/or a voice recognition system, among other examples.', 'One or more output devices \n528\n may also be connected to the interface circuit \n524\n.', 'The output devices \n528\n may permit for visualization or other sensory perception of various data, such as sensor data, status data, and/or other example data.', 'The output devices \n528\n may be, comprise, or be implemented by video output devices (e.g., an LCD, an LED display, a CRT display, a touchscreen, etc.), printers, and/or speakers, among other examples.', 'The one or more input devices \n526\n and the one or more output devices \n528\n connected to the interface circuit \n524\n may, at least in part, facilitate the HMIs described herein.', 'The processing system \n500\n may comprise a mass storage device \n530\n for storing data and program code instructions \n532\n.', 'The mass storage device \n530\n may be connected to the processor \n512\n, such as via the bus \n522\n.', 'The mass storage device \n530\n may be or comprise a tangible, non-transitory storage medium, such as a floppy disk drive, a hard disk drive, a compact disk (CD) drive, and/or digital versatile disk (DVD) drive, among other examples.', 'The processing system \n500\n may be communicatively connected with an external storage medium \n534\n via the interface circuit \n524\n.', 'The external storage medium \n534\n may be or comprise a removable storage medium (e.g., a CD or DVD), such as may be operable to store data and program code instructions \n532\n.', 'As described above, the program code instructions \n532\n may be stored in the mass storage device \n530\n, the main memory \n516\n, the local memory \n514\n, and/or the removable storage medium \n534\n.', 'Thus, the processing system \n500\n may be implemented in accordance with hardware (perhaps implemented in one or more chips including an integrated circuit, such as an ASIC), or may be implemented as software or firmware for execution by the processor \n512\n.', 'In the case of firmware or software, the implementation may be provided as a computer program product including a non-transitory, computer-readable medium or storage structure embodying computer program code instructions \n532\n (i.e., software or firmware) thereon for execution by the processor \n512\n.', 'The program code instructions \n532\n may include program instructions or computer program code that, when executed by the processor \n512\n, may cause one or more portions of the well construction system \n100\n to perform intended methods, processes, and/or operations disclosed herein.\n \nFIG.', '8\n is a graph \n610\n showing a single performance based condition indicator, namely a position profile \n612\n of a component of a piece of wellsite equipment while performing an action.', 'The profile \n612\n shows the relationship between position of the component, plotted along the vertical axis, and time, plotted along the horizontal axis.', 'The profile \n612\n may be determined by a processing device, such as the processing system \n500\n, based on sensor data generated by a position sensor associated with the component.', 'The horizontal axis may be indicative of the starting position of the component, and a horizontal reference line \n614\n may be indicative of the final position.', 'Furthermore, the vertical axis may be indicative of the starting (i.e., trigger) time of the action performed by the component, and a vertical reference line \n616\n may be indicative of the time \n618\n at which the action is completed.', 'The amount of time \n618\n for the action to be completed (e.g., travel time, cycle time) may be calculated and saved by the processing device as a single instance (i.e., sample) of a performance based condition indicator.', 'The graph \n610\n further shows an intended position profile \n622\n of the component while performing the action.', 'The profile \n622\n shows the relationship between an intended position of the component, plotted along the vertical axis, and time, plotted along the horizontal axis.', 'The profile \n612\n may be determined by the processing device based on control commands (i.e., control signals) generated by an equipment controller for controlling the piece of equipment.', 'The vertical axis may be indicative of the starting time of the action performed by the component, and a vertical reference line \n624\n may be indicative of the time \n626\n at which the control command intended to complete the action.', 'The lag time \n628\n (i.e., controller deviation) between the actual \n618\n and intended \n626\n completion times of the action may be calculated and saved by the processing device as a single instance of a performance based condition indicator in addition to or instead of the amount of time \n618\n for the action to be completed.\n \nFIG.', '9\n is a graph \n640\n showing a plurality performance based condition indicators \n642\n, namely cycle (i.e., travel) times \n642\n of a component of a piece of wellsite equipment recorded over time.', 'The graph \n640\n shows that the cycle times \n642\n are progressively increasing, which may indicate that quality of performance (i.e., performance as intended) or execution of the corresponding action is progressively decreasing.', 'Such trend may be indicative of declining condition of the actuator and/or component facilitating the corresponding action.', 'The graph \n640\n may be generated by a processing device, such as the processing system \n500\n, based on recorded historical and current cycle times.', 'The processing device may generate and output condition information indicative of the condition of the actuator and/or component of the piece of equipment based on the performance based condition indicators \n642\n.', 'For example, the processing device may output condition information indicative of remaining life of the corresponding actuator and/or component.', 'Furthermore, a threshold of acceptable condition, indicated by line \n644\n, may be set.', 'Accordingly, if a predetermined number of consecutive performance based condition indicators \n642\n meet or exceed the threshold \n644\n, such as at time \n648\n, the processing device may at such time \n648\n output condition information suggesting or mandating that maintenance on the piece of equipment be performed.', 'Furthermore, if a running average of the performance based condition indicators \n642\n, indicated by line \n646\n, meets or exceeds the threshold \n644\n, such as at time \n648\n, the processing device may at such time \n648\n output condition information suggesting or mandating that maintenance on the piece of equipment be performed.', 'Although graph \n640\n shows a plurality of performance based condition indicators \n642\n indicative of cycle time, the processing device can record and analyze other performance based condition indicators for changes or trends over time, which are indicative of progressive decrease in quality of performance or execution of the corresponding action.\n \nFIG.', '10\n is a flow-chart diagram of at least a portion of an example implementation of a process or method (\n700\n) according to one or more aspects of the present disclosure.', 'The method (\n700\n) may be performed utilizing or otherwise in conjunction with at least a portion of one or more implementations of one or more instances of the apparatus shown in one or more of \nFIGS.', '1\n-\n9\n, and/or otherwise within the scope of the present disclosure.', 'For example, the method (\n700\n) may be performed and/or caused, at least partially, by a processing system (e.g., processing system \n500\n shown in \nFIG.', '7\n) executing program code instructions according to one or more aspects of the present disclosure.', 'Thus, the following description of the method (\n700\n) also refers to apparatus shown in one or more of \nFIGS.', '1\n-\n9\n.', 'However, the method (\n700\n) may also be performed in conjunction with implementations of apparatus other than those depicted in \nFIGS.', '1\n-\n9\n that are also within the scope of the present disclosure.', 'The method (\n700\n) may comprise operating (\n705\n) a piece of equipment \n402\n at an oil and gas wellsite by performing (\n710\n) a plurality actions by a component \n408\n of the piece of equipment \n402\n and generating (\n715\n) a plurality of sensor measurements, wherein each sensor measurement may be indicative of a corresponding action.', 'The method (\n700\n) may further comprise receiving (\n720\n) the plurality of sensor measurements by a processing system \n500\n, calculating (\n725\n) a condition indicator for each component based on a corresponding sensor measurement, recording (\n730\n) each condition indicator over a period of time, and determining (\n735\n) condition of the piece of equipment \n402\n based on at least one of the condition indicators recorded over time.', 'Each condition indicator may be indicative of performance of a corresponding action, and determining (\n735\n) the condition of the piece of equipment \n402\n may be based on change in at least one of the condition indicators recorded over time.', 'The plurality of sensor measurements may be received (\n720\n) and the condition indicator may be calculated (\n725\n) in real-time while the actions are performed.', 'The method (\n700\n) may further comprise outputting (\n740\n) information related to maintenance of the piece of equipment \n402\n when at least one of the condition indicators recorded over time meets or falls below a predetermined threshold.', 'The method (\n700\n) may further comprise calculating (\n745\n) the condition indicator for each component \n408\n further based on a control command configured to initiate a corresponding action.', 'The method (\n700\n) may further comprise calculating (\n750\n) the condition indicator for each component \n408\n further based on a variance data indicative of a changed condition affecting at least one action thereby skewing a corresponding sensor measurement, wherein the variance data causes a shift in a corresponding sensor measurement to compensate for the changed condition.', 'The method (\n700\n) may further comprise calculating (\n755\n) the condition indicator for each component \n408\n further based on a contextual data indicative of a changed condition affecting at least one action thereby invalidating a corresponding sensor measurement, wherein the contextual data causes a corresponding sensor measurement not to be used as a basis for calculating a corresponding condition indicator.', 'At least one of the sensor measurements may be indicative of position of an actuator \n406\n or component \n408\n of the piece of equipment \n402\n facilitating a corresponding action.', 'At least one of the condition indicators may be indicative of travel time of an actuator \n406\n or component \n408\n of the piece of equipment \n402\n facilitating a corresponding action, average speed of an actuator \n406\n or component \n408\n of the piece of equipment \n402\n facilitating a corresponding action, or maximum speed of an actuator \n406\n or component \n408\n of the piece of equipment \n402\n facilitating a corresponding action.', 'In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces a computer program product comprising a non-transitory, computer-readable medium comprising instructions that, when executed by a processor of a processing system, cause the processing system to: receive a plurality of sensor measurements each generated by a corresponding sensor of a piece of equipment at an oil and gas wellsite, wherein the piece of equipment comprises a plurality of actuators each operable to facilitate a corresponding action performed by a component of the piece of equipment, and wherein each sensor measurement is indicative of a corresponding action; generate a condition indicator for each sensor based on a corresponding sensor measurement; record each condition indicator over a period of time; and determine condition of the piece of equipment based on at least one of the condition indicators recorded over time.', 'Each condition indicator may be indicative of performance of a corresponding action facilitated by a corresponding actuator.', 'The instructions may cause the processing system to determine the condition of the piece of equipment based on change in at least one of the condition indicators recorded over time.', 'The instructions may cause the processing system to output information related to maintenance of the piece of equipment when at least one of the condition indicators recorded over time meets or falls below a predetermined performance threshold.', 'The instructions may cause the processing system to generate the condition indicator for each sensor further based on a control command configured to initiate a corresponding action.', 'The instructions may cause the processing system to generate the condition indicator for at least one of the sensors further based on a variance data indicative of a changed condition affecting at least one action thereby skewing a corresponding sensor measurement, and the variance data may cause a shift in a corresponding sensor measurement to compensate for the changed condition.', 'The instructions may cause the processing system to generate the condition indicator for at least one of the sensors further based on a contextual data indicative of a changed condition affecting at least one action thereby invalidating a corresponding sensor measurement, and the contextual data may cause a corresponding sensor measurement not to be used as a basis for calculating a corresponding condition indicator.', 'At least one of the sensor measurements may be indicative of position of a corresponding actuator or component of the piece of equipment during a corresponding action.', 'At least one of the condition indicators may be indicative of: travel time of a corresponding actuator or component of the piece of equipment during a corresponding action; average speed of a corresponding actuator or component of the piece of equipment during a corresponding action; or maximum speed of a corresponding actuator or component of the piece of equipment during a corresponding action.', 'The instructions may cause the processing system to receive the plurality of sensor measurements and generate the condition indicators for each sensor in real-time while the actuators facilitate corresponding actions.', 'The present disclosure also introduces a method comprising operating a piece of equipment at an oil and gas wellsite by: performing a plurality actions by a component of the piece of equipment; and generating a plurality of sensor measurements, wherein each sensor measurement is indicative of a corresponding action.', 'The method may also comprise receiving the plurality of sensor measurements by a processing system; calculating a condition indicator for each component based on a corresponding sensor measurement; recording each condition indicator over a period of time; and determining condition of the piece of equipment based on at least one of the condition indicators recorded over time.', 'Each condition indicator may be indicative of performance of a corresponding action.', 'Determining the condition of the piece of equipment may be based on change in at least one of the condition indicators recorded over time.', 'The method may comprise outputting information related to maintenance of the piece of equipment when at least one of the condition indicators recorded over time meets or falls below a predetermined performance threshold.', 'The method may comprise calculating the condition indicator for each component further based on a control command configured to initiate a corresponding action.', 'The method may comprise calculating the condition indicator for each component further based on a variance data indicative of a changed condition affecting at least one action thereby skewing a corresponding sensor measurement, and the variance data may cause a shift in a corresponding sensor measurement to compensate for the changed condition.', 'The method may comprise calculating the condition indicator for each component further based on a contextual data indicative of a changed condition affecting at least one action thereby invalidating a corresponding sensor measurement, and the contextual data may cause a corresponding sensor measurement not to be used as a basis for calculating a corresponding condition indicator.', 'At least one of the sensor measurements may be indicative of position of an actuator or component of the piece of equipment facilitating a corresponding action.', 'At least one of the condition indicators may be indicative of: travel time of an actuator or component of the piece of equipment facilitating a corresponding action; average speed of an actuator or component of the piece of equipment facilitating a corresponding action; or maximum speed of an actuator or component of the piece of equipment facilitating a corresponding action.', 'The plurality of sensor measurements may be received and the condition indicator may be generated in real-time while the actions are performed.', 'The present disclosure also introduces a system comprising: (A) a piece of equipment at an oil and gas wellsite comprising: (1) a plurality of actuators each operable to facilitate a corresponding action by a component of the piece of equipment; and (2) a plurality of sensors each operable to generate a signal indicative of an operational parameter associated with a corresponding action; (B) a processing system comprising a processor and a memory storing a computer program code that, when executed, causes the processing system to: (1) receive the plurality of signals; (2) generate a condition indicator for each action based on a corresponding signal; (3) record each condition indicator over a period of time; and (4) determine condition of the piece of equipment based on at least one of the condition indicators recorded over time.', 'Each condition indicator may be indicative of quality of performance of a corresponding action.', 'The condition of the piece of equipment may be determined based on change in at least one of the condition indicators recorded over time.', 'The computer program code may cause the processing system to output information related to maintenance of the piece of equipment when at least one of the condition indicators recorded over time meets or falls below a predetermined performance threshold.', 'The computer program code may cause the processing system to generate the condition indicator for each action further based on a control command configured to initiate a corresponding action.', 'The computer program code may cause the processing system to generate the condition indicator for each action further based on a variance data indicative of a changed condition affecting at least one action thereby skewing a corresponding signal, and the variance data may cause a shift in a corresponding signal to compensate for the changed condition.', 'The computer program code may cause the processing system to generate the condition indicator for each action further based on a contextual data indicative of a changed condition affecting at least one action thereby invalidating a corresponding signal, and the contextual data may cause a corresponding signal not to be used as a basis for calculating a corresponding condition indicator.', 'At least one of the operational parameters may comprise position of the actuator or component of the piece of equipment while a corresponding action is performed.', 'At least one of the condition indicators may be indicative of: travel time of the actuator or component of the piece of equipment while a corresponding action is performed; average speed the actuator or component of the piece of equipment while a corresponding action is performed; or maximum speed of the actuator or component of the piece of equipment while a corresponding action is performed.', 'The plurality of sensor measurements may be received and each condition indicator may be generated in real-time while the actions are performed.', 'The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure.', 'A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same functions and/or achieving the same benefits of the embodiments introduced herein.', 'A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.', 'The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. § 1.72(b) to permit the reader to quickly ascertain the nature of the technical disclosure.', 'It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.']

['1.', 'A computer program product comprising:\na non-transitory, computer-readable medium comprising instructions that, when executed by a processor of a processing system, cause the processing system to:\nreceive a plurality of sensor measurements each generated by a corresponding sensor of a piece of equipment at an oil and gas wellsite, wherein the piece of equipment comprises a plurality of actuators each operable to facilitate a corresponding action performed by a component of the piece of equipment, wherein each sensor measurement is indicative of a corresponding action, and wherein at least one of the sensor measurements is indicative of position of a corresponding actuator or component of the piece of equipment during a corresponding action;\ngenerate a condition indicator for each sensor based on a corresponding sensor measurement and a control command configured to initiate a corresponding action;\nrecord each condition indicator over a period of time; and\ndetermine condition of the piece of equipment based on at least one of the condition indicators recorded over time.', '2.', 'The computer program product of claim 1 wherein each condition indicator is indicative of performance of a corresponding action facilitated by a corresponding actuator.', '3.', 'The computer program product of claim 1 wherein the instructions cause the processing system to determine the condition of the piece of equipment based on change in at least one of the condition indicators recorded over time.', '4.', 'The computer program product of claim 3 wherein the instructions further cause the processing system to output information related to maintenance of the piece of equipment when at least one of the condition indicators recorded over time meets or falls below a predetermined performance threshold.', '5.', 'The computer program product of claim 1 wherein the instructions further cause the processing system to generate the condition indicator for at least one of the sensors further based on variance data indicative of a changed condition affecting at least one action thereby skewing a corresponding sensor measurement, and wherein the variance data causes a shift in a corresponding sensor measurement to compensate for the changed condition.', '6.', 'The computer program product of claim 1 wherein the instructions further cause the processing system to generate the condition indicator for at least one of the sensors further based on a contextual data indicative of a changed condition affecting at least one action thereby invalidating a corresponding sensor measurement, and wherein the contextual data causes a corresponding sensor measurement not to be used as a basis for calculating a corresponding condition indicator.', '7.', 'The computer program product of claim 1 wherein at least one of the condition indicators is indicative of:\ntravel time of a corresponding actuator or component of the piece of equipment during a corresponding action;\naverage speed of a corresponding actuator or component of the piece of equipment during a corresponding action; or\nmaximum speed of a corresponding actuator or component of the piece of equipment during a corresponding action.', '8.', 'The computer program product of claim 1 wherein the instructions cause the processing system to receive the plurality of sensor measurements and generate the condition indicators for each sensor in real-time while the actuators facilitate corresponding actions.', '9.', 'A method comprising:\noperating a piece of equipment at an oil and gas wellsite by: performing a plurality actions by a component of the piece of equipment; and generating a plurality of sensor measurements, wherein each sensor measurement is indicative of a corresponding action and wherein at least one of the sensor measurements is indicative of position of an actuator or component of the piece of equipment facilitating a corresponding action; receiving the plurality of sensor measurements by a processing system; calculating a condition indicator for each component based on a corresponding sensor measurement and a control command configured to initiate a corresponding action; recording each condition indicator over a period of time; and determining condition of the piece of equipment based on at least one of the condition indicators recorded over time.', '10.', 'The method of claim 9 wherein each condition indicator is indicative of performance of a corresponding action.', '11.', 'The method of claim 9 wherein determining the condition of the piece of equipment is based on change in at least one of the condition indicators recorded over time.', '12.', 'The method of claim 11 further comprising outputting information related to maintenance of the piece of equipment when at least one of the condition indicators recorded over time meets or falls below a predetermined performance threshold.', '13.', 'The method of claim 9 further comprising calculating the condition indicator for each component further based on variance data indicative of a changed condition affecting at least one action thereby skewing a corresponding sensor measurement, and wherein the variance data causes a shift in a corresponding sensor measurement to compensate for the changed condition.', '14.', 'The method of claim 9 further comprising calculating the condition indicator for each component further based on a contextual data indicative of a changed condition affecting at least one action thereby invalidating a corresponding sensor measurement, and wherein the contextual data causes a corresponding sensor measurement not to be used as a basis for calculating a corresponding condition indicator.', '15.', 'The method of claim 9 wherein at least one of the condition indicators is indicative of:\ntravel time of an actuator or component of the piece of equipment facilitating a corresponding action;\naverage speed of an actuator or component of the piece of equipment facilitating a corresponding action; or\nmaximum speed of an actuator or component of the piece of equipment facilitating a corresponding action.', '16.', 'The method of claim 9 wherein the plurality of sensor measurements is received and the condition indicator is generated in real-time while the actions are performed.', '17.', 'A system comprising:\na piece of equipment at an oil and gas wellsite comprising: a plurality of actuators each operable to facilitate a corresponding action by a component of the piece of equipment; and a plurality of sensors each operable to generate a signal indicative of an operational parameter associated with a corresponding action, wherein at least one of the operational parameters comprises position of the actuator or component of the piece of equipment while a corresponding action is performed; a processing system comprising a processor and a memory storing a computer program code, which when executed, causes the processing system to: receive the plurality of signals; generate a condition indicator for each action based on a corresponding signal and a control command configured to initiate a corresponding action; record each condition indicator over a period of time; and determine condition of the piece of equipment based on at least one of the condition indicators recorded over time.', '18.', 'The system of claim 17 wherein each condition indicator is indicative of quality of performance of a corresponding action.', '19.', 'The system of claim 17 wherein the condition of the piece of equipment is determined based on change in at least one of the condition indicators recorded over time.', '20.', 'The system of claim 19 wherein the computer program code further causes the processing system to output information related to maintenance of the piece of equipment when at least one of the condition indicators recorded over time meets or falls below a predetermined performance threshold.', '21.', 'The system of claim 17 wherein the computer program code further causes the processing system to generate the condition indicator for each action further based on variance data indicative of a changed condition affecting at least one action thereby skewing a corresponding signal, and wherein the variance data causes a shift in a corresponding signal to compensate for the changed condition.', '22.', 'The system of claim 17 wherein the computer program code further causes the processing system to generate the condition indicator for each action further based on a contextual data indicative of a changed condition affecting at least one action thereby invalidating a corresponding signal, and wherein the contextual data causes a corresponding signal not to be used as a basis for calculating a corresponding condition indicator.', '23.', 'The system of claim 17 wherein at least one of the condition indicators is indicative of:\ntravel time of the actuator or component of the piece of equipment while a corresponding action is performed;\naverage speed of the actuator or component of the piece of equipment while a corresponding action is performed; or\nmaximum speed of the actuator or component of the piece of equipment while a corresponding action is performed.', '24.', 'The system of claim 17 wherein the plurality of sensor measurements is received and each condition indicator is generated in real-time while the actions are performed.']

['FIG.', '1 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG.', '2 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG.', '3 is a flow-chart diagram of at least a portion of a process according to one or more aspects of the present disclosure.; FIG. 4 is a flow-chart diagram of at least a portion of a process according to one or more aspects of the present disclosure.; FIG.', '5 is a flow-chart diagram of at least a portion of a process according to one or more aspects of the present disclosure.; FIG.', '6 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG. 7 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.; FIG. 8 is a graph related to one or more aspects of the present disclosure.', '; FIG.', '9 is a graph related to one or more aspects of the present disclosure.', '; FIG.', '10 is a flow-chart diagram of at least a portion of a method according to one or more aspects of the present disclosure.; FIG.', '1 is a schematic view of at least a portion of an example implementation of a well construction system 100 according to one or more aspects of the present disclosure.', 'The well construction system 100 represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'Although the well construction system 100 is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.; FIGS. 4 and 5 are flow-chart diagrams showing example implementations of processes 340, 370 according to one or more aspects of the present disclosure.', 'The process 340 shown in FIG.', '4 may comprise generating the high resolution condition monitoring data 342 at a drill rig 344 and transmitting 345 such data 342 in real-time via a high bandwidth data pipeline 346 to a processing device 348 located at a remote (e.g., distant) location 350 from the drill rig 344.', 'The data 342 may comprise, for example, the condition monitoring data 302, 304, 306, 308, 310 described above and shown in FIG.', '3.', 'The remote location 350 may be or comprise an offsite data center and/or server.', 'As shown, the process 340 utilizes the high bandwidth data pipeline 346 to transmit the high resolution input data 342 in real-time over a long distance to the processing device 348, which may process the data 342 to generate or output 352 performance based condition indicators 354 and, thus, condense the data 342 at the remote location 350.', 'The performance based condition indicators 354 may then be fed 356 to and processed by a processing device 358 comprising modeling or predictive processes, engines, algorithms, applications and/or other computer programs, which may determine and output 360 condition information 362 indicative of the condition of the piece of equipment and/or one or more of its components at the drill rig 344.', 'The performance based condition indicators 354 may be saved in a database (such the historian 320 shown in FIG.', '3) and accessed by the processing device 358.', 'The processing device 358 may be operable to analyze current and historical performance based condition indicators 354 systematically or in real-time over a period of time, such as to recognize changes or trends in performance (e.g., execution) of actions caused by individual actuators or components.', 'The recognized changes or trends may be indicative of developing or potential faults, which may be repaired or otherwise addressed before failure or large reductions in performance can manifest.', 'Because both processing devices 348, 358 are located at the remote location 350, the performance based condition indicators 354 and the condition information 362 may be generated or outputted by single processing device.', '; FIG.', '6 shows a schematic view of an example implementation of a monitoring and control system 400 for monitoring and controlling a piece of equipment 402 according to one or more aspects of the present disclosure.', 'The control system 400 may be or comprise a portion of a well construction system, such as the well construction system 100 shown in FIG.', '1.', 'The piece of equipment 402 may be or comprise a piece of wellsite equipment of a well construction system, such as the well construction system 100 shown in FIG.', '1.', 'For example, the piece of equipment 402 may be or comprise a top drive 116, a draw works 119, an iron roughneck 151, a PHM 163, a catwalk 131, a mud pump 144, a BOP control unit 137, a portion of the fluid reconditioning equipment 170, or another piece of pipe handling equipment.; FIG.', '7 is a schematic view of at least a portion of an example implementation of a processing system 500 (or device) according to one or more aspects of the present disclosure.', 'The processing system 500 may be or form at least a portion of one or more equipment controllers and/or other processing systems shown in one or more of the FIGS.', '1-6.', 'Accordingly, the following description refers to FIGS.', '1-7, collectively.;', 'FIG. 8 is a graph 610 showing a single performance based condition indicator, namely a position profile 612 of a component of a piece of wellsite equipment while performing an action.', 'The profile 612 shows the relationship between position of the component, plotted along the vertical axis, and time, plotted along the horizontal axis.', 'The profile 612 may be determined by a processing device, such as the processing system 500, based on sensor data generated by a position sensor associated with the component.', 'The horizontal axis may be indicative of the starting position of the component, and a horizontal reference line 614 may be indicative of the final position.', 'Furthermore, the vertical axis may be indicative of the starting (i.e., trigger) time of the action performed by the component, and a vertical reference line 616 may be indicative of the time 618 at which the action is completed.', 'The amount of time 618 for the action to be completed (e.g., travel time, cycle time) may be calculated and saved by the processing device as a single instance (i.e., sample) of a performance based condition indicator.', 'The graph 610 further shows an intended position profile 622 of the component while performing the action.', 'The profile 622 shows the relationship between an intended position of the component, plotted along the vertical axis, and time, plotted along the horizontal axis.', 'The profile 612 may be determined by the processing device based on control commands (i.e., control signals) generated by an equipment controller for controlling the piece of equipment.', 'The vertical axis may be indicative of the starting time of the action performed by the component, and a vertical reference line 624 may be indicative of the time 626 at which the control command intended to complete the action.', 'The lag time 628 (i.e., controller deviation) between the actual 618 and intended 626 completion times of the action may be calculated and saved by the processing device as a single instance of a performance based condition indicator in addition to or instead of the amount of time 618 for the action to be completed.; FIG. 9 is a graph 640 showing a plurality performance based condition indicators 642, namely cycle (i.e., travel) times 642 of a component of a piece of wellsite equipment recorded over time.', 'The graph 640 shows that the cycle times 642 are progressively increasing, which may indicate that quality of performance (i.e., performance as intended) or execution of the corresponding action is progressively decreasing.', 'Such trend may be indicative of declining condition of the actuator and/or component facilitating the corresponding action.', 'The graph 640 may be generated by a processing device, such as the processing system 500, based on recorded historical and current cycle times.', 'The processing device may generate and output condition information indicative of the condition of the actuator and/or component of the piece of equipment based on the performance based condition indicators 642.', 'For example, the processing device may output condition information indicative of remaining life of the corresponding actuator and/or component.', 'Furthermore, a threshold of acceptable condition, indicated by line 644, may be set.', 'Accordingly, if a predetermined number of consecutive performance based condition indicators 642 meet or exceed the threshold 644, such as at time 648, the processing device may at such time 648 output condition information suggesting or mandating that maintenance on the piece of equipment be performed.', 'Furthermore, if a running average of the performance based condition indicators 642, indicated by line 646, meets or exceeds the threshold 644, such as at time 648, the processing device may at such time 648 output condition information suggesting or mandating that maintenance on the piece of equipment be performed.', 'Although graph 640 shows a plurality of performance based condition indicators 642 indicative of cycle time, the processing device can record and analyze other performance based condition indicators for changes or trends over time, which are indicative of progressive decrease in quality of performance or execution of the corresponding action.', '; FIG.', '10 is a flow-chart diagram of at least a portion of an example implementation of a process or method (700) according to one or more aspects of the present disclosure.', 'The method (700) may be performed utilizing or otherwise in conjunction with at least a portion of one or more implementations of one or more instances of the apparatus shown in one or more of FIGS.', '1-9, and/or otherwise within the scope of the present disclosure.', 'For example, the method (700) may be performed and/or caused, at least partially, by a processing system (e.g., processing system 500 shown in FIG.', '7) executing program code instructions according to one or more aspects of the present disclosure.', 'Thus, the following description of the method (700) also refers to apparatus shown in one or more of FIGS.', '1-9.', 'However, the method (700) may also be performed in conjunction with implementations of apparatus other than those depicted in FIGS.', '1-9 that are also within the scope of the present disclosure.']

USD987670

Display screen with a graphical user interface

Apr 20, 2018

Torstein Soerhaug, Carsten Falck Russenes, Knut Helge Rygg, Rajesh Kumar Bade

Schlumberger Technology Corporation

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['No Abstract Available']

['Description\n\n\n\n\n\n\n \nFIG.', '1\n is a front view of a display screen with a graphical user interface;\n \nFIG.', '2\n is a front view of a display screen with a graphical user interface;\n \nFIG.', '3\n is a front view of a display screen with a graphical user interface;\n \nFIG.', '4\n is a front view of a display screen with a graphical user interface;\n \nFIG.', '5\n is a front view of a display screen with a graphical user interface;\n \nFIG.', '6\n is a front view of a display screen with a graphical user interface;\n \nFIG.', '7\n is a front view of a display screen with a graphical user interface;\n \nFIG.', '8\n is a front view of a display screen with a graphical user interface; and,\n \nFIG.', '9\n is a front view of a display screen with a graphical user interface.', 'In the drawings, each indicator bar provides a variable level of a respective parameter.', 'The drawings include one or more of the display screen or portion thereof, a menu, graphs, text, symbols, and mineral extraction equipment, such as a blowout preventer or diverter, as context.', 'In the drawings, the solid lines illustrate the claimed ornamental design, whereas the broken lines illustrate environmental features that form no part of the claimed ornamental design.']

['The ornamental design for a display screen with a graphical user interface, as shown and described.']

['FIG.', '1 is a front view of a display screen with a graphical user interface;; FIG.', '2 is a front view of a display screen with a graphical user interface;; FIG.', '3 is a front view of a display screen with a graphical user interface;; FIG. 4 is a front view of a display screen with a graphical user interface;; FIG.', '5 is a front view of a display screen with a graphical user interface;; FIG.', '6 is a front view of a display screen with a graphical user interface;; FIG. 7 is a front view of a display screen with a graphical user interface;; FIG. 8 is a front view of a display screen with a graphical user interface; and,; FIG.', '9 is a front view of a display screen with a graphical user interface.']

US11965405

Integrated well construction system operations

Mar 11, 2019

Espen Botnan, Anstein Jorud, Njál Aarsland, Christian Doennestad Nilssen

SCHLUMBERGER TECHNOLOGY CORPORATION

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['An integrated well construction system (IWCS, 100) operable for constructing a well via integrated control of integrated control devices that collectively control integrated subsystems of the IWCS.', 'The IWCS includes an IWCS communication network, the integrated control devices (each directly connected with the IWCS communication network), the integrated subsystems, and a control workstation directly connected with the IWCS communication network and operable to control each of the integrated control devices to thereby control the integrated subsystems.', 'During operation of the IWCS, data associated with the well construction operation is automatically collected and analyzed in real-time to determine parameters based on the data, and at least some of the determined parameters are used for controlling the well construction operation.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority to and the benefit of U.S. Provisional Application No. 62/640,999, titled “SYSTEM AND METHOD FOR REAL-TIME ANALYSIS OF DRILLING OPERATIONS”, filed Mar. 9, 2018, and U.S. Provisional Application No. 62/641,021, titled “SYSTEM AND METHOD FOR INTEGRATING MULTIPLE DRILLING EQUIPMENT INTO A SINGLE CONTROL NETWORK”, filed Mar. 9, 2018, U.S. Provisional Application No. 62/640,976, titled “SYSTEM AND METHOD FOR CONTROLLING DRILLING OPERATIONS”, filed Mar. 9, 2018, and Patent Cooperation Treaty Application Number PCT/US2019/021690, entitled, “INTEGRATED WELL CONSTRUCTION SYSTEM OPERATIONS,” filed on Mar. 11, 2019.', 'The four applications are hereby incorporated by reference in their entirety.', 'BACKGROUND OF THE DISCLOSURE\n \nWells are generally drilled into the ground or ocean bed to recover natural deposits of oil, gas, and other materials that are trapped in subterranean formations.', 'Such wells are drilled into the subterranean formations at the wellsite utilizing a well construction system having various surface and subterranean wellsite equipment operating in a coordinated manner.', 'The wellsite equipment may be grouped into various subsystems, wherein each subsystem performs a different operation controlled by a corresponding local and/or a remotely located controller.', 'The subsystems may include a rig control system, a fluid control system, a managed pressure drilling control system, a gas monitoring system, a closed-circuit television system, a choke pressure control system, and a well pressure control system, among other examples.', 'The wellsite equipment is monitored and controlled from a control center located at a wellsite surface.', 'A typical control center contains a wellsite control station utilized by several human wellsite operators (e.g., drillers) to monitor and control the wellsite equipment.', 'Although the equipment subsystems may operate in a coordinated manner, there is little or no communication between the subsystems and their controllers.', 'Accordingly, monitoring and control of the wellsite equipment or equipment subsystems may be performed via corresponding control panels of the wellsite control station.', 'Each control panel comprises an associated video output device (e.g., a video monitor) and a plurality of input devices (e.g., buttons, switches, joysticks, etc.).', 'Because there is no communication between the equipment subsystems, interactions and coordination between the various wellsite equipment are typically initiated by the wellsite operators.', 'For example, the wellsite operators may monitor the equipment subsystems to identify operational and safety events and manually implement processes to counteract such events.', 'Accordingly, a typical wellsite control center may be manned by multiple wellsite operators, each monitoring and controlling different wellsite equipment or equipment subsystem via a corresponding control panel.', 'Relying on multiple wellsite operators to monitor and manually control the wellsite equipment increases cost and limits speed, efficiency, and safety of well construction operations.', 'SUMMARY OF THE DISCLOSURE', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure introduces an integrated well construction system (IWCS) operable for constructing a well via integrated control of integrated control devices that collectively control integrated subsystems of the IWCS.', 'The IWCS includes an IWCS communication network; the integrated control devices, each directly connected with the IWCS communication network; the integrated subsystems; and a control workstation directly connected with the IWCS communication network and operable to control each of the integrated control devices to thereby control the integrated subsystems.', 'The present disclosure also introduces a control workstation directly connected with a communication network and operable to control each of multiple integrated control devices each directly connected with the communication network.', 'Each integrated control device controls a corresponding component of an IWCS, whereby control of the integrated control devices, via operations of the control workstation, controls the IWCS.', 'The present disclosure also introduces a computer program product including a tangible, computer-readable, non-transitory medium having instructions stored thereon for: automatically controlling integrated control devices that control integrated subsystems of an IWCS to perform combinations of predetermined operational sequences for constructing a well; receiving, via operation of a control workstation by a human operator, a selection of one of the operational sequences to be performed by the IWCS; receiving, via operation of the control workstation by the human operator, settings for first machines of the IWCS to be operated during the selected operational sequence; and in response to receiving a single commencement input via operation of the control workstation by the human operator, automatically starting and controlling the first machines and second machines of the IWCS to perform the selected operational sequence using the received settings.', 'The present disclosure also introduces a method including operating an IWCS that includes a fiberoptic ring network.', 'Nodes of the fiberoptic ring network include: programmable logic controllers (PLCs) of individual pieces of machinery forming the IWCS; video feed; drilling operator control; high-level supervisory control; and combinations thereof.', 'The present disclosure also introduces an apparatus that includes a communication network and integrated control devices each directly connected with the communication network.', 'Each integrated control device controls a corresponding component of an IWCS.', 'The IWCS is operable for constructing a well without other components not controlled by any of the integrated control devices.', 'The apparatus also includes a control workstation directly connected with the communication network and operable to control each of the integrated control devices to thereby control the IWCS.', 'The present disclosure also introduces an apparatus including a communication network and integrated control devices each directly connected with the communication network.', 'The integrated control devices control corresponding IWCS components.', 'The IWCS components are collectively operable for constructing a well exclusive of any component not controlled by any of the integrated control devices.', 'The apparatus also includes a control workstation directly connected with the communication network and operable to control each of the integrated control devices to thereby control the IWCS.', 'The present disclosure also introduces an apparatus including a communication network and integrated control devices each directly connected with the communication network.', 'Each integrated control device controls a corresponding one or more of integrated well construction components.', 'The integrated well construction components form an integrated well construction system operable for constructing a well without any other components.', 'A control workstation is directly connected with the communication network and is operable to control each integrated control device to thereby control the integrated well construction components.', 'The present disclosure also introduces a method including causing a well construction system to perform a well construction operation, whereby data associated with the well construction operation is automatically collected and analyzed in real-time to determine parameters based on the data, and at least some of the determined parameters are used for controlling the well construction operation.', 'The present disclosure also introduces a method including causing a well construction system to perform a well construction operation, whereby data associated with the well construction operation is automatically collected and analyzed in real-time to determine parameters based on the data, and at least some of the determined parameters each provide a basis for triggering at least one real-time well construction operation alarm.', 'The present disclosure also introduces an apparatus that includes an analysis-while-drilling (AWD) control system utilized in conjunction with a well construction system during a well construction operation.', 'Inputs for the AWD control system include: intended configuration of a well being constructed by the well construction system during the well construction operation; configuration of a drill string being used by the well construction system during the well construction operation; signals from drilling parameter sensors; and drilling equipment parameters.', 'Outputs from the AWD control system include real-time determination of: depth and trajectory of the well; bit depth; number of drill string tubulars and/or stands in the well; drill string volume, displacements, and weight; drilling fluid tank volumes and tank selections; drilling fluid loss and/or gain; trip tank difference volume; trip tank accumulated volume; total and/or per-section strokes and/or strokes-to-go of drilling fluid pumping system; total stroke rate of drilling fluid pumping system; drilling fluid pumping system liner capacities and efficiencies; individual and total drilling fluid flow into the well; annular drilling fluid velocity; total and/or per-section drilling fluid volumes; total minutes and/or minutes-to-go per section; drilling fluid return flow; bit runtime and revolutions; weight-on-bit; rate of penetration; hook load; and standpipe pressure.', 'The outputs from the AWD control system may further include a kick calculator and a kill sheet.', 'The outputs from the AWD control system may further include sensors and calculations for storage in a historian associated with the well construction system.', 'The outputs from the AWD control system may further include well construction operation warnings and alarms.', 'The present disclosure also introduces an apparatus that includes a control workstation directly connected with a communication network and operable to control multiple control devices each directly connected with the communication network.', 'Each control device controls a corresponding component of an IWCS, whereby control of the control devices, via operations of the control workstation, controls the IWCS.', 'The control workstation includes a display, a processor, and a memory storing: a construction program that, when executed by the processor, controls each control device; and an AWD program.', 'Inputs for the AWD system include intended configuration of a well being constructed by the well construction system during the well construction operation, configuration of a drill string being used by the well construction system during the well construction operation, signals from drilling parameter sensors, and drilling equipment parameters.', 'When executed by the processor, the AWD program generates in real-time, and displays in real-time in an AWD screen on the display, one or more of: a graphic display of the intended configuration and/or an actual configuration of the well, including depths; a graphic display of a shoe in the well; an animation of the intended and actual configurations of the well; an animation of the drill string in the well; value textual and/or graphic display of drilling fluid front tracking and/or depth; annular velocity per section; open hole volume; total strokes and minutes, strokes and minutes-to-go, and volume for one or more of: surface to bit; bit to shoe; bit to blow-out preventer; bit to surface; well circulation; full circulation; drill string displacement, open end and closed end; drill string weight; number of tubulars in the well; active volume; drilling fluid flow into the well; bit revolutions; and bit runtime.', 'The present disclosure also introduces an apparatus including a control workstation for use with an IWCS.', 'The IWCS is operable for constructing a well via integrated control of integrated control devices that collectively control integrated subsystems of the IWCS.', 'The control workstation includes a human-machine interface (HMI) that includes a display, a touchscreen, a joystick, and a processing system that includes a processor and a memory having a construction program thereon that, when executed by the processor: presents a human operator of the control workstation with a setup wizard guiding the operator through entering operating parameters for one or more well construction machines of the integrated subsystems to perform a well construction sequence; and controls the integrated control devices, and thus the integrated subsystems, to perform the well construction sequence based on the entered operating parameters.', 'The present disclosure also introduces an apparatus including an IWCS operable for constructing a well via integrated control of integrated control devices that collectively control integrated subsystems of the IWCS.', 'The IWCS includes a processing system including a processor and a memory having a construction program thereon that, when executed by the processor: controls each integrated control device, and thus each integrated subsystem, during each of multiple predetermined operational sequences; and prevents collisions between machines of the IWCS.', 'The present disclosure also introduces a method including constructing a well utilizing each of multiple automatically controlled well construction machines, including: a drawworks; an iron roughneck; a tong-handling trolley; a tong-handling arm; a catwalk; a tubular delivery arm; a lower stabilizing arm; an upper tubular restraint; an intermediate tubular restraint; a lower tubular restraint; a top drive; a top drive elevator; a fingerboard; a transfer bridge racker; a setback guide arm; a mousehole; a mousehole; a drilling fluid pumping system; and a drilling fluid recondition system.', 'The present disclosure also introduces a system operable to completely control each of multiple predetermined operational sequences of a well construction operation.', 'The sequences include: picking up single tubulars; making drilling connections; building tubular stands; tripping-in drill collar stands; tripping-out drill collar stands; tripping-out wet; backreaming; moving single tubulars from a well center to a catwalk using a top drive; moving tubular stands from the well center to the catwalk; moving casing from the catwalk to the well center using a casing tong; moving casing from the catwalk to the well center using a tubular delivery arm and a casing running tool; moving large diameter casing from the catwalk to the well center using the top drive and the casing running tool; building casing stands; and tripping-in casing stands without using the casing running tool.', 'These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the materials herein and/or practicing the principles described herein.', 'At least some aspects of the present disclosure may be achieved via means recited in the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is best understood from the following detailed description when read with the accompanying figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.\n \nFIG.', '2\n is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.\n \nFIG.', '3\n is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.\n \nFIG.', '4\n is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.\n \nFIG.', '5\n is a perspective view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '6\n is a perspective view of a portion of the apparatus shown in \nFIG.', '5\n according to one or more aspects of the present disclosure.', 'FIG.', '7\n is a top view of a portion of an example implementation of the apparatus shown in \nFIG.', '6\n according to one or more aspects of the present disclosure.', 'FIGS.', '8\n-\n10\n are example implementations of software controls displayed by the apparatus shown in \nFIG.', '7\n according to one or more aspects of the present disclosure.', 'FIGS.', '11\n-\n21\n are example implementations of screens displayed by the apparatus shown in \nFIG.', '7\n according to one or more aspects of the present disclosure.', 'FIG.', '22\n is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.\n \nFIG.', '23\n is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', 'FIG.', '24\n is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', 'DETAILED DESCRIPTION', 'It is to be understood that the following disclosure describes many example implementations for different aspects introduced herein.', 'Specific examples of components and arrangements are described below to simplify the present disclosure.', 'These are merely examples, and are not intended to be limiting.', 'In addition, the present disclosure may repeat reference numerals and/or letters in the various examples.', 'This repetition is for simplicity and clarity, and does not in itself dictate a relationship between the various implementations described herein.', 'Moreover, the formation of a first feature over or on a second feature in the description that follows may include implementations in which the first and second features are formed in direct contact, and may also include implementations in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.\n \nFIG.', '1\n is a schematic view of at least a portion of an example implementation of an integrated well construction system \n100\n (i.e., a drill rig) according to one or more aspects of the present disclosure.', 'The well construction system \n100\n represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'Although the well construction system \n100\n is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', 'The well construction system \n100\n is depicted in relation to a wellbore \n102\n formed by rotary and/or directional drilling from a wellsite surface \n104\n and extending into a subterranean formation \n106\n.', 'The well construction system \n100\n includes surface equipment \n110\n located at the wellsite surface \n104\n and a drill string \n120\n suspended within the wellbore \n102\n.', 'The surface equipment \n110\n may include a mast, a derrick, and/or other support structure \n112\n disposed over a rig floor \n114\n.', 'The drill string \n120\n may be suspended within the wellbore \n102\n from the support structure \n112\n.', 'The support structure \n112\n and the rig floor \n114\n are collectively supported over the wellbore \n102\n by legs and/or other support structures \n113\n.', 'The drill string \n120\n may comprise a bottom-hole assembly (BHA) \n124\n and means \n122\n for conveying the BHA \n124\n within the wellbore \n102\n.', 'The conveyance means \n122\n may comprise drill pipe, heavy-weight drill pipe (HWDP), wired drill pipe (WDP), and/or other means for conveying the BHA \n124\n within the wellbore \n102\n.', 'A downhole end of the BHA \n124\n may include or be coupled to a drill bit \n126\n.', 'Rotation of the drill bit \n126\n and the weight of the drill string \n120\n collectively operate to form the wellbore \n102\n.', 'The drill bit \n126\n may be rotated from the wellsite surface \n104\n and/or via a downhole mud motor (not shown) connected with the drill bit \n126\n.', 'The BHA \n124\n may also include various downhole tools \n180\n, \n182\n, \n184\n.', 'One or more of such downhole tools \n180\n, \n182\n, \n184\n may be or comprise an acoustic tool, a density tool, a directional drilling tool, an electromagnetic (EM) tool, a formation sampling tool, a formation testing tool, a gravity tool, a monitoring tool, a neutron tool, a nuclear tool, a photoelectric factor tool, a porosity tool, a reservoir characterization tool, a resistivity tool, a rotational speed sensing tool, a sampling-while-drilling (SWD) tool, a seismic tool, a surveying tool, a torsion sensing tool, and/or other measuring-while-drilling (MWD) or logging-while-drilling (LWD) tools.', 'One or more of the downhole tools \n180\n, \n182\n, \n184\n may be or comprise an MWD or LWD tool comprising a sensor package \n186\n operable for the acquisition of measurement data pertaining to the BHA \n124\n, the wellbore \n102\n, and/or the formation \n106\n.', 'One or more of the downhole tools \n180\n, \n182\n, \n184\n and/or another portion of the BHA \n124\n may also comprise a telemetry device \n187\n operable for communication with the surface equipment \n110\n, such as via mud-pulse telemetry.', 'One or more of the downhole tools \n180\n, \n182\n, \n184\n and/or another portion of the BHA \n124\n may also comprise a downhole processing device \n188\n operable to receive, process, and/or store information received from the surface equipment \n110\n, the sensor package \n186\n, and/or other portions of the BHA \n124\n.', 'The processing device \n188\n may also store executable computer programs (e.g., program code instructions), including for implementing one or more aspects of the operations described herein.', 'The support structure \n112\n may support a driver, such as a top drive \n116\n, operable to connect (perhaps indirectly) with an uphole end of the conveyance means \n122\n, and to impart rotary motion \n117\n to the drill string \n120\n and the drill bit \n126\n.', 'However, another driver, such as a kelly and rotary table (neither shown), may be utilized instead of or in addition to the top drive \n116\n to impart the rotary motion \n117\n.', 'The top drive \n116\n and the connected drill string \n120\n may be suspended from the support structure \n112\n via hoisting equipment, which may include a traveling block \n118\n, a crown block (not shown), and a draw works (DW) \n119\n storing a support cable or line \n123\n.', 'The crown block may be connected to or otherwise supported by the support structure \n112\n, and the traveling block \n118\n may be coupled with the top drive \n116\n, such as via a hook.', 'The DW \n119\n may be mounted on or otherwise supported by the rig floor \n114\n.', 'The crown block and traveling block \n118\n comprise pulleys or sheaves around which the support line \n123\n is reeved to operatively connect the crown block, the traveling block \n118\n, and the DW \n119\n (and perhaps an anchor).', 'The DW \n119\n may thus selectively impart tension to the support line \n123\n to lift and lower the top drive \n116\n, resulting in vertical motion \n135\n.', 'The DW \n119\n may comprise a drum, a frame, and a prime mover (e.g., an engine or motor) (not shown) operable to drive the drum to rotate and reel in the support line \n123\n, causing the traveling block \n118\n and the top drive \n116\n to move upward.', 'The DW \n119\n is also operable to reel out the support line \n123\n via a controlled rotation of the drum, causing the traveling block \n118\n and the top drive \n116\n to move downward.', 'The top drive \n116\n may comprise a grabber, a swivel (neither shown), tubular handling assembly links \n127\n terminating with an elevator \n129\n, and a drive shaft \n125\n operatively connected with a prime mover (not shown), such as via a gear box or transmission (not shown).', 'The drill string \n120\n may be mechanically coupled to the drive shaft \n125\n with or without a saver sub between the drill string \n120\n and the drive shaft \n125\n.', 'The prime mover of the top drive \n116\n is selectively operable to rotate the drive shaft \n125\n and the drill string \n120\n coupled with the drive shaft \n125\n.', 'Hence, the top drive \n116\n and the DW \n119\n cooperate to advance the drill string \n120\n into the formation \n106\n to form the wellbore \n102\n.', 'The tubular handling assembly links \n127\n and the elevator \n129\n of the top drive \n116\n may handle tubulars (e.g., drill pipes, drill collars, casing joints, etc.) that are not mechanically coupled to the drive shaft \n125\n.', 'For example, when the drill string \n120\n is being tripped into or out of the wellbore \n102\n, the elevator \n129\n may grasp the tubulars of the drill string \n120\n such that the tubulars may be raised and/or lowered via the hoisting equipment mechanically coupled to the top drive \n116\n.', 'The grabber may include a clamp that clamps onto a tubular when making-up and/or breaking-out a connection of a tubular with the drive shaft \n125\n.', 'The top drive \n116\n may have a guide system (not shown), such as rollers that track up and down a guide rail on the support structure \n112\n.', 'The guide system may aid in keeping the top drive \n116\n aligned with the wellbore \n102\n, and in preventing the top drive \n116\n from rotating during drilling by transferring reactive torque to the support structure \n112\n.', 'The well construction system \n100\n may further include a well control system for maintaining well pressure control.', 'For example, the drill string \n120\n may be conveyed within the wellbore \n102\n through various blowout preventer (BOP) equipment disposed at the wellsite surface \n104\n on top of the wellbore \n102\n and perhaps below the rig floor \n114\n.', 'The BOP equipment may be operable to control pressure within the wellbore \n102\n via a series of pressure barriers (e.g., rams) between the wellbore \n102\n and the wellsite surface \n104\n.', 'The BOP equipment may include a BOP stack \n130\n, an annular preventer \n132\n, and/or a rotating control device (RCD) \n138\n mounted above the annular preventer \n132\n.', 'The BOP equipment \n130\n, \n132\n, \n138\n may be mounted on top of a wellhead \n134\n.', 'The well control system may further include a BOP control unit \n137\n (i.e., a BOP closing unit) operatively connected with the BOP equipment \n130\n, \n132\n, \n138\n and operable to actuate, drive, operate, or otherwise control the BOP equipment \n130\n, \n132\n, \n138\n.', 'The BOP control unit \n137\n may be or comprise a hydraulic fluid power unit fluidly connected with the BOP equipment \n130\n, \n132\n, \n138\n and selectively operable to hydraulically drive various portions (e.g., rams, valves, seals) of the BOP equipment \n130\n, \n132\n, \n138\n.', 'The well construction system \n100\n may further include a drilling fluid circulation system operable to circulate fluids between the surface equipment \n110\n and the drill bit \n126\n during drilling and other operations.', 'For example, the drilling fluid circulation system may be operable to inject a drilling fluid from the wellsite surface \n104\n into the wellbore \n102\n via an internal fluid passage \n121\n extending longitudinally through the drill string \n120\n.', 'The drilling fluid circulation system may comprise a pit, a tank, and/or other fluid container \n142\n holding the drilling fluid (i.e., mud) \n140\n, and a pump \n144\n operable to move the drilling fluid \n140\n from the container \n142\n into the fluid passage \n121\n of the drill string \n120\n via a fluid conduit \n146\n extending from the pump \n144\n to the top drive \n116\n and an internal passage extending through the top drive \n116\n.', 'The fluid conduit \n146\n may comprise one or more of a pump discharge line, a stand pipe, a rotary hose, and a gooseneck (not shown) connected with a fluid inlet of the top drive \n116\n.', 'The pump \n144\n and the container \n142\n may be fluidly connected by a fluid conduit \n148\n, such as a suction line.', 'During drilling operations, the drilling fluid may continue to flow downhole through the internal passage \n121\n of the drill string \n120\n, as indicated by directional arrow \n158\n.', 'The drilling fluid may exit the BHA \n124\n via ports \n128\n in the drill bit \n126\n and then circulate uphole through an annular space (annulus) \n108\n of the wellbore \n102\n defined between an exterior of the drill string \n120\n and the wall of the wellbore \n102\n, such flow being indicated in \nFIG.', '1\n by directional arrows \n159\n.', 'In this manner, the drilling fluid lubricates the drill bit \n126\n and carries formation cuttings uphole to the wellsite surface \n104\n.', 'The returning drilling fluid may exit the annulus \n108\n via a bell nipple \n139\n, the RCD \n138\n, and/or a ported adapter \n136\n (e.g., a spool, a wing valve, etc.) located below one or more portions of the BOP stack \n130\n.', 'The drilling fluid exiting the annulus \n108\n via the bell nipple \n139\n may be directed toward drilling fluid reconditioning equipment \n170\n via a fluid conduit \n145\n (e.g., gravity return line) to be cleaned and/or reconditioned, as described below, prior to being returned to the container \n142\n for recirculation.', 'The drilling fluid exiting the annulus \n108\n via the RCD \n138\n may be directed into a fluid conduit \n160\n (e.g., a drilling pressure control line), and may pass through various wellsite equipment fluidly connected along the conduit \n160\n prior to being returned to the container \n142\n for recirculation.', 'For example, the drilling fluid may pass through a choke manifold \n162\n (e.g., a drilling pressure control choke manifold) and then through the drilling fluid reconditioning equipment \n170\n.', 'The choke manifold \n162\n may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow through and out of the choke manifold \n162\n.', 'Backpressure may be applied to the annulus \n108\n by variably restricting flow of the drilling fluid or other fluids flowing through the choke manifold \n162\n.', 'The greater the restriction to flow through the choke manifold \n162\n, the greater the backpressure applied to the annulus \n108\n.', 'The drilling fluid exiting the annulus \n108\n via the ported adapter \n136\n may be directed into a fluid conduit \n171\n (e.g., rig choke line), and may pass through various equipment fluidly connected along the conduit \n171\n prior to being returned to the container \n142\n for recirculation.', 'For example, the drilling fluid may pass through a choke manifold \n173\n (e.g., a rig choke manifold, well control choke manifold, etc.)', 'and then through the drilling fluid reconditioning equipment \n170\n.', 'The choke manifold \n173\n may include at least one choke and a plurality of fluid valves (neither shown) collectively operable to control the flow through the choke manifold \n173\n.', 'Backpressure may be applied to the annulus \n108\n by variably restricting flow of the drilling fluid or other fluids flowing through the choke manifold \n173\n.', 'Before being returned to the container \n142\n, the drilling fluid returning to the wellsite surface \n104\n may be cleaned and/or reconditioned via the drilling fluid reconditioning equipment \n170\n, which may include one or more of liquid gas separators, shale shakers, centrifuges, and other drilling fluid cleaning equipment.', 'The liquid gas separators may remove formation gasses entrained in the drilling fluid discharged from the wellbore \n102\n, and the shale shakers may separate and remove solid particles \n141\n (e.g., drill cuttings) from the drilling fluid.', 'The drilling fluid reconditioning equipment \n170\n may further comprise equipment operable to remove additional gas and finer formation cuttings from the drilling fluid and/or modify physical properties or characteristics (e.g., rheology) of the drilling fluid.', 'For example, the drilling fluid reconditioning equipment \n170\n may include a degasser, a desander, a desilter, a mud cleaner, and/or a decanter, among other examples.', 'Intermediate tanks/containers (not shown) may be utilized to hold the drilling fluid while the drilling fluid progresses through the various stages or portions of the drilling fluid reconditioning equipment \n170\n.', 'The cleaned/reconditioned drilling fluid may be transferred to the fluid container \n142\n, the solid particles \n141\n removed from the drilling fluid may be transferred to a solids container \n143\n (e.g., a reserve pit), and the removed gas may be transferred to a flare stack \n172\n via a conduit \n174\n (e.g., a flare line) to be burned or to a container (not shown) for storage and removal from the wellsite.', 'The surface equipment \n110\n may include tubular handling equipment operable to store, move, connect, and disconnect tubulars (e.g., drill pipes) to assemble and disassemble the conveyance means \n122\n of the drill string \n120\n during drilling operations.', 'For example, a catwalk \n131\n may be utilized to convey tubulars from a ground level, such as along the wellsite surface \n104\n, to the rig floor \n114\n, permitting the tubular handling assembly links \n127\n to grab and lift the tubulars above the wellbore \n102\n for connection with previously deployed tubulars.', 'The catwalk \n131\n may have a horizontal portion \n147\n and a ramp or inclined portion \n149\n, wherein the inclined portion extends between the horizontal portion and the rig floor \n114\n.', 'The catwalk \n131\n may comprise a skate \n133\n movable along a groove (not shown) extending longitudinally along the horizontal and inclined portions of the catwalk \n131\n.', 'The skate \n133\n may be operable to convey (e.g; push) the tubulars along the catwalk \n131\n to the rig floor \n114\n.', 'The skate \n133\n may be driven along the groove by a drive system (not shown), such as a pulley system or a hydraulic system.', 'Additionally, one or more racks (not shown) may adjoin the horizontal portion of the catwalk \n131\n.', 'The racks may be feeding tables (not shown), such as may have a spinner unit and/or other means for transferring tubulars to the groove of the catwalk \n131\n.', 'An iron roughneck (RN) \n151\n may be positioned on the rig floor \n114\n.', 'The RN \n151\n may comprise a torquing portion \n153\n, such as may include a spinner and a torque wrench comprising a lower tong and an upper tong.', 'The torquing portion \n153\n of the RN \n151\n may be moveable toward and at least partially around the drill string \n120\n, such as may permit the RN \n151\n to make-up and break-out connections of the drill string \n120\n.', 'The torquing portion \n153\n may also be moveable away from the drill string \n120\n, such as may permit the RN \n151\n to move clear of the drill string \n120\n during drilling operations.', 'The spinner of the RN \n151\n may be utilized to apply low torque to make-up and break-out threaded connections between tubulars of the drill string \n120\n, and the torque wrench may be utilized to apply a higher torque to tighten and loosen the threaded connections.', 'The system \n100\n may include more than one instance of the RN \n151\n.', 'Reciprocating slips \n161\n may be located on the rig floor \n114\n, such as may accommodate therethrough the downhole tubulars during make-up and break-out operations and during the drilling operations.', 'The reciprocating slips \n161\n may be in an open position during drilling operations to permit advancement of the drill string \n120\n therethrough, and in a closed position to clamp near an upper end of the conveyance means \n122\n (e.g., assembled tubulars) to thereby suspend and prevent advancement of the drill string \n120\n within the wellbore \n102\n, such as during the make-up and break-out operations.', 'During drilling operations, the hoisting equipment lowers the drill string \n120\n while the top drive \n116\n rotates the drill string \n120\n to advance the drill string \n120\n within the wellbore \n102\n and into the formation \n106\n.', 'During the advancement of the drill string \n120\n, the reciprocating slips \n161\n are in an open position, and the RN \n151\n is moved away or is otherwise clear of the drill string \n120\n.', 'When the upper portion of the tubular in the drill string \n120\n that is made up to the drive shaft \n125\n is near the reciprocating slips \n161\n and/or the rig floor \n114\n, the top drive \n116\n ceases rotating and the reciprocating slips \n161\n close to clamp the tubular made up to the drive shaft \n125\n.', 'The grabber of the top drive \n116\n then clamps the upper portion of the tubular made up to the drive shaft \n125\n, and the drive shaft \n125\n rotates in a direction reverse from the drilling rotation to break-out the connection between the drive shaft \n125\n and the made up tubular.', 'The grabber of the top drive \n116\n may then release the tubular of the drill string \n120\n.', 'Multiple tubulars may be loaded on the rack of the catwalk \n131\n and individual tubulars may be transferred from the rack to the groove in the catwalk \n131\n.', 'The tubular positioned in the groove may be conveyed along the groove by the skate \n133\n until an end of the tubular projects above the rig floor \n114\n.', 'The elevator \n129\n of the top drive \n116\n may then grasp the protruding end, and the DW \n119\n is operated to lift the top drive \n116\n, the elevator \n129\n, and the new tubular.', 'The hoisting equipment then raises the top drive \n116\n, the elevator \n129\n, and the tubular until the tubular is aligned with the upper portion of the drill string \n120\n clamped by the slips \n161\n.', 'The RN \n151\n is moved toward the drill string \n120\n, and the lower tong of the torquing portion \n153\n clamps onto the upper portion of the drill string \n120\n.', 'The spinning system rotates the new tubular into the upper portion of the drill string \n120\n.', 'The upper tong then clamps onto the new tubular and rotates with high torque to complete making-up the connection with the drill string \n120\n.', 'In this manner, the new tubular becomes part of the drill string \n120\n.', 'The RN \n151\n then releases and moves clear of the drill string \n120\n.', 'The grabber of the top drive \n116\n may then clamp onto the drill string \n120\n.', 'The drive shaft \n125\n (or a saver sub or other device extending from the drive shaft \n125\n) is brought into contact with the drill string \n120\n and rotated to make-up a connection between the drill string \n120\n and the drive shaft \n125\n.', 'The grabber then releases the drill string \n120\n, and the reciprocating slips \n161\n are moved to the open position.', 'The drilling operations may then resume.', 'The tubular handling equipment may further include a pipe handling manipulator (PHM) \n163\n disposed in association with a vertical pipe rack \n165\n for storing tubulars \n111\n (or stands of two or three tubulars).', 'The vertical pipe rack \n165\n may comprise or support a fingerboard (FIB) \n166\n defining a plurality of slots configured to support or otherwise hold the tubulars \n111\n within or above a setback \n164\n (e.g., a platform or another area) located adjacent to, along, or below the rig floor \n114\n.', 'The FIB \n166\n may comprise a plurality of fingers (not shown), each associated with a corresponding slot and operable to close around and/or otherwise interpose individual tubulars \n111\n to maintain the tubulars \n111\n within corresponding slots of the setback \n164\n.', 'The vertical pipe rack \n165\n may be connected with and supported by the support structure \n112\n or another portion of the wellsite system \n100\n.', 'The FIB \n166\n/setback \n164\n provide storage (e.g., temporary storage) of tubulars \n111\n during various operations, such as during and between tripping out and tripping of the drill string \n120\n.', 'The PHM \n163\n may be operable to transfer the tubulars \n111\n between the FIB \n166\n/setback \n164\n and the drill string \n120\n (i.e., space above the suspended drill string \n120\n).', 'For example, the PHM \n163\n may include arms \n167\n terminating with clamps \n169\n, such as may be operable to grasp and/or clamp onto one of the tubulars \n111\n.', 'The arms \n167\n of the PHM \n163\n may extend and retract, and/or at least a portion of the PHM \n163\n may be rotatable and/or movable toward and away from the drill string \n120\n, such as may permit the PHM \n163\n to transfer the tubular \n111\n between the FIB \n166\n/setback \n164\n and the drill string \n120\n.', 'The surface equipment \n110\n of the well construction system \n100\n may also comprise a control center \n190\n from which various portions of the well construction system \n100\n, such as the top drive \n116\n, the hoisting system, the tubular handling system, the drilling fluid circulation system, the well control system, and the BHA \n124\n, among other examples, may be monitored and controlled.', 'The control center \n190\n may be located on the rig floor \n114\n or another location of the well construction system \n100\n, such as the wellsite surface \n104\n.', 'The control center \n190\n may comprise a facility \n191\n (e.g., a room, a cabin, a trailer, etc.) containing a control workstation \n197\n, which may be operated by a human wellsite operator \n195\n to monitor and control various wellsite equipment or portions of the well construction system \n100\n.', 'The control workstation \n197\n may comprise or be communicatively connected with a processing device \n192\n (e.g., a controller, a computer, etc.), such as may be operable to receive, process, and output information to monitor and/or control operations of one or more portions of the well construction system \n100\n.', 'For example, the processing device \n192\n may be communicatively connected with the various surface and downhole equipment described herein, and may be operable to receive signals from and transmit signals to such equipment to perform various operations described herein.', 'The processing device \n192\n may store executable program code, instructions, and/or operational parameters or set-points, including for implementing one or more aspects of methods and operations described herein.', 'The processing device \n192\n may be located within and/or outside of the facility \n191\n.', 'The control workstation \n197\n may be operable for entering or otherwise communicating control commands to the processing device \n192\n by the wellsite operator \n195\n, and for displaying or otherwise communicating information from the processing device \n192\n to the wellsite operator \n195\n.', 'The control workstation \n197\n may comprise a plurality of human-machine interface (HMI) devices, including one or more input devices \n194\n (e.g., a keyboard, a mouse, a joystick, a touchscreen, etc.) and one or more output devices \n196\n (e.g., a video monitor, a touchscreen, a printer, audio speakers, etc.).', 'Communication between the processing device \n192\n, the input and output devices \n194\n, \n196\n, and the various wellsite equipment may be via wired and/or wireless communication means.', 'However, for clarity and ease of understanding, such communication means are not depicted, and a person having ordinary skill in the art will appreciate that such communication means are within the scope of the present disclosure.', 'Well construction systems within the scope of the present disclosure may include more or fewer components than as described above and depicted in \nFIG.', '1\n.', 'Additionally, various equipment and/or subsystems of the well construction system \n100\n shown in \nFIG.', '1\n may include more or fewer components than as described above and depicted in \nFIG. \n1\n.', 'For example, various engines, motors, hydraulics, actuators, valves, and/or other components not explicitly described herein may be included in the well construction system \n100\n, and are within the scope of the present disclosure.', 'FIG.', '2\n is a schematic view of an example implementation of a wellsite system \n200\n comprising a plurality of pipe handling equipment, each comprising or carrying one or more sensors operable to generate sensor measurements indicative of corresponding operational parameters (e.g., position, speed, acceleration, etc.) of such equipment.', 'According to one or more aspects of the present disclosure, the various pieces of equipment of the wellsite system \n200\n may be operable to move tubulars \n111\n between various positions of the wellsite system \n200\n, to perform processes described herein, including assembly and disassembly of a drill string \n120\n.', 'The wellsite system \n200\n may form a portion of and/or operate in conjunction with the well construction system \n100\n shown in \nFIG.', '1\n, including where indicated by the same numerals.', 'Accordingly, the following description refers to \nFIGS.', '1\n and \n2\n, collectively.', 'The wellsite system \n200\n may comprise a support structure \n112\n supporting various automated pipe handling equipment operable to transport tubulars \n111\n (e.g., drill pipes, stands of drill pipe, casing joints) between different areas of the wellsite system \n200\n.', 'The wellsite system \n200\n may further comprise a catwalk \n131\n operable to transport tubulars \n111\n from a storage area (not shown) at a ground level (e.g., wellsite surface \n104\n) to a rig floor \n114\n.', 'The support structure \n112\n or another portion of the wellsite system \n200\n may support a tubular delivery arm (TDA) \n202\n operable to grab the tubulars \n111\n, one at a time, from an FIB \n166\n and/or the catwalk \n131\n and lift or otherwise move the tubulars \n111\n to predetermined positions.', 'For example, the TDA \n202\n may move a tubular \n111\n over the wellbore \n102\n, such that the tubular \n111\n is aligned with the wellbore center \n203\n above the reciprocating slips \n161\n and fluid control equipment \n213\n (e.g., BOP equipment \n130\n, \n132\n, \n138\n mounted on top of a wellhead \n134\n, etc.) located below the rig floor \n114\n.', 'The TDA \n202\n may also move a tubular \n111\n over a mouse hole (MOH) \n204\n, such that the tubular \n111\n is aligned with a mouse hole center \n205\n, permitting one or more tubulars \n111\n to be disposed therein such that two or more tubulars \n111\n can be coupled together to form a stand.', 'The TDA \n202\n may also move a tubular \n111\n to a doping stand or area \n206\n, such that the tubular \n111\n may be prepared for make-up operations by a washer/doper device (doper) \n209\n.', 'For example the doper \n209\n may apply dope to pin ends of tubulars \n111\n in preparation for being made-up, and/or may wash pin ends of tubulars \n111\n prior to transfer to the FIB \n166\n/setback \n164\n.', 'Accordingly, the doper \n209\n may be positioned in conjunction with the doping area \n206\n, the MOH \n204\n, and/or other areas, such as for performing the washing/doping operations on a tubular \n111\n while the tubular \n111\n is engaged by the TDA \n202\n.', 'The doper \n209\n may also be positioned in conjunction with the TDA \n202\n.', 'Portions of the TDA \n202\n may be operable to move horizontally and/or vertically, as indicated by arrows \n208\n, such as may permit a grabber or clamp \n210\n of the TDA \n202\n to grab or otherwise receive a tubular \n111\n being transferred to the rig floor \n114\n by the catwalk \n131\n.', 'A DW \n119\n may be operable to move the TDA \n202\n vertically along the support structure \n112\n, as indicated by arrows \n212\n.', 'The DW \n119\n may be operatively connected with the TDA \n202\n via a support line \n214\n extending between the TDA \n202\n and a drum \n216\n of the DW \n119\n.', 'One or more sensors \n211\n may be disposed in association with the clamp \n210\n, such as may permit the sensor \n211\n to generate sensor signals indicative of presence or proximity of a tubular \n111\n received by the clamp \n210\n.', 'One or more sensors \n218\n may be disposed in association with the DW \n119\n, such as may permit the sensor \n218\n to generate sensor measurements (e.g., electrical sensor signals or data) indicative of rotational position of the drum \n216\n.', 'Such sensor measurements may be further indicative of vertical position of the TDA \n202\n along the support structure \n112\n.', 'The TDA \n202\n may carry or comprise one or more sensors \n220\n operable to generate sensor measurements indicative of tension applied to and, thus, weight supported by the TDA \n202\n.', 'The support structure \n112\n may further support a plurality of sensors \n226\n, each located at a predetermined or otherwise known reference position \n221\n-\n224\n (i.e., height) along the support structure \n112\n.', 'Such known reference positions \n221\n-\n224\n may be known in the oil and gas industry as flags or targets.', 'Each sensor \n226\n may be operable to generate a sensor signal indicative of presence or proximity of the TDA \n202\n when the TDA \n202\n passes the sensor \n226\n, thereby indicating a corresponding known position \n221\n-\n224\n of the TDA \n202\n at such time.', 'The support structure \n112\n or another portion of the wellsite system \n200\n may further support a lower stabilization arm (LSA) \n228\n operable to receive (e.g., catch) and stabilize via a holding device \n230\n a tubular \n111\n supported by the TDA \n202\n after the tubular \n111\n is lifted off of the catwalk \n131\n and swings toward the support structure \n112\n.', 'The LSA \n228\n may then pivot \n231\n to horizontally move \n233\n the tubular \n111\n to align the tubular \n111\n with the mouse hole center \n205\n or the doping area \n206\n.', 'The holding device \n230\n may be extended around (at least partially) a tubular \n111\n to provide additional stability, such as during stabbing prior to make-up operations.', 'The LSA \n228\n may carry or comprise one or more sensors \n232\n operable to generate sensor measurements indicative of stabilization arm extension (i.e., length) and/or angle \n234\n between the LSA \n228\n and the support structure \n112\n or a reference plane.', 'The support structure \n112\n or another portion of the wellsite system \n200\n may support a vertical rack \n165\n comprising or supporting the FIB \n166\n defining a plurality of slots configured to support or otherwise hold the tubulars \n111\n within or above a setback \n164\n located adjacent to, along, of below the rig floor \n114\n.', 'The support structure \n112\n, the vertical rack \n165\n, or another portion of the wellsite system \n200\n, such as the PHM \n163\n, may support an upper tubular constraint (UTC) \n242\n and a lower tubular constraint (LTC) \n244\n, each operable to grab a corresponding upper and lower portion of a tubular \n111\n via a corresponding grabber or clamp \n246\n, \n248\n.', 'The UTC \n242\n and LTC \n244\n may stabilize the tubular \n111\n and/or horizontally move the corresponding upper and/or lower portions of the tubular \n111\n, as indicated by arrows \n247\n, \n249\n, to align the tubular \n111\n with the mouse hole center \n205\n or the doping area \n206\n.', 'The UTC \n242\n and LTC \n244\n may also horizontally move the corresponding upper and/or lower portions of the tubular \n111\n, as indicated by arrows \n247\n, \n249\n, to position the tubular \n111\n along a tubular handoff position (THP) \n207\n, at which the TDA \n202\n can grab and align the tubular \n111\n with the wellbore center \n203\n for connection with the drill string \n120\n or align the tubular \n111\n with a portion of the catwalk \n131\n, permitting the tubular \n111\n to be lowered onto the catwalk \n131\n, which may then move the tubular \n111\n from the rig floor \n114\n to the ground level (e.g., the wellsite surface \n104\n).', 'The THP \n207\n may be horizontally aligned with the doping area \n206\n, such as may permit a tubular \n111\n to be doped and/or washed by the doper \n209\n before the TDA \n202\n aligns the tubular along the wellbore center \n203\n for connection with the drill string \n120\n or positions the tubular \n111\n to be lowered by the catwalk \n131\n.', 'The UTC \n242\n and LTC \n244\n may each carry or comprise one or more corresponding sensors \n250\n, \n252\n operable to generate sensor measurements indicative of extension or horizontal positions \n247\n, \n249\n of the corresponding clamps \n246\n, \n248\n.', 'The support structure \n112\n, the vertical rack \n165\n, or another portion of the wellsite system \n200\n may further support an intermediate tubular constraint (ITC) \n236\n operable to grab a tubular \n111\n supported by the TDA \n202\n via a grabber or clamp \n238\n, stabilize the tubular \n111\n, and/or horizontally move \n235\n the tubular \n111\n to align the tubular \n111\n with the mouse hole center \n205\n or the doping area \n206\n.', 'The ITC \n236\n may carry or comprise one or more sensors \n240\n operable to generate sensor measurements indicative of extension or horizontal position \n235\n of the clamp \n238\n.', 'The support structure \n112\n, the vertical rack \n165\n, or another portion of the wellsite system \n200\n may further support a transfer bridge racker (TBR) \n254\n and a setback guide arm (SGA) \n262\n, a collectively operable to store (e.g., hang, rack) the tubulars \n111\n in the FIB \n166\n of the vertical rack \n165\n within or above the setback \n164\n.', 'For example, the TBR \n254\n may be operable to grab an upper portion of a tubular \n111\n via a grabber or clamp \n256\n and move the tubular \n111\n horizontally and/or vertically between the FIB \n166\n and the THP \n207\n, as indicated by arrows \n258\n.', 'The TBR \n254\n may carry or comprise one or more corresponding sensors \n260\n operable to generate sensor measurements indicative of the horizontal and/or vertical position \n258\n of the clamp \n256\n.', 'The SGA \n262\n may be operable to grab a lower portion of the tubular \n111\n via a grabber or clamp \n264\n and guide the lower portion of the tubular \n111\n horizontally and/or vertically between the setback \n164\n and the THP \n207\n, as indicated by arrows \n266\n, in unison (i.e., synchronously) with the TBR \n254\n.', 'The SGA \n262\n may carry or comprise one or more corresponding sensors \n268\n operable to generate sensor measurements indicative of the horizontal and/or vertical position \n266\n of the clamp \n264\n.', 'When the tubular \n111\n is aligned with the THP \n207\n, the TDA \n202\n can grab and align the tubular \n111\n with the wellbore center \n203\n for connection with the drill string \n120\n or align the tubular with a portion of the catwalk \n131\n, permitting the tubular \n111\n to be lowered onto the catwalk \n131\n.', 'The UTC \n242\n, the ITC \n236\n, and the LTC \n244\n may temporarily grasp a tubular \n111\n while in the THP \n207\n, such as while the TBR \n254\n, the SGA \n262\n, and the TDA \n202\n are performing other operations.', 'One or more of the UTC \n242\n, the ITC \n236\n, and the LTC \n244\n may also be extendable to grasp a tubular \n111\n in (or move the tubular \n111\n to) the MOH \n204\n.', 'For example, the tubular \n111\n may be temporarily stored in the MOH \n204\n while awaiting addition to the drill string \n120\n or while awaiting transfer to the THP \n207\n and/or the FIB \n166\n/setback \n164\n.', 'The catwalk \n131\n may comprise a skate \n133\n movable along a groove (not shown) extending longitudinally along the catwalk \n131\n.', 'The skate \n133\n may be driven along the groove by a drive system \n270\n, such as a winch system comprising a spool \n272\n driven by a motor (not shown).', 'The drive system \n270\n may be selectively operable to pull the skate \n133\n in opposing directions along the catwalk \n131\n via a line \n274\n extending between the spool \n272\n and the skate \n133\n.', 'Actuated by the drive system \n270\n, the skate \n133\n may be operable to convey (e.g., push) a tubular \n111\n along the catwalk \n131\n to the rig floor \n114\n.', 'The skate \n133\n may move the box end of the tubular \n111\n into the clamp \n210\n of the TDA \n202\n, such that the tubular \n111\n can be lifted by the TDA \n202\n.', 'The drive system \n270\n may carry or comprise one or more corresponding sensors \n276\n operable to generate sensor measurements indicative of rotational position of the spool \n272\n and, thus, position of the skate \n133\n along the catwalk \n131\n.', 'The sensors \n218\n, \n276\n may be or comprise, for example, encoders, rotary potentiometers, and/or rotary variable-differential transformers (RVDTs).', 'The sensors \n220\n may be or comprise, for example, strain gauges and/or load cells.', 'The sensors \n211\n, \n226\n may be or comprise, for example, proximity sensors and Hall effect sensors.', 'The sensors \n232\n, \n240\n, \n250\n, \n252\n, \n260\n, \n268\n may be or comprise, for example, encoders, rotary potentiometers, linear potentiometers, or rotary variable-differential transformers (RVDTs).', 'The present disclosure further provides various implementations of systems and/or methods for controlling one or more portions of the well construction system \n100\n and the wellsite system \n200\n.', 'Because the wellsite system \n200\n may form a portion of and/or operate in conjunction with the well construction system \n100\n, the well construction system \n100\n and the wellsite system \n200\n are hereinafter referred to collectively as a well construction system \n100\n, \n200\n.', 'FIG.', '3\n is a schematic view of at least a portion of an example implementation of a monitoring and control system \n300\n for monitoring and controlling various equipment, portions, and subsystems of the well construction system \n100\n, \n200\n according to one or more aspects of the present disclosure.', 'The following description refers to \nFIGS.', '1\n-\n3\n, collectively.', 'The control system \n300\n may be in real-time communication with the well construction system \n100\n, \n200\n and may be utilized to monitor and/or control various portions, components, and equipment of the well construction system \n100\n, \n200\n.', 'The equipment of the well construction system \n100\n, \n200\n may be grouped into several subsystems, each operable to perform a corresponding operation and/or a portion of the well construction operations described herein.', 'The subsystems may include a rig control (RC) system \n311\n, a fluid circulation (FC) system \n312\n, a managed pressure drilling control (MPDC) system \n313\n, a choke pressure control (CPC) system \n314\n, a well pressure control (WC) system \n315\n, and a closed-circuit television (CCTV) system \n316\n, among other examples.', 'The control workstation \n197\n may be utilized to monitor, configure, control, and/or otherwise operate one or more of the well construction subsystems \n311\n-\n316\n.', 'The RC system \n311\n may include the support structure \n112\n, the drill string hoisting system or equipment (e.g., the DW \n119\n), the drill string rotational system (e.g., the top drive \n116\n and/or the rotary table and kelly), the reciprocating slips \n161\n, the drill pipe handling system or equipment (e.g., the catwalk \n131\n, the TDA \n202\n, the setback \n164\n, the FIB \n166\n, the TBR \n254\n, the SGA \n262\n, the LTC \n244\n, the ITC \n236\n, the UTC \n242\n, the LSA \n228\n, and the RN \n151\n), electrical generators, and other equipment.', 'Accordingly, the RC system \n311\n may perform power generation and/or distribution, and may control drill pipe handling, hoisting, and rotation operations.', 'The RC system \n311\n may also serve as a support platform for drilling equipment and staging ground for rig operations, such as connection make-up and break-out operations described above.', 'The FC system \n312\n may include the drilling fluid \n140\n, the pumps \n144\n, drilling fluid loading and/or mixing equipment, the drilling fluid reconditioning equipment \n170\n, the flare stack \n172\n, and/or other fluid control equipment.', 'Accordingly, the FC system \n312\n may perform fluid operations of the well construction system \n100\n.', 'The MPDC system \n313\n may include the RCD \n138\n, the choke manifold \n162\n, downhole pressure sensors \n186\n, and/or other equipment.', 'The CPC system \n314\n may comprise the choke manifold \n173\n and/or other equipment.', 'The WC system \n315\n may comprise the BOP equipment \n130\n, \n132\n, \n138\n, the BOP control unit \n137\n, and a BOP control station (not shown) for controlling the BOP control unit \n137\n.', 'The CCTV system \n316\n may include the video cameras \n198\n and corresponding actuators (e.g., motors) for moving or otherwise controlling direction of the video cameras \n198\n.', 'The CCTV system \n316\n may be utilized to capture real-time video of various portions or subsystems \n311\n-\n315\n of the well construction system \n100\n and display video signals from the video cameras \n198\n on the video output devices \n196\n to display in real-time the various portions or subsystems \n311\n-\n315\n.', 'Each of the well construction subsystems \n311\n-\n316\n may further comprise various communication equipment (e.g., modems, network interface cards/circuits, etc.) and communication conductors (e.g., cables), communicatively connecting the equipment (e.g., sensors and actuators) of each subsystem \n311\n-\n316\n with the control workstation \n197\n and/or other equipment.', 'Although the wellsite equipment listed above and shown in \nFIGS.', '1\n and \n2\n is associated with certain wellsite subsystems \n311\n-\n316\n, such associations are merely examples that are not intended to limit or prevent such wellsite equipment from being associated with two or more wellsite subsystems \n311\n-\n316\n and/or different wellsite subsystems \n311\n-\n316\n.', 'The control system \n300\n may include a wellsite computing resource environment \n305\n, which may be located at the wellsite \n104\n as part of the well construction system \n100\n, \n200\n.', 'The control system \n300\n may also include a remote computing resource environment \n306\n, which may be located offsite (i.e., not at the wellsite \n104\n).', 'The control system \n300\n may also include various local controllers (e.g., controllers \n341\n-\n346\n shown in \nFIG.', '4\n) associated with the subsystems \n311\n-\n316\n and/or individual components or equipment of the well construction system \n100\n, \n200\n.', 'As described above, each subsystem \n311\n-\n316\n of the well construction system \n100\n, \n200\n may include actuators (e.g., actuators \n331\n-\n336\n shown in \nFIG.', '4\n) and sensors (e.g., sensors \n321\n-\n326\n shown in \nFIG.', '4\n) for performing operations of the well construction system \n100\n, \n200\n.', 'These actuators and sensors may be monitored and/or controlled via the wellsite computing resource environment \n305\n, the remote computing resource environment \n306\n, and/or the corresponding local controllers.', 'For example, the wellsite computing resource environment \n305\n and/or the local controllers may be operable to monitor the sensors of the wellsite subsystems \n311\n-\n316\n in real-time, and to provide real-time control commands to the subsystems \n311\n-\n316\n based on the received sensor data.', 'Data may be generated by sensors and/or computation and may be utilized for coordinated control among two or more of the subsystems \n311\n-\n316\n.', 'The control system \n300\n may be in real-time communication with the various components of the well construction system \n100\n, \n200\n.', 'For example, the local controllers may be in communication with various sensors and actuators of the corresponding subsystems \n311\n-\n316\n via local communication networks (not shown), and the wellsite computing resource environment \n305\n may be in communication with the subsystems \n311\n-\n316\n via a data bus or network \n309\n.', 'As described below, data or sensor signals generated by the sensors of the subsystems \n311\n-\n316\n may be made available for use by processes (e.g., processes \n374\n, \n375\n shown in \nFIG.', '4\n) and/or devices of the wellsite computing resource environment \n305\n.', 'Similarly, data or control signals generated by the processes and/or devices of the wellsite computing resource environment \n305\n may be automatically communicated to various actuators of the subsystems \n311\n-\n316\n, perhaps pursuant to predetermined programming, such as to facilitate well construction operations and/or other operations described herein.', 'The remote computing resource environment \n306\n, the wellsite computing resource environment \n305\n, and the subsystems \n311\n-\n316\n of the well construction system \n100\n, \n200\n may be communicatively connected with each other via a network connection, such as via a wide-area-network (WAN), a local-area-network (LAN), and/or other networks also within the scope of the present disclosure.', 'A “cloud” computing environment is one example of a remote computing resource environment \n306\n.', 'The wellsite computing resource environment \n305\n may be or form at least a portion of the processing device \n192\n and, thus, may form a portion of or be communicatively connected with the control workstation \n197\n.\n \nFIG.', '4\n is a schematic view of an example implementation of the control system \n300\n shown in \nFIG.', '3\n communicatively connected with the subsystems \n311\n-\n316\n of the well construction system \n100\n, \n200\n, including the RC system \n311\n, the FC system \n312\n, the MPDC system \n313\n, the CPC system \n314\n, the WC system \n315\n, and the CCTV system \n316\n.', 'The following description refers to \nFIGS.', '1\n-\n4\n, collectively.', 'The well construction system \n100\n, \n200\n may include one or more onsite user devices (OUD) \n302\n communicatively connected with the wellsite computing resource environment \n305\n.', 'The onsite user devices \n302\n may be or comprise stationary user devices intended to be stationed at the well construction system \n100\n, \n200\n and/or portable user devices.', 'For example, the onsite user devices \n302\n may include a desktop computer, a laptop computer, a smartphone and/or other portable smart device, a personal digital assistant (PDA), a tablet/touchscreen computer, a wearable computer, and/or other devices.', 'The onsite user devices \n302\n may be operable to communicate with the wellsite computing resource environment \n305\n of the well construction system \n100\n, \n200\n and/or the remote computing resource environment \n306\n.', 'At least one of the onsite user devices \n302\n may be or comprise at least a portion of the control workstation \n197\n shown in \nFIG.', '1\n and/or the processing device \n192\n shown in \nFIGS.', '1\n and \n3\n, which may be located within the facility \n191\n.', 'The wellsite computing resource environment \n305\n and/or other portions of the well construction system \n100\n, \n200\n may further comprise an information technology (IT) system \n319\n operable to communicatively interconnect various portions of the wellsite computing resource environment \n305\n and/or to communicatively connect the wellsite computing resource environment \n305\n with other portions of the well construction system \n100\n, \n200\n.', 'The IT system \n319\n may include communication conduits, software, computers, and/or other IT equipment facilitating communication among one or more portions of the wellsite computing resource environment \n305\n and/or between the wellsite computing resource environment \n305\n and another portion of the well construction system \n100\n, \n200\n, such as the remote computing resource environment \n306\n, the onsite user device \n302\n, and the subsystems \n311\n-\n316\n.', 'The control system \n300\n may include (or otherwise be utilized in conjunction with) one or more offsite user devices \n303\n.', 'The offsite user devices \n303\n may be or comprise a desktop computer, a laptop computer, a smartphone and/or other portable smart device, a PDA, a tablet/touchscreen computer, a wearable computer, and/or other devices.', 'The offsite user devices \n303\n may be operable to receive and/or transmit information (e.g., for monitoring functionality) from and/or to the well construction system \n100\n, \n200\n, such as by communication with the wellsite computing resource environment \n305\n via the network \n308\n.', 'The offsite user devices \n303\n may be utilized just for monitoring functions.', 'However, one or more of the offsite user devices \n303\n may be utilized to provide control processes for controlling operation of the various subsystems \n311\n-\n316\n of the well construction system \n100\n, \n200\n.', 'The offsite user devices \n303\n and/or the wellsite computing resource environment \n305\n may also be operable to communicate with the remote computing resource environment \n306\n via the network \n308\n.', 'The network \n308\n may be a WAN, such as the internet, a cellular network, a satellite network, other WANs, and/or combinations thereof.', 'The subsystems \n311\n-\n316\n of the well construction system \n100\n, \n200\n and the control system \n300\n may include sensors \n321\n-\n326\n, actuators \n331\n-\n336\n, and local controllers \n341\n-\n346\n.', 'The controllers \n341\n-\n346\n may be programmable logic controllers (PLCs) and/or other controllers having aspects similar to the example processing device \n1000\n shown in \nFIG.', '23\n.', 'The RC system \n311\n may include one or more sensors \n321\n, one or more actuators \n331\n, and one or more controllers \n341\n.', 'The FC system \n312\n may include one or more sensors \n322\n, one or more actuators \n332\n, and one or more controllers \n342\n.', 'The MPDC system \n313\n may include one or more sensors \n323\n, one or more actuators \n333\n, and one or more controllers \n343\n.', 'The CPC system \n314\n may include one or more sensors \n324\n, one or more actuators \n334\n, and one or more controllers \n344\n (e.g., a BOP control station \n470\n shown in \nFIG. \n6\n).', 'The WC system \n315\n may include one or more sensors \n325\n, one or more actuators \n335\n, and one or more controllers \n345\n.', 'The CCTV system \n316\n may include one or more sensors \n326\n, one or more actuators \n336\n, and one or more controllers \n346\n.', 'The sensors \n321\n-\n326\n may include sensors utilized for operation of the various subsystems \n311\n-\n316\n of the well construction system \n100\n, \n200\n.', 'For example, the sensors \n321\n-\n326\n may include cameras, position sensors, pressure sensors, temperature sensors, flow rate sensors, vibration sensors, current sensors, voltage sensors, resistance sensors, gesture detection sensors or devices, voice actuated or recognition devices or sensors, and/or other examples.', 'The sensors \n321\n-\n326\n may be operable to provide sensor data to the wellsite computing resource environment \n305\n, such as to the coordinated control device \n304\n.', 'For example, the sensors \n321\n-\n326\n may provide sensor data \n351\n-\n356\n, respectively.', 'The sensor data \n351\n-\n356\n may include signals or information indicative of equipment operation status (e.g., on or off, up or down, set or release, etc.), drilling parameters (e.g., depth, hook load, torque, etc.), auxiliary parameters (e.g., vibration data of a pump), flow rate, temperature, operational speed, position, and pressure, among other examples.', 'The acquired sensor data \n351\n-\n356\n may include or be associated with a timestamp (e.g., date and/or time) indicative of when the sensor data \n351\n-\n356\n was acquired.', 'The sensor data \n351\n-\n356\n may also or instead be aligned with a depth, time, and/or other drilling parameter.', 'Acquiring the sensor data \n351\n-\n356\n at the coordinated control device \n304\n may facilitate measurement of the same physical properties at different locations of the well construction system \n100\n, \n200\n, wherein the sensor data \n351\n-\n356\n may be utilized for measurement redundancy to permit continued well construction operations.', 'Measurements of the same physical properties at different locations may also be utilized for detecting equipment conditions among different physical locations at the wellsite surface \n104\n or within the wellbore \n102\n.', 'Variation in measurements at different wellsite locations over time may be utilized to determine equipment performance, system performance, scheduled maintenance due dates, and the like.', 'For example, slip status (e.g., set or unset) may be acquired from the sensors \n321\n and communicated to the wellsite computing resource environment \n305\n.', 'Acquisition of fluid samples may be measured by a sensor, such as the sensors \n186\n, \n323\n, and related with bit depth and time measured by other sensors.', 'Acquisition of data from the video cameras \n198\n, \n325\n may facilitate detection of arrival and/or installation of materials or equipment at the well construction system \n100\n, \n200\n.', 'The time of arrival and/or installation of materials or equipment may be utilized to evaluate degradation of material, scheduled maintenance of equipment, and other evaluations.', 'The coordinated control device \n304\n may facilitate control of one or more of the subsystems \n311\n-\n316\n at the level of each individual subsystem \n311\n-\n316\n.', 'For example, in the FC system \n312\n, sensor data \n352\n may be fed into the controller \n342\n, which may respond to control the actuators \n332\n.', 'However, for control operations that involve multiple systems, the control may be coordinated through the coordinated control device \n304\n.', 'For example, coordinated control operations may include the control of downhole pressure during tripping.', 'The downhole pressure may be affected by each of the FC system \n312\n (e.g., pump rate), the MPDC \n313\n (e.g., choke position of the MPDC), and the RC system \n311\n (e.g., tripping speed).', 'Thus, when it is intended to maintain certain downhole pressure during tripping, the coordinated control device \n304\n may be utilized to direct the appropriate control commands to two or more (or each) of the participating subsystems.', 'Control of the subsystems \n311\n-\n316\n of the well construction system \n100\n, \n200\n may be provided via a three-tier control system that includes a first tier of the local controllers \n341\n-\n346\n, a second tier of the coordinated control device \n304\n, and a third tier of the supervisory control system \n307\n.', 'Coordinated control may also be provided by one or more controllers \n341\n-\n346\n of one or more of the subsystems \n311\n-\n316\n without the use of a coordinated control device \n304\n.', 'In such implementations of the control system \n300\n, the wellsite computing resource environment \n305\n may provide control processes directly to these controllers \n341\n-\n346\n for coordinated control.', 'The sensor data \n351\n-\n356\n may be received by the coordinated control device \n304\n and utilized for control of the subsystems \n311\n-\n316\n.', 'The sensor data \n351\n-\n356\n may be encrypted to produce encrypted sensor data \n371\n.', 'For example, the wellsite computing resource environment \n305\n may encrypt sensor data from different types of sensors and systems to produce a set of encrypted sensor data \n371\n.', 'Thus, the encrypted sensor data \n371\n may not be viewable by unauthorized user devices (either offsite user devices \n303\n or onsite user devices \n302\n) if such devices gain access to one or more networks of the well construction system \n100\n, \n200\n.', 'The encrypted sensor data \n371\n may include a timestamp and an aligned drilling parameter (e.g., depth), as described above.', 'The encrypted sensor data \n371\n may be communicated to the remote computing resource environment \n306\n via the network \n308\n and stored as encrypted sensor data \n372\n.', 'The wellsite computing resource environment \n305\n may provide the encrypted sensor data \n371\n, \n372\n available for viewing and processing offsite, such as via the offsite user devices \n303\n.', 'Access to the encrypted sensor data \n371\n, \n372\n may be restricted via access control implemented in the wellsite computing resource environment \n305\n.', 'The encrypted sensor data \n371\n, \n372\n may be provided in real-time to offsite user devices \n303\n such that offsite personnel may view real-time status of the well construction system \n100\n, \n200\n and provide feedback based on the real-time sensor data.', 'For example, different portions of the encrypted sensor data \n371\n, \n372\n may be sent to the offsite user devices \n303\n.', 'The encrypted sensor data \n371\n, \n372\n may be decrypted by the wellsite computing resource environment \n305\n before transmission, and/or decrypted on the offsite user device \n303\n after encrypted sensor data is received.', 'The offsite user device \n303\n may include a thin client (not shown) configured to display data received from the wellsite computing resource environment \n305\n and/or the remote computing resource environment \n306\n.', 'For example, multiple types of thin clients (e.g., devices with display capability and minimal processing capability) may be utilized for certain functions or for viewing various sensor data \n351\n-\n356\n.', 'The wellsite computing resource environment \n305\n may include various computing resources utilized for monitoring and controlling operations, such as one or more computers having a processor and a memory.', 'For example, the coordinated control device \n304\n may include a processing device (e.g., processing device \n1000\n shown in \nFIG. \n23\n) having a processor and memory for processing the sensor data, storing the sensor data, and issuing control commands responsive to the sensor data.', 'As described above, the coordinated control device \n304\n may control various operations of the subsystems \n311\n-\n316\n via analysis of sensor data \n351\n-\n356\n from one or more of the wellsite subsystems \n311\n-\n316\n to facilitate coordinated control between the subsystems \n311\n-\n316\n.', 'The coordinated control device \n304\n may generate control data \n373\n (e.g., signals, commands, coded instructions) to execute control of the subsystems \n311\n-\n316\n.', 'The coordinated control device \n304\n may transmit the control data \n373\n to one or more subsystems \n311\n-\n316\n.', 'For example, control data \n361\n may be sent to the RC system \n311\n, control data \n362\n may be sent to the FC system \n312\n, control data \n363\n may be sent to the MPDC system \n313\n, control data \n364\n may be sent to the CPC system \n314\n, control data \n365\n may be sent to the WC system \n315\n, and control data \n366\n may be sent to the CCTV system \n316\n.', 'The control data \n361\n-\n366\n may include, for example, wellsite operator commands (e.g., turn on or off a pump, switch on or off a valve, update a physical property set-point, etc.).', 'The coordinated control device \n304\n may include a fast control loop that directly obtains sensor data \n351\n-\n356\n and executes, for example, a control algorithm.', 'The coordinated control device \n304\n may include a slow control loop that obtains data via the wellsite computing resource environment \n305\n to generate control commands.', 'The coordinated control device \n304\n may intermediate between the supervisory control system \n307\n and the local controllers \n341\n-\n346\n of the subsystems \n311\n-\n316\n, such as may permit the supervisory control system \n307\n to control the subsystems \n311\n-\n316\n.', 'The supervisory control system \n307\n may include, for example, devices for entering control commands to perform operations of the subsystems \n311\n-\n316\n.', 'The coordinated control device \n304\n may receive commands from the supervisory control system \n307\n, process such commands according to a rule (e.g., an algorithm based upon the laws of physics for drilling operations), and provide control data to one or more subsystems \n311\n-\n316\n.', 'The supervisory control system \n307\n may be provided by the wellsite operator \n195\n and/or process monitoring and control program.', 'In such implementations, the coordinated control device \n304\n may coordinate control between discrete supervisory control systems and the subsystems \n311\n-\n316\n while utilizing control data \n361\n-\n366\n that may be generated based on the sensor data \n351\n-\n356\n received from the subsystems \n311\n-\n316\n and analyzed via the wellsite computing resource environment \n305\n.', 'The coordinated control device \n304\n may receive the control data \n361\n-\n366\n and then dispatch control data \n361\n, including interlock commands, to each subsystem \n311\n-\n316\n.', 'The coordinated control device \n304\n may also or instead just monitor the control data \n361\n-\n366\n being dispatched to each subsystem \n311\n-\n316\n and then initiate the machine interlock commands to the relevant local controller \n341\n-\n346\n.', 'The coordinated control device \n304\n may run with different levels of autonomy.', 'For example, the coordinated control device \n304\n may operate in an advice mode to inform the wellsite operators \n195\n to perform a specific task or take specific corrective action based on sensor data \n351\n-\n356\n received from the various subsystems \n311\n-\n316\n.', 'While in the advice mode, the coordinated control device \n304\n may, for example, advise or instruct the wellsite operator \n195\n to perform a standard work sequence when gas is detected on the rig floor \n114\n, such as to close the annular BOP \n132\n.', 'Furthermore, if the wellbore \n102\n is gaining or losing drilling fluid \n140\n, the coordinated control device \n304\n may, for example, advise or instruct the wellsite operator \n195\n to modify the density of the drilling fluid \n140\n, modify the pumping rate of the drilling fluid \n140\n, and/or modify the pressure of the drilling fluid within the wellbore \n102\n.', 'The coordinated control device \n304\n may also operate in a system/equipment interlock mode, whereby certain operations or operational sequences are prevented based on the received sensor data \n351\n-\n356\n.', 'While operating in the interlock mode, the coordinated control device \n304\n may manage interlock operations among the various equipment of the subsystems \n311\n-\n316\n.', 'For example, if a pipe ram of the BOP stack \n130\n is activated, the coordinated control device \n304\n may issue an interlock command to the RC system controller \n341\n to stop the DW \n119\n from moving the drill string \n120\n.', 'However, if a shear ram of the BOP stack \n130\n is activated, the coordinated control device \n304\n may issue an interlock command to the controller \n341\n to operate the DW \n119\n to adjust the position of the drill string \n120\n within the BOP stack \n130\n before activating the shear ram, so that the shear ram does not align with a shoulder of the tubulars forming the drill string \n120\n.', 'The coordinated control device \n304\n may also operate in an automated sequence mode, whereby certain operations or operational sequences are automatically performed based on the received sensor data \n351\n-\n356\n.', 'For example, the coordinated control device \n304\n may automatically activate an alarm and/or stop or reduce operating speed of the pipe handling equipment when a wellsite operator \n195\n is detected close to a moving RN \n151\n, the TDA \n202\n, the LSA \n228\n, the LTC \n244\n, or the catwalk \n131\n.', 'As another example, if the wellbore pressure increases rapidly, the coordinated control device \n304\n may automatically close the annular BOP \n132\n, close one or more rams of the BOP stack \n130\n, and/or adjust the choke manifold \n162\n.', 'The wellsite computing resource environment \n305\n may comprise or execute a monitoring process \n374\n (e.g., an event detection process) that may utilize the sensor data \n351\n-\n356\n to determine information about status of the well construction system \n100\n, \n200\n and automatically initiate an operational action, a process, and/or a sequence of one or more of the subsystems \n311\n-\n316\n.', 'The monitoring process \n374\n may initiate the operational action to be caused by the coordinated control device \n304\n.', 'Depending on the type and range of the sensor data \n351\n-\n356\n received, the operational actions may be executed in the advice mode, the interlock mode, or the automated sequence mode.', 'For example, the monitoring process \n374\n may determine a drilling state, equipment health, system health, a maintenance schedule, or combination thereof, and initiate an advice to be generated.', 'The monitoring process \n374\n may also detect abnormal drilling events, such as a wellbore fluid loss and gain, a wellbore washout, a fluid quality issue, or an equipment event based on job design and execution parameters (e.g., wellbore, drilling fluid, and drill string parameters), current drilling state, and real-time sensor information from the surface equipment \n110\n (e.g., presence of hazardous gas at the rig floor, presence of wellsite operators in close proximity to moving pipe handling equipment, etc.) and the BHA \n124\n, initiating an operational action in the automated mode.', 'The monitoring process \n374\n may be connected to the real-time communication network \n309\n.', 'The coordinated control device \n304\n may initiate a counteractive measure (e.g., a predetermined action, process, or operation) based on the events detected by the monitoring process \n374\n.', 'The term “event” as used herein may include, but not be limited to, an operational and/or safety related event described herein and/or another operational and safety related event that can take place at a well construction system \n100\n, \n200\n.', 'The events described herein may be detected by the monitoring process \n374\n based on the sensor data \n351\n-\n356\n (e.g., sensor signals or information) received and analyzed by the monitoring process \n374\n.', 'The wellsite computing resource environment \n305\n may also comprise or execute a control process \n375\n that may utilize the sensor data \n351\n-\n356\n to optimize drilling operations, such as the control of drilling equipment to improve drilling efficiency, equipment reliability, and the like.', 'For example, the acquired sensor data \n352\n may be utilized to derive a noise cancellation scheme to improve electromagnetic and/or mud-pulse telemetry signal processing.', 'The remote computing resource environment \n306\n may comprise or execute a control process \n376\n substantially similar to the control process \n375\n that may be provided to the wellsite computing resource environment \n305\n.', 'The monitoring and control processes \n374\n, \n375\n, \n376\n may be implemented via, for example, a control algorithm, a computer program, firmware, or other hardware and/or software.', 'The wellsite computing resource environment \n305\n may include various computing resources, such as a single computer or multiple computers.', 'The wellsite computing resource environment \n305\n may further include a virtual computer system and a virtual database or other virtual structure for collected data, such as may include one or more resource interfaces (e.g., web interfaces) that facilitate the submission of application programming interface (API) calls to the various resources through a request.', 'In addition, each of the resources may include one or more resource interfaces that facilitate the resources accessing each other (e.g., to facilitate a virtual computer system of the computing resource environment to store data in or retrieve data from the database or other structure for collected data).', 'The virtual computer system may include a collection of computing resources configured to instantiate virtual machine instances.', 'A wellsite operator \n195\n may interface with the virtual computer system via the offsite user device \n303\n or the onsite user device \n302\n.', 'Other computer systems or computer system services may be utilized in the wellsite computing resource environment \n305\n, such as a computer system or computer system service that provides computing resources on dedicated or shared computers/servers and/or other physical devices.', 'The wellsite computing resource environment \n305\n may include a single server (in a discrete hardware component or as a virtual server) or multiple servers (e.g., web servers, application servers, or other servers).', 'The servers may be, for example, computers arranged in physical and/or virtual configuration.', 'The wellsite computing resource environment \n305\n may also include a database that may be or comprise a collection of computing resources that run one or more data collections.', 'Such data collections may be operated and managed by utilizing API calls.', 'The data collections, such as the sensor data \n351\n-\n356\n, may be made available to other resources in the wellsite computing resource environment \n305\n, or to user devices (e.g., onsite user device \n302\n and/or offsite user device \n303\n) accessing the wellsite computing resource environment \n305\n.', 'The remote computing resource environment \n306\n may include computing resources similar to those described above, such as a single computer or multiple computers (in discrete hardware components or virtual computer systems).', 'FIGS.', '5\n and \n6\n are perspective and sectional views of at least a portion of an example implementation of a control center \n400\n according to one or more aspects of the present disclosure.', 'The control center \n400\n may be or form at least a portion of the control center \n190\n shown in \nFIG.', '1\n.', 'The following description refers to \nFIGS.', '1\n-\n6\n, collectively.', 'The control center \n400\n comprises a facility \n405\n (e.g., a room, a cabin, a trailer, etc.) containing various control devices for monitoring and controlling the subsystems \n311\n-\n316\n and other portions of the well construction system \n100\n, \n200\n.', 'The facility \n405\n may comprise a front side \n401\n and a rear side \n403\n.', 'The front side \n401\n may be directed toward or located closest to the drill string \n120\n being constructed by the well construction system \n100\n, \n200\n.', 'The rear side \n403\n may be directed away from the drill string \n120\n.', 'The facility \n405\n may comprise a floor \n402\n, a front wall \n404\n, a left wall \n406\n, a right wall \n408\n, a rear wall \n410\n, and a roof \n412\n.', 'The facility \n405\n may also have a side door \n414\n, a rear door \n416\n, and a plurality of windows \n421\n-\n428\n in one or more of the walls \n404\n, \n406\n, \n408\n, \n410\n and/or the roof \n412\n.', 'Each of the windows \n421\n-\n428\n may be surrounded by structural framing \n430\n connected with the walls and supporting window safety guards \n432\n (e.g., bars, grills) in front of or along the windows \n421\n-\n428\n.', 'The facility \n405\n may have an observation area \n440\n at the front side \n401\n of the facility \n405\n from which a wellsite operator \n195\n may have a direct view of the drill string \n120\n, the rig floor \n114\n, and/or other portions of the well construction system \n100\n, \n200\n.', "The observation area \n440\n may be surrounded or defined by windows \n423\n-\n428\n on several sides to increase the wellsite operator's \n195\n horizontal and vertical angle of view of the well constriction system \n100\n.", 'A portion \n442\n of the observation area \n440\n (e.g., windows \n423\n-\n427\n) may protrude or extend out past other portions of the facility \n405\n (e.g., front wall \n404\n) to facilitate the view of the well construction system \n100\n, \n200\n by the wellsite operators \n195\n.', 'The observation area \n440\n may be located on a side of the facility \n405\n.', 'The observation area \n440\n may be surrounded by or at least partially defined by a front window \n424\n permitting the wellsite operator \n195\n to look forward, two side windows \n423\n, \n425\n permitting the wellsite operator \n195\n to look sideways (i.e., left and right), a lower window \n426\n permitting the wellsite operator \n195\n to look downwards, and one or more upper windows \n427\n, \n428\n permitting the wellsite operator \n195\n to look upwards.', 'The lower window \n426\n and/or at least one upper window \n427\n may extend diagonally with respect to the front window \n424\n.', 'The control center \n400\n may comprise one or more wellsite operator control workstations within the facility \n405\n.', 'The workstations may be utilized by the wellsite operators \n195\n to monitor and control the subsystems \n311\n-\n316\n and other portions of the well construction system \n100\n, \n200\n.', 'For example, the observation area \n440\n may contain a first control workstation \n450\n located adjacent the windows \n423\n, \n424\n, \n425\n, \n426\n, \n428\n and at least partially within the extended portion \n442\n of the observation area \n440\n, such as may permit the wellsite operator \n195\n utilizing the control workstation \n450\n to have an unobstructed view of the drill string \n120\n, the rig floor \n114\n, and/or other portions of the well construction system \n100\n, \n200\n.', 'The observation area \n440\n may also contain a second control workstation \n452\n located adjacent (e.g., behind) the first control workstation \n450\n and adjacent the window \n425\n, but perhaps not within the extended portion \n442\n of the observation area \n440\n.', 'The control workstation \n452\n may be elevated at least partially above the control workstation \n450\n to reduce the obstruction of view caused by the control workstation \n450\n and, thus, permit the wellsite operator \n195\n utilizing the control workstation \n452\n to view the drill string \n120\n, the rig floor \n114\n, and/or other portions of the well construction system \n100\n, \n200\n over the control workstation \n450\n via the front window \n424\n.', 'The control center \n400\n may also comprise a third control workstation \n454\n located adjacent the control workstations \n450\n, \n452\n and adjacent the windows \n421\n, \n422\n, but not within the observation area \n440\n.', 'The control center \n400\n may further comprise a processing device \n456\n (e.g., a controller, a computer, a server, etc.)', 'operable to provide control to one or more portions of the well construction system \n100\n, \n200\n and/or operable to monitor operations of one or more portions of the well construction system \n100\n, \n200\n.', 'For example, the processing device \n456\n may be communicatively connected with the various surface and downhole equipment described herein, and may be operable to receive signals from and transmit signals to such equipment to perform various operations described herein or otherwise within the scope of the present disclosure.', 'The processing device \n456\n may store executable programs, instructions, and/or operational parameters or set-points, including for implementing one or more aspects of the operations described herein.', 'The processing device \n456\n may be communicatively connected with the control workstations \n450\n, \n452\n, \n454\n.', 'Although the processing device \n456\n is shown located within the facility \n405\n, the processing device \n456\n may be located outside of the facility \n405\n.', 'Furthermore, although the processing device \n456\n is shown as a single device that is separate and distinct from the control workstations \n450\n, \n452\n, \n454\n, one or more of the control workstations \n450\n, \n452\n, \n454\n may comprise a corresponding processing device \n456\n disposed in association with or forming at least a portion of such corresponding processing device \n456\n.', 'The control workstations \n450\n, \n452\n, \n454\n may be operable to enter or otherwise communicate commands to the processing device \n456\n by the wellsite operator \n195\n and to display or otherwise communicate information from the processing device \n456\n to the wellsite operator \n195\n.', 'One or more of the control workstations \n450\n, \n452\n, \n454\n may comprise an operator chair \n460\n and an HMI system comprising one or more input devices \n462\n (e.g., a keyboard, a mouse, a joystick, a touchscreen, a microphone, etc.) and one or more output devices \n464\n (e.g., a video monitor, a printer, audio speakers, a touchscreen, etc.).', 'The input and output devices \n462\n, \n464\n may be disposed in association with and/or integrated with the operator chair \n460\n to permit the wellsite operator \n195\n to enter commands or other information to the processing device \n456\n, and to view, hear, and/or otherwise receive information from the processing device \n456\n and other portions of the well construction system \n100\n, \n200\n.', 'One or more of the control workstations \n450\n, \n452\n, \n454\n may be or form at least a portion of the control workstation \n197\n shown in \nFIG.', '1\n, and the processing device \n456\n may be or form at least a portion of the processing device \n192\n shown in \nFIG.', '1\n.', 'The control center \n400\n may further contain a BOP control station \n470\n (e.g., control panel) of the WC system \n315\n operable to monitor and control one or more portions of the WC system \n315\n.', 'For example, the BOP control station \n470\n may be communicatively connected with the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n, and may be operable to monitor and control operations of the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n.', 'The BOP control station \n470\n may be operable communicate to the BOP control unit \n137\n control commands entered by the wellsite operator \n195\n for controlling the BOP equipment \n130\n, \n132\n and to display or otherwise communicate information indicative of operational status of the BOP equipment \n130\n, \n132\n and the BOP control unit \n137\n to the wellsite operator \n195\n.', 'The BOP control station \n470\n may comprise a processing device (e.g., processing device \n1000\n shown in \nFIG.', '23\n) operable to store executable programs, instructions, and/or operational parameters or set-points, including for implementing one or more BOP operations described herein.', 'The BOP control station \n470\n may further comprise an HMI system comprising one or more input devices \n472\n (e.g., buttons, keys, a touchscreen, etc.) and one or more output devices \n474\n (e.g., a video monitor, gauges, audio speakers, a touchscreen, etc.).', 'The input and output devices \n472\n, \n474\n may be disposed in association with and/or integrated with a housing or enclosure of the BOP control station \n470\n to permit the wellsite operator \n195\n to enter commands or other information to the BOP control station \n470\n to control the BOP equipment \n130\n, \n132\n and receive information from the BOP control station \n470\n to monitor operational status of the BOP equipment \n130\n, \n132\n.', 'The BOP control unit \n470\n may be communicatively connected with one or more of the control workstations \n450\n, \n452\n, \n454\n, such as may permit monitoring and control of one or more portions of the WC system \n315\n via the control workstations \n450\n, \n452\n, \n454\n.', 'For example, one or more of the control workstations \n450\n, \n452\n, \n454\n or the processing device \n456\n may be communicatively connected directly with the processing device of the BOP control station \n470\n or indirectly, such as via the input and output devices \n472\n, \n474\n of the BOP control station \n470\n.', 'Such connection may permit the control workstations \n450\n, \n452\n, \n454\n to receive information indicative of operational status of the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n via the BOP control station \n470\n.', 'Such connection may further permit the control workstations \n450\n, \n452\n, \n454\n to transmit control commands to the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n via the BOP control station \n470\n.', 'Such connection may also or instead facilitate control of the BOP control station \n470\n via the control workstations \n450\n, \n452\n, \n454\n, such as may cause the BOP control station \n470\n to control the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n as directed by or from the control workstations \n450\n, \n452\n, \n454\n.', 'The control workstations \n450\n, \n452\n, \n454\n may be operable to display the information indicative of operational status of the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n to the wellsite operator \n195\n via the output devices \n464\n to permit the wellsite operator to monitor the operational status of the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n while sitting in the corresponding operator chair \n460\n.', 'The control workstations \n450\n, \n452\n, \n454\n may be further operable to receive the control commands from the wellsite operator \n195\n via the input devices \n462\n while sitting in the corresponding operator chair \n460\n for transmission to the BOP control station \n470\n to control the BOP control unit \n137\n and the BOP equipment \n130\n, \n132\n.\n \nFIG.', '7\n is a top view of a portion of an example implementation of a wellsite operator control workstation \n500\n communicatively connected with and operable to control the well construction system \n100\n, \n200\n according to one or more aspects of the present disclosure.', 'The control workstation \n500\n depicted in \nFIG.', '7\n is an example implementation of the control workstations \n450\n, \n452\n, \n454\n described above.', 'The control workstation \n500\n may facilitate receiving and displaying various information, such as sensor signals or information (e.g., sensor data \n351\n-\n356\n), control commands (e.g., control data \n361\n-\n366\n), processes taking place, events being detected, and operational status of various equipment of the subsystems \n311\n-\n316\n of the well construction system \n100\n, \n200\n.', 'The following description refers to \nFIGS.', '1\n-\n7\n, collectively.', "The control workstation \n500\n comprises an operator chair \n502\n (e.g., driller's chair) and an HMI system comprising a plurality of input and output devices integrated with, supported by, or otherwise disposed in association with the operator chair \n502\n.", 'The input devices permit the wellsite operator \n195\n to enter commands or other information to control the wellsite equipment of the well construction system \n100\n, \n200\n, and the output devices permit the wellsite operator \n195\n to receive sensor signals and other information indicative of operational status of the wellsite equipment.', 'The operator chair \n502\n may include a seat \n504\n, a left armrest \n506\n, and a right armrest \n508\n.', 'The input devices of the control workstation \n500\n may include a plurality of physical controls, such as a left joystick \n510\n, a right joystick \n512\n, and/or other physical controls \n514\n, \n515\n, \n516\n, \n518\n, such as buttons, keys, switches, knobs, dials, slider bars, a mouse, a keyboard, and a microphone.', 'One or more of the joysticks \n510\n, \n512\n and/or the physical controls \n514\n, \n515\n, \n516\n may be integrated into or otherwise supported by the corresponding armrests \n506\n, \n508\n of the operator chair \n502\n to permit the wellsite operator \n195\n to operate these input devices from the operator chair \n502\n.', 'Furthermore, one or more of the physical controls \n518\n may be integrated into the corresponding joysticks \n510\n, \n512\n to permit the wellsite operator \n195\n to operate these physical controls \n518\n while operating the joysticks \n510\n, \n512\n.', 'The physical controls may comprise emergency stop (E-stop) buttons \n515\n, which may be electrically connected to E-stop relays of one or more pieces of wellsite equipment (e.g., the RN \n151\n, the TDA \n202\n, the DW \n119\n, the LSA \n228\n, the LTC \n244\n, the SGA \n262\n, the top drive \n116\n, etc.), such that the wellsite operator \n195\n can shut down the wellsite equipment during emergencies and other situations.', 'The output devices of the control workstation \n500\n may include one or more video output devices \n526\n (e.g., video monitors), printers, speakers, and other output devices disposed in association with the operator chair \n502\n and operable to display to the wellsite operator \n195\n sensor signals and other information indicative of operational status of the well construction system \n100\n, \n200\n.', 'The video output devices \n526\n may be implemented as one or more LCD displays, LED displays, plasma displays, cathode ray tube displays, and/or other types of displays.', 'The video output devices \n526\n may be disposed in front of or otherwise adjacent the operator chair \n502\n.', 'The video output devices \n526\n may include a plurality of video output devices \n532\n, \n534\n, \n536\n, each dedicated to displaying predetermined information in a predetermined (e.g., programmed) manner.', 'Although the video output devices \n526\n are shown comprising three video output devices \n532\n, \n534\n, \n536\n, the video output devices \n526\n may be or comprise one, two, four, or more video output devices.', 'The video output devices \n532\n, \n534\n, \n536\n may each display in a predetermined manner selected sensor signals or information indicative of operational status of a selected portion of the well construction system \n100\n, \n200\n.', 'For example, the video output devices \n534\n, \n536\n may display sensor signals or information \n540\n (e.g., sensor data \n351\n-\n356\n) generated by the various sensors (e.g., sensors \n321\n-\n326\n) of the well construction system \n100\n, \n200\n to permit the wellsite operator \n195\n to monitor operational status of the subsystems \n311\n-\n316\n.', 'The information \n540\n may be displayed in the form of virtual or computer-generated lists, menus, tables, graphs, bars, gauges, lights, and schematics, among other examples.', 'One or more of the video output devices \n526\n may be configured to display video signals (i.e., video feeds) generated by one or more of the video cameras \n198\n.', 'For example, the video output device \n532\n may be dedicated for displaying the video signals generated by one or more of the video cameras \n198\n.', 'When displaying the video signals from multiple video cameras \n198\n, the video output device \n532\n may display multiple video windows, each displaying a corresponding video signal.', 'Furthermore, one or more of the other video output devices \n534\n, \n536\n may also display the video signals from one or more of the video cameras \n198\n.', 'For example, one or both of the video output devices \n534\n, \n536\n may display one or more picture-in-picture (PIP) video windows \n544\n, each displaying a video signal from a corresponding one of the video cameras \n198\n.', 'The PIP video windows \n544\n may be embedded or inset along or adjacent the sensor information \n540\n.', 'Sourcing (i.e., selection) of the video cameras \n198\n whose video signals are to be displayed on the video output devices \n526\n may be selected manually by the wellsite operator \n195\n or automated via the control system \n300\n, such as based on operational events (e.g., drilling events, well construction operation stage, etc.)', 'at the well construction system \n100\n, \n200\n, such that video signals relevant to an event currently taking place are displayed.', 'The control workstation \n500\n may further comprise combination devices operable as both input and output devices to display information to the wellsite operator \n195\n and receive commands or information from the wellsite operator \n195\n.', 'Such devices may be or comprise touchscreens \n522\n, \n524\n operable to display a plurality of software (e.g., virtual, computer generated) buttons, switches, knobs, dials, icons, and/or other software controls \n530\n permitting the wellsite operator \n195\n to operate (e.g., click, select, move) the software controls \n530\n via finger contact with the touchscreens \n522\n, \n524\n to control the various wellsite equipment of the subsystems \n311\n-\n316\n.', 'The software controls \n530\n may also be operated by the physical controls \n514\n, \n516\n, the joysticks \n510\n, \n512\n, or other input devices of the control workstation \n500\n.', 'The software controls \n530\n and/or other features displayed on the touchscreens \n522\n, \n524\n may also display sensor signals or information (e.g., sensor data \n351\n-\n356\n), operational settings, set-points, and/or status of selected wellsite equipment for viewing by the wellsite operator \n195\n.', 'For example, the software controls \n530\n may change color, move in position or direction, and/or display the sensor information, set-points, and/or operational values (e.g., temperature, pressure, position).', 'The touchscreens \n522\n, \n524\n may be disposed on, supported by, or integrated into the armrests \n506\n, \n508\n or other parts of the operator chair \n502\n to permit the wellsite operator \n195\n to operate the software controls \n530\n displayed on the touchscreens \n522\n, \n524\n from the operator chair \n502\n.', 'Each video output device \n526\n and touchscreen \n522\n, \n524\n may display (i.e., generate) a plurality of display screens (i.e., an integrated display system), each displaying to the wellsite operator \n195\n selected sensor signals or information \n540\n indicative of operational status of the well construction system \n100\n, \n200\n and software controls \n530\n for controlling selected portions of the well construction system, respectively.', 'Each display screen may integrate the software controls \n530\n and/or sensor information \n540\n from one or more pieces of wellsite equipment (e.g., subsystems \n311\n-\n316\n) with information generated by the control system \n300\n (e.g., the monitoring process \n374\n, the control process \n375\n, and the control data \n361\n-\n366\n, \n373\n) for viewing and/or operating by the wellsite operator \n195\n.', 'The display screens may be shown or displayed alternately on one or more of the video output devices \n526\n and/or the touchscreens \n522\n, \n524\n or simultaneously on one or more of these devices.', 'The display screens intended to be displayed on the video output devices \n526\n and/or the touchscreens \n522\n, \n524\n may be selected by the wellsite operator \n195\n via the physical controls \n514\n, \n516\n, \n518\n and/or software controls \n530\n.', 'The display screens intended to be displayed on the video output devices \n526\n and/or the touchscreens \n522\n, \n524\n may also or instead be selected automatically by the control system \n300\n based on operational events detected (e.g., equipment failures, hazardous drilling conditions) or planned (e.g., changing phases or stages of the well construction operations) at the well construction system \n100\n, \n200\n, such that information relevant to the event currently taking place is displayed.', 'Each display screen generated by the touchscreens \n522\n, \n524\n may display software controls \n530\n operable by the wellsite operator \n195\n to control the wellsite equipment associated with the software controls \n530\n, and each display screen generated by the video output devices \n526\n may display information \n540\n indicative of operational status of the wellsite equipment associated with the information \n540\n.', 'Accordingly, the display screens displayed on the touchscreens \n522\n, \n524\n may be referred to hereinafter as control screens, and the display screens displayed on the video output devices \n526\n may be referred to hereinafter as status screens.', 'The touchscreens \n522\n, \n524\n may be operable to display one or more control screens (e.g., configuration screens), which may be utilized to operate, set, adjust, configure, or otherwise control the subsystems \n311\n-\n316\n or other wellsite equipment.', 'Each control screen may display one or more software controls \n530\n, such as may permit the wellsite operator \n195\n to operate, set, adjust, configure, or otherwise control the subsystems \n311\n-\n316\n or other wellsite equipment via finger contact with the touchscreens \n522\n, \n524\n from the operator chair \n502\n.', 'FIGS.', '8\n-\n10\n are example implementations of software controls \n552\n, \n554\n, \n556\n that may be displayed on the touchscreens \n522\n, \n524\n and operated by the wellsite operator \n195\n to operate, set, adjust, configure, or otherwise control the subsystems \n311\n-\n316\n or other wellsite equipment of the well construction system \n100\n, \n200\n.', 'The following description refers to \nFIGS.', '7\n-\n10\n, collectively.', 'The software controls \n552\n, \n554\n, \n556\n may be pressed, clicked, selected, moved, or otherwise operated via the physical controls \n514\n, \n516\n and/or via finger contact by the wellsite operator \n195\n to increase, decrease, change, or otherwise enter operational parameters, set-points, and/or instructions for controlling one or more pieces of wellsite equipment of the well construction system \n100\n, \n200\n.', 'The software controls \n552\n, \n554\n, \n556\n may also display the entered and/or current operational parameters on or in association with the software controls \n552\n, \n554\n, \n556\n for viewing by the wellsite operator \n195\n.', 'The operational parameters, set-points, and/or instructions associated with the software controls \n552\n, \n554\n, \n556\n may include equipment operational status (e.g., on or off, up or down, set or release, position, speed, temperature, etc.), drilling parameters (e.g., depth, hook load, torque, etc.), auxiliary parameters (e.g., vibration data of a pump), and fluid parameters (e.g., flow rate, pressure, temperature, etc.), among other examples.', 'The software controls \n552\n may be or comprise software buttons, which may be operated to increase, decrease, change, or otherwise enter different operational parameters, set-points, and/or instructions for controlling one or more portions of the well construction system \n100\n, \n200\n associated with the software controls \n552\n.', 'The software controls \n554\n may be or comprise a list or menu of items (e.g., equipment, processes, operational stages, equipment subsystems, etc.)', 'related to one or more aspects of the well construction system \n100\n, \n200\n, which may be operated to select one or more items on the list.', 'The selected items may be highlighted, differently colored, or otherwise indicated, such as via a checkmark, a circle, a dot, or other characters/icons appearing in association with the selected items.', 'The software controls \n556\n may be or comprise a combination of different software controls, which may be operated to increase, decrease, change, or otherwise enter different operational parameters, set-points, and/or instructions for controlling one or more portions of the well construction system \n100\n, \n200\n associated with the software controls \n556\n, such as a pump of the well construction system \n100\n, \n200\n.', 'The software controls \n556\n may include a slider \n553\n, which may be moved or otherwise operated along a graduated bar to increase, decrease, or otherwise change pump speed or another operational parameter associated with the slider bar \n553\n.', 'The entered pump speed may be shown in a display window \n555\n.', 'The software controls \n556\n may also include software buttons \n557\n, such as may be operated to start, pause, and stop operation of the pump or another portion of the well construction system \n100\n, \n200\n associated with the software buttons \n557\n.\n \nFIGS.', '11\n-\n15\n are example implementations of control screens \n601\n-\n605\n (e.g., configuration screens or menus) that may be displayed on the touchscreens \n522\n, \n524\n according to one or more aspects of the present disclosure.', 'Each control screen \n601\n-\n605\n may be operated via finger contact with the touchscreens \n522\n, \n524\n (and/or other input means) by the wellsite operator \n195\n to operate, set, adjust, configure, or otherwise control the subsystems \n311\n-\n316\n or other wellsite equipment of the well construction system \n100\n, \n200\n associated with or displayed on the control screen \n601\n-\n605\n.', 'The following description refers to \nFIGS.', '11\n-\n15\n, collectively.', 'Each control screen, including the control screens \n601\n-\n605\n, may display a selection bar \n610\n for switching between or selecting which control screen is to be displayed on the corresponding touchscreen \n522\n, \n524\n and/or which status screen is to be displayed on each of the video output devices \n526\n.', 'Each control screen may also comprise an equipment control area \n618\n for displaying software controls for controlling well construction operations and/or wellsite equipment associated with the control screen.', 'The selection bar \n610\n may comprise an equipment menu button \n612\n, which when operated by the wellsite operator \n195\n, may cause a control screen selection menu \n614\n (e.g., a dropdown or pop-up menu) to appear.', 'The selection menu \n614\n may contain a plurality of buttons \n616\n, each associated with and listing a corresponding well construction operation or wellsite equipment to be controlled.', 'The wellsite operator \n195\n may operate (e.g., click on, touch, and/or otherwise select) one of the buttons \n616\n to select a well construction operation or wellsite equipment, thereby causing a corresponding control screen for controlling the associated well construction operation or wellsite equipment to be displayed.', 'After one of the buttons \n616\n is selected, a plurality of software controls \n630\n (shown in \nFIGS.', '12\n-\n15\n) may appear in the equipment control area \n618\n, and the well construction operation or wellsite equipment that is selected may be listed or otherwise identified in a control screen identification area \n620\n.', 'The software controls \n630\n or other information displayed in the equipment control area \n618\n will change when the wellsite operator \n195\n switches between the various control screens by selecting different buttons \n616\n.', 'As shown in \nFIG. \n11\n, example control screens that may be selected for display on the touchscreens \n522\n, \n524\n may include a tripping control screen displaying software controls for controlling automatic operation of wellsite equipment collectively operable to perform tripping operations, a drilling control screen displaying software controls for controlling automatic operation of wellsite equipment collectively operable to perform drilling operations, a drill pipe handling control screen displaying software controls for controlling automatic operation of wellsite equipment collectively operable to move drill pipes at the wellsite, and a plurality of individual equipment control screens each displaying software controls for automatically and/or manually controlling operation of individual wellsite equipment, such as the catwalk \n131\n, the TDA \n202\n, the setback \n164\n, the FIB \n166\n, the TBR \n254\n, the SGA \n262\n, the LTC \n244\n, the ITC \n236\n, the UTC \n242\n, the LSA \n228\n, the setback \n164\n, the catwalk \n131\n, the top drive \n116\n, the RN \n151\n, the choke \n162\n, and fluid reconditioning equipment \n170\n, among other examples.', 'Although not described herein, the control screens within the scope of the present disclosure may include control screens displaying software controls of other individual wellsite equipment and/or wellsite equipment subsystems (e.g., subsystems \n311\n-\n316\n).', 'Each control screen, including the control screens \n601\n-\n605\n, may also be utilized to switch between or select which status screen is to be displayed on which video output device \n532\n, \n534\n, \n536\n.', 'For example, the selection bar \n610\n may comprise status screen selection buttons \n622\n, each associated with a corresponding one of the video output devices \n532\n, \n534\n, \n536\n and, when operated by the wellsite operator \n195\n, operable to cause a corresponding status screen selection menu \n624\n (e.g., a dropdown or pop-up menu) to appear.', 'Each selection menu \n624\n may contain a plurality of buttons \n626\n, each associated with and listing a corresponding well construction operation, wellsite equipment, and/or subsystem (e.g., subsystem \n311\n-\n316\n) of the well construction system \n100\n, \n200\n to be displayed.', 'The wellsite operator \n195\n may operate (e.g., click on, touch, and/or otherwise select) one of the buttons \n622\n and buttons \n626\n to select one of the video output devices \n532\n, \n534\n, \n536\n and a well construction operation, wellsite equipment, or subsystem, thereby causing a corresponding status screen displaying sensor signals or information \n540\n indicative of operational status of the selected well construction operation, wellsite equipment, or subsystem to be displayed on the selected video output device \n532\n, \n534\n, \n536\n.', 'The status screens that may be displayed on the video output devices \n532\n, \n534\n, \n536\n are described in more detail below.', 'When operated, the software controls \n630\n may activate, deactivate, start, stop, configure, or otherwise control operation of the wellsite equipment associated with the software controls \n630\n.', 'The software controls \n630\n may initiate automatic operation of the wellsite equipment associated with the control screen, such as by operating an “AUTO” software button.', 'The software controls \n630\n may also cause manual control of the wellsite equipment associated with the control screen to be given to the wellsite operator \n195\n, such as by operating a “MANUAL” software button.', 'The software controls \n630\n may be grouped by related equipment and/or related operations, which may be identified by text \n632\n associated with each group of software controls \n630\n.', 'Furthermore, each software control \n630\n may list or otherwise identify the piece of equipment or operation that is controlled or otherwise associated with the software control \n630\n.', 'One or more of the software controls \n630\n may list or otherwise indicate the operational status (i.e., feedback) of the wellsite equipment or operation associated with the software control \n630\n.', 'For example, one or more of the software controls \n630\n may change color, text, shape, or otherwise change to indicate that a piece of wellsite equipment associated with the software control \n630\n is activated, deactivated, or in a predetermined position, or that an operation associated with the software control \n630\n has commenced, stopped, or is in a particular stage.\n \nFIG.', '12\n is an example implementation of a “DRILLING” control screen \n602\n that may be utilized to control automated, semi-automated, and/or manual operation of wellsite equipment associated with and/or collectively operable to perform drilling operations according to one or more aspects of the present disclosure.', 'The control screen \n602\n may display in the equipment control area \n618\n various software controls \n630\n for controlling various wellsite equipment and/or operational parameters of the drilling operations performed by well construction system \n100\n, \n200\n.', 'For example, when operated, the software controls \n630\n may activate, deactivate, start, stop, configure, or otherwise control automated, semi-automated, and/or manual operation of the wellsite equipment associated with the drilling operations.', 'Such wellsite equipment may include the top drive \n116\n, the DW \n119\n, the pump \n144\n, and the BOP equipment \n130\n, \n132\n, among other examples.\n \nFIG.', '13\n is an example implementation of an “PIPE HANDLING” control screen \n603\n that may be utilized to control automated, semi-automated, and/or manual operation of wellsite equipment associated with and/or collectively operable to perform drill pipe handling (e.g., moving, storing) operations according to one or more aspects of the present disclosure.', 'The control screen \n603\n may display in the equipment control area \n618\n various software controls \n630\n for controlling various wellsite equipment and/or operational parameters of the drill pipe handling operations performed by well construction system \n100\n, \n200\n.', 'For example, when operated, the software controls \n630\n may activate, deactivate, start, stop, configure, or otherwise control automated, semi-automated, and/or manual operation of the wellsite equipment associated with the drill pipe handling operations.', 'Such wellsite equipment may include the catwalk \n131\n, the TDA \n202\n, the setback \n164\n, the FIB \n166\n, the TBR \n254\n, the SGA \n262\n, the LTC \n244\n, the ITC \n236\n, the UTC \n242\n, the LSA \n228\n, the RN \n151\n, and the reciprocating slips \n161\n, among other examples.\n \nFIG.', '14\n is an example implementation of a “TOP DRIVE” control screen \n604\n that may be utilized to control automated, semi-automated, and/or manual operation of the top drive \n116\n according to one or more aspects of the present disclosure.', 'The control screen \n604\n may display in the equipment control area \n618\n various software controls \n630\n for configuring and/or controlling automated, semi-automated, and/or manual operations performed by the top drive \n116\n and/or operational parameters associated with the top drive \n116\n.', 'For example, when operated, the software controls \n630\n may activate, deactivate, start, stop, configure, or otherwise control operation of one or more portions of the top drive \n116\n, such as the drive shaft \n125\n, the grabber, the swivel, the tubular handling assembly \n127\n, and other portions of the top drive \n116\n.', 'The software controls \n630\n may also be utilized to control other wellsite equipment that may be directly or closely associated with or operate in close association with the top drive \n116\n, such as the RN \n151\n.\n \nFIG.', '15\n is an example implementation of a “ROUGHNECK 1” control screen \n605\n that may be utilized to control automated, semi-automated, and/or manual operation of one of the RNs \n151\n according to one or more aspects of the present disclosure.', 'The control screen \n605\n may display in the equipment control area \n618\n various software controls \n630\n for configuring or controlling automated, semi-automated, and/or manual operations performed by the RN \n151\n and/or operational parameters associated with the RN \n151\n.', 'For example, when operated, the software controls \n630\n may activate, deactivate, start, stop, configure, or otherwise control operation of one or more portions of the RN \n151\n, such as the spinner and the torque wrench, including the upper and lower tongs and the associated clamps.', 'The software controls \n630\n may also be utilized to control other wellsite equipment that may be directly or closely associated with or operate in close association with the RN \n151\n.', 'The video output devices \n526\n and/or the touchscreens \n522\n, \n524\n may also display manual control guide menus or screens utilized by the wellsite operator \n195\n to guide or assist the wellsite operator \n195\n to manually control selected operations of the well construction system \n100\n, \n200\n or an individual piece of wellsite equipment.', 'The guide screens may display control functions of a selected one of the joysticks \n510\n, \n512\n, the associated physical controls \n518\n, and/or other physical controls \n514\n, \n516\n with respect to a selected operation or a piece of wellsite equipment.', 'Manual control may be initiated, for example, when the “MANUAL” software control \n630\n button is selected on one of the control screens displayed on one of the touchscreens \n522\n, \n524\n.', 'Thereafter, the control system \n300\n may abort automatic operation of the associated wellsite equipment, transfer operational control to a predetermined joystick \n510\n, \n512\n and/or other physical controls \n514\n, \n516\n, and display a corresponding manual control guide listing the control functions for manually controlling the wellsite equipment associated with the control screen.\n \nFIG.', '16\n is an example implementation of a manual control guide screen \n606\n displaying control functions for controlling drilling operations via the left joystick \n510\n and physical controls \n514\n.', 'The guide screen \n606\n may display a title bar \n640\n identifying an operation or wellsite equipment to be controlled and the joystick \n510\n and/or physical controls \n514\n for controlling such operation or wellsite equipment.', 'The guide screen \n606\n may comprise a joystick control area \n642\n displaying a schematic view \n644\n of the joystick \n510\n and a schematic view \n646\n of the associated physical controls \n518\n (e.g., joystick buttons and thumb lever).', 'Each schematic button \n646\n is associated with text \n638\n describing control functions of each corresponding physical button \n518\n of the joystick \n510\n.', 'The joystick control area \n642\n may further display arrows \n648\n and corresponding text \n650\n describing control functions associated with movements of the joystick \n510\n, and arrows \n652\n and corresponding text \n654\n describing control functions associated with movement of the joystick thumb lever \n518\n.', 'The guide screen \n606\n may also comprise a button control area \n656\n displaying schematic views \n658\n of the corresponding physical controls \n514\n.', 'The button control area \n656\n may further display text \n660\n describing control functions associated with operation of each of the corresponding physical controls \n514\n.', 'The guide screen \n606\n may further display an “EXIT” software control \n662\n, which may be operated to abort manual control of the drilling operations and close the guide screen \n606\n.', 'As described above with respect to \nFIG.', '7\n, an operator workstation within the scope of the present disclosure may display on one or more of the video output devices \n526\n a plurality of status screens, each displaying selected sensor signals or information (e.g., sensor data \n351\n-\n356\n) generated by various sensors (e.g., sensors \n321\n-\n326\n) of the wellsite construction system \n100\n, such as may permit the wellsite operator to monitor operations, wellsite equipment, and/or equipment subsystems (e.g., subsystems \n311\n-\n316\n) described herein.', 'FIGS.', '17\n-\n21\n are views of example implementations of status screens \n701\n-\n706\n displayed on one or more of the video output devices \n526\n according to one or more aspects of the present disclosure.', 'The following description refers to \nFIGS.', '1\n-\n4\n, \n7\n, and \n17\n-\n21\n, collectively.', 'The status screens, including the status screens \n701\n-\n706\n, may be displayed alternatingly on one of the video output devices \n526\n.', 'Some of the status screens may display operational status of a well construction operation (e.g., tripping, drilling, pipe handling, etc.) involving a plurality of pieces of wellsite equipment operating in a coordinated manner to perform such operation, which may permit the wellsite operator \n195\n to monitor operational status or parameters of such operation on a single status screen.', 'Some of the status screens may display operational status of a single piece of wellsite equipment or a subsystem (e.g., subsystem \n311\n-\n316\n) of wellsite equipment, such as may also permit the wellsite operator \n195\n to monitor operational status or parameters of a single piece of equipment or an equipment subsystem.', 'As described above, the status screen and the corresponding operation, wellsite equipment, or equipment subsystem may be selected via the touchscreens \n522\n, \n524\n.', 'As shown in \nFIG. \n11\n, example status screens that may be selected for display may include a tripping status screen displaying information indicative of operational status of the tripping operations, a drilling status screen displaying information indicative of operational status of the drilling operations, a pipe handing status screen displaying information indicative of operational status of the drill pipe handling operations, and a plurality of subsystem status screens each displaying information indicative of operational status of the corresponding subsystem of the well construction system \n100\n, \n200\n.', 'Although not described herein, the status screens within the scope of the present disclosure may also or instead include status screens displaying information indicative of operational status of individual pieces of wellsite equipment described herein.', 'The status screens, including the status screens \n701\n-\n706\n, may comprise a wellsite status screen indicator and alarm window or area \n710\n, which may visually indicate which operation or wellsite equipment is being displayed on a selected video output device \n526\n and if safety or operational alarms associated with an operation or wellsite equipment are active.', 'For example, the area \n710\n may include a plurality of indicators \n712\n (e.g., text, icons, graphics, etc.) listing operations, wellsite equipment, and/or equipment subsystems that may be displayed via corresponding status screens.', 'The indicator \n712\n corresponding to the operation, wellsite equipment, or equipment subsystem of the currently displayed status screen may appear or become lit, highlighted, or otherwise marked to indicate to the wellsite operator \n195\n which status screen is displayed.', 'The area \n710\n may further include a plurality of alarm or event indicators \n714\n (e.g., lights), each associated with a corresponding operation, wellsite equipment, or equipment subsystem indicator \n712\n.', 'One or more of the indicators \n714\n may activate (e.g., light up, change color, etc.), such as via operation of the control system \n300\n (shown in \nFIG.', '4\n), to visually inform the wellsite operator \n195\n of an alarm or operational event taking place at or associated with a corresponding operation, wellsite equipment, or equipment subsystem.', 'Responsive to the event indicator \n714\n being activated, the wellsite operator \n195\n may switch to a status screen corresponding to the activated event indicator \n714\n to assess the event and/or implement appropriate counteractive measures or actions.', 'Instead of manually changing between the status screens, the status screens may change automatically to show the status screen corresponding to the operation, wellsite equipment, or equipment subsystem experiencing the event.', 'The status screens, including the status screens \n701\n-\n706\n, may further comprise a primary operational status window or area \n716\n, displaying selected sensor signals or information indicative of operational status of the operation, wellsite equipment, or equipment subsystem associated with the displayed status screen.', 'The information displayed in the primary operational status area \n716\n may be generated by the actual wellsite equipment performing the operation or forming the equipment subsystem associated with the displayed status screen.', 'The information displayed in the primary operational status area \n716\n may change when a different display screen is displayed.', 'The information in the primary operational status area \n716\n may be displayed in the form of lists, menus, tables, graphs, bars, gauges, lights, and/or schematics, among other examples.', 'The status screens, including the status screens \n701\n-\n706\n, may further comprise a secondary operational status window or area \n718\n, displaying selected sensor signals or information indicative of operational status of drilling operations and/or general status of the well construction operations, such as may permit the wellsite operator to monitor progress of the drilling operations and/or other well construction operations while monitoring a specific operation, wellsite equipment, or equipment subsystem displayed in the primary operational status area \n716\n.', 'The secondary operational status area \n718\n may also display sensor signals or information indicative of operational status of other wellsite equipment that is related to, but not necessarily performing, the drilling operations.', 'The information that is displayed in the secondary operational status area \n718\n may remain unchanged or change partially when a different status screen is displayed, such as may permit the wellsite operator \n195\n to monitor progress of the drilling operations and/or other well construction operations while monitoring different operations, wellsite equipment, or equipment subsystems associated with the different status screens.', 'However, the information that is displayed in the secondary operational status area \n718\n may change when a different status screen is displayed.', 'The changing information may permit the wellsite operator \n195\n to monitor operational status of other wellsite equipment that is related to, but not necessarily directly performing, the operation displayed in the primary operational status area \n716\n, and/or to monitor operational status of other wellsite equipment that is related to the wellsite equipment or equipment subsystem displayed in the primary operational status area \n716\n.', 'The information in the secondary operational status area \n718\n may be displayed in the form of lists, menus, tables, graphs, bars, gauges, lights, and/or schematics, among other examples.', 'Each status screen, including the status screens \n701\n-\n706\n, may also comprise a detailed description window or area \n720\n listing and/or describing one or more aspects related to the operation, wellsite equipment, or equipment subsystem displayed in the primary operational status area \n716\n or another aspect of the well construction operations.', 'For example, as shown in \nFIGS.', '17\n and \n18', ', the description area \n720\n may display general and/or detailed description of work or activities (e.g., a construction or job plan) that was, is, or will be performed or overseen at the wellsite by the wellsite operator \n195\n.', 'The description area \n720\n may display proactive information regarding the work and/or call-to-actions guiding future work.', 'The description of work may include a title or name of the project stage or phase, an estimated completion date (i.e., deadline) for completing the project stage, and/or a list of operational steps or actions to be implemented by the wellsite operator \n195\n during the project stage.', 'However, the control system \n300\n may automatically operate the wellsite equipment or subsystem to automatically implement such steps or actions pursuant to the construction or job plan, such as by transmitting predetermined control commands to a corresponding piece of wellsite equipment or subsystem.', 'Such automated operations may be initiated, for example, by operating an “AUTO” software button \n630\n on an associated control screen, as described above.', 'As shown in \nFIGS.', '19\n-\n21', ', the description area \n720\n may also or instead display detailed description or information related to the events detected or otherwise taking place at the well construction system \n100\n, \n200\n.', 'The description area \n720\n may also list and/or describe one or more counteractive measures (e.g., corrective actions, operational sequences) related to the event that may be performed or otherwise implemented in response to the event.', 'Depending on the event and/or mode (e.g., advice, interlock, automated) in which the control system \n300\n (e.g., the computing resource environment \n305\n) is operating, the description area \n720\n may describe the corrective action to be initiated or otherwise implemented by the wellsite operator \n195\n.', 'However, the control system \n300\n may automatically implement the corrective action, or cause the corrective action to be automatically implemented, such as by transmitting predetermined control commands to a corresponding piece of wellsite equipment or subsystem.', 'The information displayed in the description area \n720\n may just display events and/or corrective actions related to the operation, wellsite equipment, or equipment subsystem shown in the primary operational status area \n716\n and, thus, change when switching between the status screens.', 'However, the information displayed in the description area \n720\n may not change when switching between the status screens, and may list each detected event and/or corresponding corrective action, such as in chronological order or in the order of importance.', 'As described above, the control system \n300\n may automatically change the status screen to show the operation, wellsite equipment, or equipment subsystem experiencing the event.', 'Each status screen, including the status screens \n701\n-\n706\n, may further include one or more PIP video windows \n722\n (shown in \nFIGS. \n20\n and \n21\n), each displaying in real-time a video signal from a predetermined video camera \n198\n to display wellsite equipment associated with the operation, wellsite equipment, or equipment subsystem displayed in the primary operational status area \n716\n.', 'The PIP video windows \n722\n may be embedded or inset on the corresponding status screens, such as within the primary operational status area \n716\n.', 'The view shown in the PIP video window \n722\n may be manually or automatically switched between different video cameras \n198\n to show different wellsite equipment or different views of the wellsite equipment.', 'As described above, the status screens to be displayed on the video output devices \n526\n may be selected via the touchscreens \n522\n, \n524\n.', 'However, the status screens, including the sensor signals or information displayed in the indicator and alarm area \n710\n, the primary operational status area \n716\n, the secondary operational status area \n718\n, the detailed description area \n720\n, and/or the PIP windows \n722\n, may automatically change based on successive stages of the well construction operations.', 'For example, while the well construction operations progress through successive stages (e.g., tripping, drilling, pipe handling, etc.), the control system \n300\n may cause the video output devices \n526\n to automatically change and display a status screen comprising information indicative of operational status of wellsite equipment performing or otherwise associated with a current stage of the well construction operations.', 'Each status screen, including the status screens \n701\n-\n706\n, may be adjusted or otherwise configured by the wellsite operator \n195\n to display one or more of the various information areas \n710\n, \n716\n, \n718\n, \n720\n in a chosen position on each status screen.', 'For example, the indicator and alarm area \n710\n may be displayed at the top of the status screens, the detailed description area \n720\n may be displayed at the bottom of the status screens, the primary operational status area \n716\n may be displayed in the middle on the left side of the status screens, and the secondary operational status area \n718\n may be displayed on the right side of the status screens.', 'Furthermore, the location and/or size (i.e., dimensions) of the PIP video windows \n722\n displayed on each status screen may also be adjusted or otherwise selected.', 'The relative location of the information areas \n710\n, \n716\n, \n718\n, \n720\n and the PIP video windows \n722\n on the status screens may also be selected, for example, via one or more of the physical controls \n514\n, \n516\n, \n518\n, such as by dragging and dropping the information areas \n710\n, \n716\n, \n718\n, \n720\n and/or the PIP video windows \n722\n to a chosen location on the status screens.', 'FIG.', '17\n is an example implementation of a status screen \n701\n displaying sensor signals or information indicative of operational status of various wellsite equipment associated with and collectively operable to perform drill pipe tripping operations according to one or more aspects of the present disclosure.', 'When the wellsite operator \n195\n or the control system \n300\n causes the tripping operations status screen \n701\n to be displayed on one of the video output devices \n526\n, the indicator \n712\n associated with the tripping operations, such as letters “TR,” may appear or become highlighted to visually indicate to the wellsite operator \n195\n that the tripping operations status screen is being displayed.', 'The primary operational status area \n716\n may display information, such as hook load, weight-on-bit, travelling block position, roughneck torque, trip tank accumulation or volume, and return flow, among other examples.', 'The secondary operational status area \n718\n may display information related to drilling operations, such as hook load, traveling block position, drill bit depth, wellbore depth, number of stands or tubulars in the wellbore, standpipe pressure, top drive dolly location, inside BOP position, top drive pipe connection status, elevator status, stick-up connection status, and slips status, among other examples.', 'The description area \n720\n may display a work plan (i.e., well construction plan) related to the tripping operations, including actions or steps that will be performed or overseen at the wellsite by the wellsite operator \n195\n during the tripping operations.', 'However, the description area \n720\n may also or instead display information indicative of operational events, as described above.\n \nFIG.', '18\n is an example implementation of a status screen \n702\n displaying sensor signals or information indicative of operational status of various wellsite equipment associated with and collectively operable to perform drilling operations according to one or more aspects of the present disclosure.', 'When the wellsite operator \n195\n or the control system \n300\n causes the drilling operations status screen \n702\n to be displayed on one of the video output devices \n526\n, the indicator \n712\n associated with the drilling operations, such as letters “DR,” may appear or become highlighted to visually indicate to the wellsite operator \n195\n that the drilling operations status screen is being displayed.', 'The primary operational status area \n716\n may display information, such as hook load, travelling block speed, weight-on-bit, rate of penetration, standpipe pressure, top drive torque, torque wrench torque, top drive rotational speed, drilling fluid loss/gain, and drilling fluid return flow, among other examples.', 'The secondary operational status area \n718\n may display information related to drilling operations, such as information related to or indicative of drilling fluid (i.e., mud) operational status and/or active tank operational status.', 'The description area \n720\n may display a work plan (i.e., well construction plan) related to the drilling operations, including actions or steps that will be performed or overseen at the wellsite by the wellsite operator \n195\n during the drilling operations.', 'However, the description area \n720\n may also or instead display information indicative of operational events, as described above.', 'As described above, the status screens may display sensor signals or information indicative of operational status of wellsite equipment subsystems (e.g., subsystems \n311\n-\n316\n).', 'FIG.', '19\n is an example implementation of an RC system status screen \n703\n displaying sensor signals or information indicative of operational status of the RC system \n311\n according to one or more aspects of the present disclosure.', 'When the wellsite operator \n195\n or the control system \n300\n causes the RC system status screen \n703\n to be displayed on one of the video output devices \n526\n, the indicator \n712\n associated with the RC system \n311\n, such as letters “RC,” may appear or become highlighted to visually indicate to the wellsite operator \n195\n that the RC system status screen \n703\n is being displayed.', 'The primary operational status area \n716\n may display sensor signals or information related to various pieces of wellsite equipment forming the RC system \n311\n, such as the catwalk \n131\n, the TDA \n202\n, the setback \n164\n, the FIB \n166\n, the TBR \n254\n, the SGA \n262\n, the LTC \n244\n, the ITC \n236\n, the UTC \n242\n, the LSA \n228\n, and the RN \n151\n, among other examples.', 'The primary operational status area \n716\n may also display schematic representations \n730\n of such wellsite equipment to visually display to the wellsite operator \n195\n operational status (e.g., position) of such wellsite equipment.', 'For example, the schematic representations \n730\n of the drill floor \n114\n, catwalk \n131\n, the setback \n164\n, the FIB \n166\n, the RN \n151\n, and the TDA \n202\n may visually indicate to the wellsite operator \n195\n in real-time movements and positions of various portions of such wellsite equipment.', 'The RC system status screen \n703\n may include schematic representations \n730\n of the skate \n133\n of the catwalk \n131\n, the TDA \n202\n, the LSA \n228\n, the SGA \n262\n, the ITC \n236\n, and the LTC \n244\n, and of the vertical pipe rack assembly \n165\n (e.g., setback \n164\n and FIB \n166\n) containing the tubulars \n111\n, among other examples.', 'Portions of the schematic representations \n730\n (e.g., various arms of the TDA \n202\n) may change position and/or color to visually indicate to the wellsite operator \n195\n various positions and movements of the represented wellsite equipment.', 'The primary operational status area \n716\n may also display sensor signals or information indicative of operational status of the wellsite equipment within text boxes \n732\n located in association with the schematic representations \n730\n of the wellsite equipment.', 'The secondary operational status area \n718\n may display information related to drilling operations and/or additional information related to operational status of the RC system \n311\n, such as additional information that is not displayed in the primary operational status area \n716\n.', 'The description area \n720\n may display information indicative of operational events, as described above.', 'However, the description area \n720\n may also or instead display a work plan related to tripping, drilling, or other wellsite construction operations.\n \nFIG.', '20\n is an example implementation of a CPC system status screen \n705\n displaying sensor signals or information indicative of operational status of the CPC system \n314\n according to one or more aspects of the present disclosure.', 'When the wellsite operator \n195\n or the control system \n300\n causes the CPC system status screen \n705\n to be displayed on one of the video output devices \n526\n, the indicator \n712\n associated with the CPC system \n314\n, such as letters “CPC,” may appear or become highlighted to visually indicate to the wellsite operator \n195\n that the CPC system status screen \n705\n is being displayed.', 'The primary operational status area \n716\n may display sensor signals or information related to various pieces of wellsite equipment forming the CPC system \n314\n, such as the choke manifold \n162\n and related wellsite equipment.', 'The primary operational status area \n716\n may also display schematic representations \n730\n of the wellsite equipment to visually display to the wellsite operator \n195\n operational status of such wellsite equipment.', 'The schematic representations \n730\n may include, for example, various fluid control valves (e.g., ball valves, adjustable chokes) of the choke manifold \n162\n and a plurality of fluid control valves fluidly connected with the choke manifold \n162\n.', 'The primary operational status area \n716\n may visually indicate to the wellsite operator \n195\n in real-time operational status, fluid flow rates, fluid pressures, and valve positions of the wellsite equipment forming the CPC system \n314\n.', 'Portions of the schematic representations \n730\n (e.g., fluid valves) may change position and/or color to indicate to the wellsite operator \n195\n operational status (e.g., positions) of such wellsite equipment.', 'The primary operational status area \n716\n may also display sensor signals or information indicative of operational status of the wellsite equipment within text boxes \n732\n located in association with the schematic representations \n730\n of the wellsite equipment.', 'The secondary operational status area \n718\n may display information related to drilling operations and/or additional information related to operational status of the CPC system \n314\n, such as additional information that is not displayed in the primary operational status area \n716\n.', 'The description area \n720\n may display information indicative of operational events, as described above.', 'However, the description area \n720\n may also or instead display a work plan related to tripping, drilling, or other wellsite construction operations.', 'A PIP video window \n722\n showing a real-time view of the choke manifold \n162\n or another portion of the CPC system \n314\n may be displayed in the primary operational status area \n716\n or another area of the CPC system status screen \n705\n.', 'FIG.', '21\n is an example implementation of a WC system status screen \n706\n displaying sensor signals or information indicative of operational status of the WC system \n315\n according to one or more aspects of the present disclosure.', 'When the wellsite operator \n195\n or the control system \n300\n causes the WC system status screen \n706\n to be displayed on one of the video output devices \n526\n, the indicator \n712\n associated with the WC system \n315\n, such as letters “WC,” may appear or become highlighted to visually indicate to the wellsite operator \n195\n that the WC system status screen \n706\n is being displayed.', 'The primary operational status area \n716\n may display sensor signals or information related to various pieces of wellsite equipment forming the WC system \n315\n, such as the BOP equipment \n130\n, \n132\n.', 'Information displayed in the primary operational status area \n716\n may include, for example, information related to risers/diverters, POD controls, POD regulators, analog sensor values (e.g., pressure, position), BOP event alarm signals, and inclination sensors.', 'The primary operational status area \n716\n may visually indicate to the wellsite operator \n195\n in real-time operational status, fluid pressures, and operational positions of the wellsite equipment forming the CPC system \n314\n.', 'The primary operational status area \n716\n may also display schematic representations \n730\n of the wellsite equipment to visually display to the wellsite operator \n195\n operational status of such wellsite equipment.', 'The schematic representations \n730\n may include, for example, the BOP stack \n130\n and the annular fluid control device \n132\n, and visually indicate to the wellsite operator \n195\n operational status (e.g., position) of the various rams and valves of the BOP stack \n130\n and the annular fluid control device \n132\n.', 'Portions of the schematic representations \n730\n (e.g., fluid valves, rams) may change position and/or color to indicate to the wellsite operator \n195\n operational status (e.g., positions) of such wellsite equipment.', 'The primary operational status area \n716\n may also display sensor signals or information indicative of operational status of the wellsite equipment within text boxes \n732\n located in association with the schematic representations \n730\n of the wellsite equipment.', 'The secondary operational status area \n718\n may display information related to drilling operations and/or additional information related to operational status of the WC system \n315\n, such as additional information that is not displayed in the primary operational status area \n716\n.', 'The description area \n720\n may display information indicative of operational events, as described above.', 'However, the description area \n720\n may also or instead display a work plan related to tripping, drilling, or other wellsite construction operations.', 'A PIP video window \n722\n showing a real-time view of the BOP equipment \n130\n, \n132\n or another portion of the WC system \n315\n may be displayed in the primary operational status area \n716\n or another area of the WC system status screen \n706\n.', 'FIG.', '22\n is a schematic view of at least a portion of an example implementation of a system (or processing device) \n800\n according to one or more aspects of the present disclosure.', 'The system \n800\n may form at least a portion of one or more electronic devices utilized at the well construction system \n100\n, \n200\n.', 'For example, the system \n800\n may be or form at least a portion of the processing devices \n188\n, \n192\n, \n456\n, and the control workstations \n450\n, \n452\n, \n454\n, \n500\n.', 'The system \n800\n may form at least a portion of the control system \n300\n, including the wellsite computing resource environment \n305\n, the coordinated control device \n304\n, the supervisory control system \n307\n, the local controllers \n341\n-\n346\n, the onsite user devices \n302\n, and the offsite user devices \n303\n.', 'The following description refers to \nFIGS.', '1\n-\n7\n and \n22\n, collectively.', 'The well construction system \n100\n, \n200\n also includes stationary and/or mobile video cameras \n198\n disposed or utilized at various locations within the well construction system \n100\n, \n200\n.', 'The video cameras \n198\n capture videos of various portions, equipment, or subsystems of the well construction system \n100\n, \n200\n, and perhaps the wellsite operators \n195\n and the actions they perform, during or otherwise in association with the wellsite operations, including while performing repairs to the well construction system \n100\n, \n200\n.', 'For example, the video cameras \n198\n may capture digital images (or video frames) of the entire well construction system \n100\n, \n200\n and/or specific portions of the well construction system \n100\n, \n200\n, such as the top drive \n116\n, the RN \n151\n, the TDA \n202\n, the FIB \n166\n, the setback \n164\n, the catwalk \n131\n, and/or the areas through which tubulars \n111\n are transferred between components of the well construction system \n100\n, \n200\n, among other examples.', 'The video cameras \n198\n generate corresponding video signals (i.e., feeds) comprising or otherwise indicative of the captured digital images.', 'The video cameras \n198\n may be in signal communication with the processing device \n192\n, such as may permit the video signals to be processed and transmitted to the control workstation \n197\n and, thus, permit the wellsite operators \n195\n to view various portions or components of the well construction system \n100\n, \n200\n on one or more of the output devices \n196\n.', 'The processing device \n192\n or another portion of the control workstation \n197\n may be operable to record the video signals generated by the video cameras \n198\n.', 'The system \n800\n may include a network ring \n900\n that electronically interconnects multiple drilling/analysis apparatus and/or control mechanisms for at least partially automating such apparatus.', 'On the network ring \n900\n, there may be a plurality of ring network nodes \n801\n that electronically connect various elements of the well construction system \n100\n, \n200\n or the control system \n300\n to each other.', 'For example, a first control workstation \n850\n (e.g., which may include or be the first control workstation \n450\n shown in \nFIGS.', '5\n and \n6\n and/or the wellsite operator control workstation \n500\n shown in \nFIG.', '7\n) and optionally a second control workstation \n852\n (e.g., which may include or be the second control workstation \n452\n shown in \nFIGS.', '5\n and \n6\n and/or the wellsite operator control workstation \n500\n shown in \nFIG.', '7\n) may be electronically connected to the network ring \n900\n through one or more of the plurality of ring network nodes \n801\n.', 'Optionally, the network ring \n900\n may be electronically interconnected, via one or more ring network nodes \n801\n, to a phone system comprising one or more phone lines.', 'For example, five VOIP (Voice over Internet Protocol) lines \n881\n-\n885\n are represented in \nFIG.', '22\n, but there may be more or fewer phone lines to accommodate various numbers of users, workstations, or the like.', 'Programmable logic controllers (PLCs) \n901\n, \n911\n, \n921\n, \n931\n, \n941\n, \n951\n, \n961\n, \n971\n, \n981\n, \n991\n are also connected to the network ring \n900\n, each through a corresponding ring network node \n801\n, thus facilitating communication between the first and second control workstations \n850\n, \n852\n and the well construction and/or control subsystems (e.g., the RC subsystem \n311\n, the FC subsystem \n312\n, the MPDC subsystem \n313\n, the CPC subsystem \n314\n, the WC subsystem \n315\n, and the CCTV subsystem \n316\n, inter alia).', 'Each PLC \n901\n, \n911\n, \n921\n, \n931\n, \n941\n, \n951\n, \n961\n, \n971\n, \n981\n, \n991\n may be electronically connected to its own subsystem network ring \n909\n, \n919\n, \n929\n, \n939\n, \n949\n, \n959\n, \n969\n, \n979\n, \n989\n, \n999\n, each of which electronically connect to its corresponding PLC and/or to one or more other pieces of equipment via subsystem ring network nodes \n809\n, \n819\n, \n829\n, \n839\n, \n849\n, \n859\n, \n869\n, \n879\n, \n889\n, \n899\n.', 'For example, programmable logic subsystem controllers, processing devices, and/or sensors \n902\n, \n903\n, \n904\n, \n905\n may be electronically connected, each through a corresponding subsystem ring network node \n809\n, to the subsystem network ring \n909\n that is also electronically connected to the PLC \n901\n through its own subsystem ring network node \n809\n, thereby forming a ring network subsystem.', 'Although four PLCs/sensors/processing devices \n902\n-\n905\n are represented as being connected to PLC \n901\n via the subsystem network ring \n909\n in \nFIG.', '22\n, it should be understood that more or fewer such devices may be electronically connected thereto and/or that there may be more than one class of such devices electronically connected thereto in a given ring network subsystem.', 'Similar ring network subsystems are shown in \nFIG.', '22\n as being connected to the network ring \n900\n, each via a corresponding ring network node \n801\n electronically connecting additional PLCs \n911\n, \n921\n, \n931\n, \n941\n, \n951\n, \n961\n, \n971\n, \n981\n, \n991\n and additional PLCs/sensors/processing devices \n912\n-\n915\n, \n922\n-\n925\n, \n932\n-\n935\n, \n942\n-\n945\n, \n952\n-\n955\n, \n962\n-\n965\n, \n972\n-\n975\n, \n982\n-\n984\n, \n992\n-\n995\n, through corresponding subsystem ring network nodes \n819\n, \n829\n, \n839\n, \n849\n, \n859\n, \n869\n, \n879\n, \n889\n, \n899\n via their corresponding subsystem network rings \n919\n, \n929\n, \n939\n, \n949\n, \n959\n, \n969\n, \n979\n, \n989\n, \n999\n.', 'Again, although four workstations \n992\n-\n995\n are represented as being connected to PLC \n991\n via subsystem network ring \n999\n and although three cameras \n982\n-\n984\n are represented as being connected to PLC \n981\n via subsystem network ring \n989\n in \nFIG.', '22\n, it should be understood that more or fewer such devices may be electronically connected thereto and/or that there may be more than one class of such devices electronically connected thereto in any given ring network subsystem.', 'FIG.', '23\n is a schematic view of at least a portion of an example implementation of a processing device \n1000\n according to one or more aspects of the present disclosure.', 'One or more electronic devices utilized at the well construction system \n100\n, \n200\n may each be, comprise, or be formed by at least a portion of the processing device \n1000\n.', 'For example, the processing devices \n188\n, \n192\n, \n456\n, the BOP control station \n470\n, the control workstations \n450\n, \n452\n, \n454\n, \n500\n, \n850\n, \n852\n, \n992\n, and the CPUs \n901\n-\n981\n, may each be, comprise, or be formed by at least a portion of an instance the processing device \n1000\n.', 'Instances of the processing device \n1000\n, or portions thereof, may form at least a portion of the control system \n300\n, including the wellsite computing resource environment \n305\n, the coordinated control device \n304\n, the supervisory control system \n307\n, the local controllers \n341\n-\n346\n, the onsite user devices \n302\n, and the offsite user devices \n303\n.', 'The processing device \n1000\n may be in communication with various sensors, actuators, controllers, and other devices of the subsystems \n311\n-\n316\n and/or other portions of the well construction system \n100\n, \n200\n.', 'The processing device \n1000\n may be operable to receive coded instructions \n1032\n from the wellsite operators \n195\n via the wellsite control workstation \n500\n, \n850\n, \n852\n and the sensor data \n351\n-\n356\n generated by the sensors \n321\n-\n326\n, process the coded instructions \n1032\n and the sensor data \n351\n-\n356\n, and communicate the control data \n361\n-\n366\n to the local controllers \n341\n-\n346\n and/or the actuators \n331\n-\n336\n of the subsystems \n311\n-\n316\n to execute the coded instructions \n1032\n to implement at least a portion of one or more example methods and/or operations described herein, and/or to implement at least a portion of one or more of the example systems described herein.', 'The processing device \n1000\n may be or comprise, for example, one or more processors, special-purpose computing devices, servers, personal computers (e.g., desktop, laptop, and/or tablet computers), personal digital assistants, smartphones, internet appliances, and/or other types of computing devices.', 'The processing device \n1000\n may comprise a processor \n1012\n, such as a general-purpose programmable processor.', 'The processor \n1012\n may comprise a local memory \n1014\n, and may execute coded instructions \n1032\n present in the local memory \n1014\n and/or another memory device.', 'The processor \n1012\n may execute, among other things, the machine-readable coded instructions \n1032\n and/or other instructions and/or programs to implement the example methods and/or operations described herein.', 'The programs stored in the local memory \n1014\n may include program instructions or computer program code that, when executed by the processor \n1012\n of the processing device \n1000\n, may cause the subsystems \n311\n-\n316\n and/or individual pieces of wellsite equipment of the well construction system \n100\n, \n200\n to perform the example methods and/or operations described herein.', 'The processor \n1012\n may be, comprise, or be implemented by one or more processors of various types suitable to the local application environment, and may include one or more of general-purpose computers, special-purpose computers, microprocessors, digital signal processors (DSPs), field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), and processors based on a multi-core processor architecture, as non-limiting examples.', 'Of course, other processors from other families are also appropriate.', 'The processor \n1012\n may be in communication with a main memory \n1016\n, such as may include a volatile memory \n1018\n and a non-volatile memory \n1020\n, perhaps via a bus \n1022\n and/or other communication means.', 'The volatile memory \n1018\n may be, comprise, or be implemented by random access memory (RAM), static random access memory (SRAM), synchronous dynamic random access memory (SDRAM), dynamic random access memory (DRAM), RAMBUS dynamic random access memory (RDRAM), and/or other types of random access memory devices.', 'The non-volatile memory \n1020\n may be, comprise, or be implemented by read-only memory, flash memory, and/or other types of memory devices.', 'One or more memory controllers (not shown) may control access to the volatile memory \n1018\n and/or non-volatile memory \n1020\n.', 'The processing device \n1000\n may also comprise an interface circuit \n1024\n.', 'The interface circuit \n1024\n may be, comprise, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'The interface circuit \n1024\n may also comprise a graphics driver card.', 'The interface circuit \n1024\n may also comprise a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).', 'One or more of the local controllers \n341\n-\n346\n, the sensors \n321\n-\n326\n, and the actuators \n331\n-\n336\n may be connected with the processing device \n1000\n via the interface circuit \n1024\n, such as may facilitate communication between the processing device \n1000\n and the local controllers \n341\n-\n346\n, the sensors \n321\n-\n326\n, and/or the actuators \n331\n-\n336\n.', 'One or more input devices \n1026\n may also be connected to the interface circuit \n1024\n.', 'The input devices \n1026\n may permit the wellsite operators \n195\n to enter the coded instructions \n1032\n, such as control commands, processing routines, and/or operational settings and set-points.', 'The input devices \n1026\n may be, comprise, or be implemented by a keyboard, a mouse, a joystick, a touchscreen, a track-pad, a trackball, an isopoint, and/or a voice recognition system, among other examples.', 'One or more output devices \n1028\n may also be connected to the interface circuit \n1024\n.', 'The output devices \n1028\n may be, comprise, or be implemented by video output devices (e.g., an LCD, an LED display, a touchscreen, etc.), printers, and/or speakers, among other examples.', 'The processing device \n1000\n may also communicate with one or more mass storage devices \n1030\n and/or a removable storage medium \n1034\n, such as may be or include floppy disk drives, hard drive disks, compact disk (CD) drives, digital versatile disk (DVD) drives, and/or USB and/or other flash drives, among other examples.', 'The coded instructions \n1032\n may be stored in the mass storage device \n1030\n, the main memory \n1016\n, the local memory \n1014\n, and/or the removable storage medium \n1034\n.', 'Thus, the processing device \n1000\n may be implemented in accordance with hardware (perhaps implemented in one or more chips including an integrated circuit, such as an ASIC), or may be implemented as software or firmware for execution by the processor \n1012\n.', 'In the case of firmware or software, the implementation may be provided as a computer program product including a non-transitory, computer-readable medium or storage structure embodying computer program code (i.e., software or firmware) thereon for execution by the processor \n1012\n.', 'The coded instructions \n1032\n may include program instructions or computer program code that, when executed by the processor \n1012\n, may cause the various subsystems \n311\n-\n316\n or individual pieces of wellsite equipment of the well construction system \n100\n, \n200\n to perform intended methods, processes, and/or operations disclosed herein.', 'In the example operations sequences described below, among others within the scope of the present disclosure, the pipe handling equipment may be operated automatically via the Construction Program, and the step execution of the pipe handling equipment may be controlled automatically by one or two operators \n195\n at the associated workstation(s) \n450\n, \n452\n, \n454\n.', 'The Construction Program may also feature configurable step confirmations.', 'Each sequence controlled by the Construction Program may be stopped or interrupted at any time, and some or all functions may be operated manually by the one or two operators \n195\n at the associated workstation(s) \n450\n, \n452\n, \n454\n.', 'Various well construction operations may be performed utilizing different combinations of the aspects described above.', 'For example, when a tripping-in operation is to be performed, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth below in Table 1A.\n \n \n \n \n \n \n \n \nTABLE 1A\n \n \n \n \n \n \n \n \nTripping-In Preparations\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nFIB 166\n \nOperator 195 on rig floor 114.', 'Tubulars 111 exist per HMI/tally.', 'Setback 164\n \n \nFingers are closed.', 'Travel path is unobstructed.', 'TBR 254\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'SGA 262\n \n \nGripper inserts/dies are clean, not worn.', 'LTC 244\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'ITC 236\n \n \nGripper inserts/dies are clean, not worn.', 'UTC 242\n \n \nITC 236 is open and retracted.', 'THP\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'Doper 209\n \n \nWater, correct dope available for doper\n \n \n \n \n \n209.', 'LSA 228\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'TDA 202\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'Correct dope available for doper 209.', 'Correct inserts/dies in gripper/elevator.', 'Inserts/dies are clean, not worn.', 'RN 151\n \nOperator 195 on rig floor 114.', 'Drill pipe tong (DPT) is connected.', 'Gripper dies are clean, not worn.', 'Travel path is unobstructed.', 'Slips 161\n \nOperator 195 on rig floor 114; and/or\n \nCorrect inserts/dies.', '“Driller” 195 at workstation 452.', 'Inserts/dies are clean, not worn.', 'TD 116\n \nOperator 195 on rig floor 114; and/or\n \nCorrect inserts/dies in elevator.', '“Driller” 195 at workstation 452.', 'Correct saver sub status.', 'Travel path is unobstructed.', 'DW 119\n \nOperator 195 on rig floor 114; and/or\n \nChecked.', '“Driller” 195 at workstation 452.', 'The well construction system \n100\n, \n200\n can then be set-up for the trip-in sequence.', 'Examples of such set-up may be as set forth below in Table 1B.\n \n \n \n \n \n \n \n \nTABLE 1B\n \n \n \n \n \n \n \n \nTripping-In Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nDriller/\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'handling:\n \nPipe\n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nTBR 254,\n \nHandler\n \nemergency stop for all pipe handling\n \nsetup wizard.', 'SGA 262,\n \n \nequipment.', 'After startup: Check for\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \nLTC 244,\n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \nITC 236,\n \n \nSelect Trip In mode.', 'status header on front\n \n \n \nTHP 207,\n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.', 'TDA 202,\n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \nLSA 228,\n \n \nsettings:\n \n \n \nRN 151\n \n \nSelect slot, direction for picking\n \n \n \n \n \npipe.', 'Select Pipe type.', 'Select RN 151 to use in the\n \n \n \n \n \noperations.', 'RN 151 MU torque.', 'Select pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'DW 119,\n \n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nMP 144,\n \n \nemergency stop for all pipe handling\n \nsetup wizard.', 'Trip tank\n \n \nequipment.', 'After startup: Check for\n \n \n \n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \n \n \nSelect Trip In mode.', 'status header on front\n \n \n \n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \n \n \nsettings:\n \n \n \n \n \nStick-up target.', 'Set DW 119 upper/lower stops.', 'Set maximum lowering speed.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator screen,\n \n \n \n \n \ncompleted pre-checks.', 'system status/alarms.', 'Activate TD 116 from touchscreen 522,\n \n \n \n \n \n524.', 'Select Operation screen on touchscreen\n \n \n \n \n \n522, 524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator screen,\n \n \n \n \n \n524.\n \nsystem status/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled\n \nVerify operator screen,\n \n \n \nmachines\n \n \nin zone management system and\n \nsystem status/alarms.', 'tubular interlock system.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'The tripping-in sequence starts with the top drive \n116\n in a lower position with the elevator \n129\n closed, with the slips \n161\n closed, and with a portion (e.g., about one meter) of the drill string \n120\n (referred to as “stick-up”) protruding above the slips \n161\n.', 'A tubular \n111\n has been lifted by the TDA \n202\n (and perhaps the LSA \n228\n) from the THP \n207\n to stick-up level above the MOH \n204\n.', 'The THP \n207\n is empty, and the UTC \n242\n and the LTC \n244\n are open and retracted.', 'The TBR \n254\n and the SGA \n262\n may also be empty and perhaps moving to pick up a new tubular \n111\n from the vertical pipe rack assembly \n165\n.', 'The top drive elevator \n129\n is then opened and retracted from the stick-up.', 'The top drive \n116\n is then moved to an upper stop via operation of the DW \n119\n.', 'The TDA \n202\n (perhaps with cooperation from the LSA \n228\n) then moves the new tubular \n111\n to over the well center \n203\n (WC).', 'The RN \n151\n also moves toward the WC \n203\n.', 'During this time, the TBR \n254\n and the SGA \n262\n operate to remove another tubular \n111\n from the setback \n164\n and the FIB \n166\n.', 'The position from which this additional tubular \n111\n is removed may be selected automatically or via input from the operator \n195\n at a control workstation \n450\n, \n452\n, \n454\n.', 'For example, a “Pipe Handler” operator \n195\n seated at control workstation \n450\n may generally control/monitor pipe handling equipment (e.g., equipment that is handling tubulars \n111\n that not connected to the drill string \n120\n), while a “driller” operator \n195\n seated at control workstation \n452\n may generally control/monitor the remaining equipment (or at least the equipment that is handling the drill string \n120\n).', 'The TBR \n254\n and the SGA \n262\n then cooperate to move the currently held tubular \n111\n to the THP \n207\n.', 'The UTC \n242\n and the LTC \n244\n then close to hold the new tubular \n111\n.', 'The doper \n209\n may be integrated in or otherwise associated with the THP \n207\n may then wash and dope the pin end of the new tubular \n111\n.', 'The TBR \n254\n and the SGA \n262\n may then return to select the next tubular \n111\n from the vertical pipe rack assembly.', 'A stabbing guide and/or back up tong (BUT) of the RN \n151\n may then be closed to assist stabbing.', 'The TDA \n202\n then lowers the new tubular \n111\n to stab into the stick-up, perhaps continuing a short distance (e.g., about one meter) after stabbing to provide room for the top drive elevator \n129\n.', 'The LSA \n228\n may then open and retract from WC \n203\n.', 'The RN \n151\n then performs low-torque spinning and subsequent high-torque “wrenching” to make-up the tubular \n111\n to the drill string \n120\n.', 'The top drive \n116\n, which during this time was hoisted to an elevation generally near the top end of the new tubular \n111\n, then extends to WC \n203\n and closes the elevator \n129\n around the new tubular \n111\n.', 'At the same time, the TDA \n202\n and (perhaps) the LSA \n228\n move to the THP \n207\n for the next tubular \n111\n, and the RN \n151\n opens and retracts away from the WC \n203\n to a standby position.', 'The DW \n119\n then lifts the top drive \n116\n to pick up the now-extended drill string \n120\n and open the slips \n161\n, and then lowers the top drive \n116\n to lower the drill string \n120\n into the wellbore \n102\n.', 'The slips \n161\n are closed again, leaving a stick-up ready for the next tubular \n111\n.', 'During this time that the drill string \n120\n is being lowered into the wellbore, the TDA \n202\n and (perhaps) the LSA \n228\n extend and latch onto another new tubular \n111\n currently in the THP \n207\n, and then the UTC \n242\n and the LTC \n244\n and opened and retracted.', 'The new tubular \n111\n is lifted from setback level to drill (rig) floor level (e.g., about 9 meters), perhaps guided by the LSA \n228\n.', 'The box (top) end of the new tubular \n111\n can be doped by another washing/doping device, if selected.', 'This trip-in sequence is summarized in Table 1C set forth below.', 'TABLE 1C\n \n \n \n \n \n \n \n \nTripping-In Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nPrecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nOpen elevator 129:', 'Visual/\n \nSlips 161 closed.', 'Elevator open is not\n \nElevator 129 to\n \n \n \n \n \nVerify slips 161 are\n \nCCTV\n \n \nselectable if slips\n \nOpen state.', 'closed.', '161 are not closed.', 'Open elevator 129.\n \n \n \n \n \n \n \n1.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and\n \nTBR 254 will move\n \nTBR 254 and\n \n \n \n \nHandler\n \npick up new tubular 111:\n \nCCTV\n \nSGA 262 are open.', 'above open latches.', 'SGA 262 grip/\n \n \n \n \n \nMove TBR 254 and\n \n \nPosition selected\n \nTBR 254 and SGA\n \nguide to Closed\n \n \n \n \n \nSGA 262 to selected\n \n \nin FIB 166 is “valid.”\n \n262 grip/guide will\n \nstate.', 'finger/slot in FIB 166.\n \n \n \nclose.', 'Close guides and\n \n \n \n \n \n \n \n \n \nclamp on tubular 111.\n \n \n \n \n \n \n \n2.\n \nDriller\n \nRetract and move TD\n \nVisual/\n \nTD 116 pipe\n \n \nDW 119 upper\n \n \n \n \n \n116 to latching height:\n \nCCTV\n \nhandler position\n \n \nstop setting.', 'Verify elevator 129 is\n \n \nfacing TDA 202.\n \n \n \n \n \n \n \nopen.', 'Retract TD 116 to\n \n \n \n \n \n \n \n \n \nclear tool joint (TJ).', 'Hoist elevator 129 to\n \n \n \n \n \n \n \n \n \ntubular latch height\n \n \n \n \n \n \n \n \n \n(upper stop or\n \n \n \n \n \n \n \n \n \ncalculated stop point).', '2.1.', 'Pipe\n \nMove RN 151 to WC\n \nVisual/\n \nOnly possible with\n \nRN 151 will move\n \nTJ (stick-up)\n \n \n \n \nHandler\n \n203:\n \nCCTV\n \ntong handling\n \nto WC 203.', 'assist indication.', 'Verify TD 116 is\n \n \ntrolley (THT).', 'If\n \nElevate to stick-up.\n \n \n \n \n \n \nhoisted above working\n \n \ntong handling arm\n \n \n \n \n \n \n \narea of RN 151.\n \n \n(THA) is used, then\n \n \n \n \n \n \n \nStart RN 151 make-up\n \n \nwait for tubular 111\n \n \n \n \n \n \n \nsequence to move RN\n \n \nlocated above stick-\n \n \n \n \n \n \n \n151 to WC 203.\n \n \nup.', 'RN 151 tongs are\n \n \n \n \n \n \n \n \n \nopen.', 'WC 203 is\n \n \n \n \n \n \n \n \n \nselected.', '2.2\n \nPipe\n \nTDA 202 moves tubular\n \nVisual/\n \nTD 116 is retracted.', 'Tilt towards WC\n \nTDA 202 load\n \n \n \n \nHandler\n \n111 to WC 203:\n \nCCTV\n \n \n203.\n \nindication.', 'TDA 202 moves\n \n \n \nTDA 202 dope top\n \n \n \n \n \n \ntubular 111 to WC 203.\n \n \n \nbox if preselected\n \n \n \n \n \n \nLSA 228 guides to WC\n \n \n \n(automatic).', '203.', '2.3.', 'Pipe\n \nGuide tubular 111 with\n \nCCTV\n \nTubular 111 is held\n \nClose RN 151\n \nStabbing guide\n \n \n \n \nHandler\n \nRN 151 in WC 203:\n \n \nby TDA 202/LSA\n \nBUT.', 'Closed indication.', 'Verify tubular 111 is\n \n \n228 above stick-up\n \nClose stabbing\n \nBUT Closed\n \n \n \n \n \nover WC 203.\n \n \nat WC 203.\n \nguide.\n \nindication.', 'Adjust elevation if\n \n \n \n \n \n \n \n \n \nneeded.', 'Continue RN 151\n \n \n \n \n \n \n \n \n \nsequence.', '2.4.\n \nPipe\n \nTDA 202 stabs tubular\n \nVisual/\n \nRN 151 is at WC\n \nContinue lowering\n \nTDA 202 load\n \n \n \n \nHandler\n \n111 in stick-up:\n \nCCTV\n \n203 with stabbing\n \n(e.g., about two\n \nindication\n \n \n \n \n \nLower tubular 111 to\n \n \nguide closed.\n \nmeters) after verify\n \n(unloading).', 'stab into stick-up.\n \n \n \nset of weight.', 'Continue lowering to\n \n \n \n \n \n \n \n \n \npermit room for elevator\n \n \n \n \n \n \n \n \n \n129.', 'LSA 228 opens and\n \n \n \n \n \n \n \n \n \nretracts when RN 151\n \n \n \n \n \n \n \n \n \nstabbing guide is closed\n \n \n \n \n \n \n \n \n \non tubular 111.\n \n \n \n \n \n \n \n2.5.', 'Pipe\n \nRN 151 spin-in and\n \nVisual/\n \nTubular 111 is\n \nSpin-in and make-\n \nTorque log\n \n \n \n \nHandler\n \nmake-up:\n \nCCTV\n \nstabbed in stick-up.', 'up', 'connection.\n \nupdated.', 'Verify RN 151 is in\n \n \nTDA 202 is\n \nOpen spinner,\n \nMake-up (MU)\n \n \n \n \n \ncorrect elevation.', 'unloaded.\n \nguide, and clamps.', 'torque presented\n \n \n \n \n \nContinue RN 151\n \n \n \nRN 151 returns to\n \nto driller.\n \n \n \n \n \nsequence to spin-in and\n \n \n \npark position.\n \n \n \n \n \n \nmake-up.\n \n \n \n \n \n \n \n2.6.\n \nPipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTHP 207 is empty.', 'TBR 254 cannot\n \nIndicate FIB 166\n \n \n \n \nHandler\n \nmove tubular 111 to\n \nCCTV\n \nUTC 242 and LTC\n \nopen with weight.', 'latches Open.', 'THP 207:\n \n \n244 are open.', 'TBR 254 opens\n \nTBR 254 load\n \n \n \n \n \nOpen FIB 166 latches\n \n \nCorrect pipe\n \nwhen unloaded.\n \nindication.', 'for selected row.\n \n \ndetected in TBR\n \nFIB 166 latches will\n \n \n \n \n \n \nVerify latches open.\n \n \n254 and SGA 262.\n \nnot open with TBR\n \n \n \n \n \n \nTBR 254 and SGA 262\n \n \n \n254 in low position.', 'move tubular 111 to\n \n \n \n \n \n \n \n \n \nTHP 207.', 'FIB 166 latches will\n \n \n \n \n \n \n \n \n \nclose as the tubular 111\n \n \n \n \n \n \n \n \n \nis moved out.', 'Wash and/or dope pin\n \n \n \n \n \n \n \n \n \nof tubular 111 if\n \n \n \n \n \n \n \n \n \npreselected.', '2.7.\n \nPipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nextend to THP 207 and\n \nCCTV\n \n262 have tubular\n \n244 extend and\n \nLTC 244 to\n \n \n \n \n \nthen close.\n \n \n111 in THP 207.\n \nclose.', 'Closed state.', '2.8.\n \nPipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nUTC 242 and LTC\n \n \n \n \n \n \nHandler\n \nopen and move towards\n \nCCTV\n \n244 closed on\n \n \n \n \n \n \n \nFIB 166:\n \n \ntubular 111.', 'Open TBR 254 and\n \n \n \n \n \n \n \n \n \nSGA 262 damps/\n \n \n \n \n \n \n \n \n \nguides.', 'Move TBR 254 and\n \n \n \n \n \n \n \n \n \nSGA 262 toward FIB\n \n \n \n \n \n \n \n \n \n166 (next tubular 111).', 'Continue step 1.1.', '3.', 'Driller\n \nExtend TD 116 and latch\n \nVisual/\n \nTDA 202 below TJ.\n \n \nElevator 129 to\n \n \n \n \n \nelevator 129:\n \nCCTV\n \n \n \nClosed state.', 'Extend TD 116 to WC\n \n \n \n \nIndicate TD\n \n \n \n \n \n203.\n \n \n \n \n116 at WC 203.', 'Latch elevator 129\n \n \n \n \n \n \n \n \n \n(automatic close on\n \n \n \n \n \n \n \n \n \nimpact).', '3.1.', 'Pipe\n \nTDA 202 opens and\n \nVisual/\n \nTD elevator 129 is\n \nTDA 202 will rotate\n \nTDA 202 to\n \n \n \n \nHandler\n \nmoves to THP 207:\n \nCCTV\n \nclosed.\n \nand lower when\n \nOpen state.', 'Verify elevator 129 is\n \n \n \nvertical until facing\n \n \n \n \n \n \nclosed.\n \n \n \ntoward THP 207.', 'Move TDA 202 to\n \n \n \n \n \n \n \n \n \ntubular 111 in THP 207.\n \n \n \n \n \n \n \n4.\n \nDriller\n \nOpen slips 161:\n \nVisual\n \nTD elevator 129\n \n \nSlips 161 to\n \n \n \n \n \nOpen slips 161\n \n \nis closed.', 'Open state.', '(command).', 'RN 151 has\n \n \nDW 119 load.', 'Hoist to open slips\n \n \ncompleted the\n \n \n \n \n \n \n \n161.\n \n \nmake-up\n \n \n \n \n \n \n \n \n \nsequence with\n \n \n \n \n \n \n \n \n \ncorrect torque.', '5.\n \nDriller\n \nLower drill string 120:\n \nVisual\n \nSlips 161 are\n \n \nSettings: DW 119\n \n \n \n \n \nVerify slips 161 are\n \n \nopen.', 'lowering speed\n \n \n \n \n \nopen before lowering\n \n \n \n \nand minimum\n \n \n \n \n \ndrill string 120.\n \n \n \n \nslack-off weight.\n \n \n \n5.1.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTDA 202 is\n \nTDA 202 moves\n \n \n \n \n \nHandler\n \nextend to tubular 111 in\n \nCCTV\n \nopen.', 'until contact with\n \n \n \n \n \n \nTHP 207:\n \n \nLSA 228 guide\n \ntubular 111 in THP\n \n \n \n \n \n \nMove TDA 202 until\n \n \nfunnel is open.', '207.\n \n \n \n \n \n \ncontact with tubular 111\n \n \n \n \n \n \n \n \n \nin THP 207, below TJ.\n \n \n \n \n \n \n \n5.2.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTDA 202 is at\n \nThe closing\n \nConfirm TDA\n \n \n \n \nHandler\n \nlatch onto tubular 111 in\n \nCCTV\n \nTHP 207.', 'sequence is\n \n202 is closed on\n \n \n \n \n \nTHP 207:\n \n \n \nverified to assure\n \ntubular 111.', 'Close TDA 202.\n \n \n \nproper grip on\n \nLSA 228 guide\n \n \n \n \n \nClose LSA 228 guide\n \n \n \ntubular 111.\n \nis closed.\n \n \n \n \n \nfunnel.\n \n \n \n \n \n \n \n5.3.', 'Pipe\n \nUTC 242 and LTC 244', 'Visual/\n \nTDA 202 is\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nopen and retract.', 'CCTV\n \nclosed.', '244 open and\n \nLTC 244 to Open\n \n \n \n \n \n \n \n \nretract.\n \nstate.\n \n \n \n5.4.', 'Pipe\n \nTDA 202 moves tubular\n \nVisual/\n \nUTC 242 and LTC\n \nTDA 202 hoists,\n \nTDA 202 load\n \n \n \n \nHandler\n \n111 to THP 207:\n \nCCTV\n \n244 are open.', 'tilts to vertical,\n \nindication.', 'TDA 202 lifts tubular\n \n \n \nrotates 180\n \n \n \n \n \n \n111, guided by LSA\n \n \n \ndegrees to face TD\n \n \n \n \n \n \n228, to THP 207.\n \n \n \n116.', 'Continue step 2.2.', 'TDA 202 dopes\n \n \n \n \n \n \n \n \n \ntop box if\n \n \n \n \n \n \n \n \n \npreselected\n \n \n \n \n \n \n \n \n \n(automatic).', '6.\n \nDriller\n \nSet slips 161:\n \nVisual\n \nStick-up at correct\n \n \nSlips 161 to\n \n \n \n \n \nSet slips 161 at correct\n \n \nheight.', 'Closed state.', 'stick-up height.', 'DW 119 load\n \n \n \n \n \nSet off weight.\n \n \n \n \nindicator.', 'Tally update.', '7.\n \nDriller\n \nCheck trip tank volume,\n \nVisual\n \nSlips 161 are\n \nTrip tank gain/loss is\n \nTrip sheet/\n \n \n \n \n \ngain/loss:\n \n \nclosed.', 'calculated and\n \nvolume control.', 'Determine trip tank\n \n \n \ndisplayed.', 'gain/loss.', 'Repeat all steps for\n \n \n \n \n \n \n \n \n \nnext tubular 111.', 'When a tripping-out operation is to be performed, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth above in Table 1A. The well construction system \n100\n, \n200\n can then be set-up for the trip-out sequence.', 'Examples of such set-up may be as set forth below in Table 2A.\n \n \n \n \n \n \n \n \nTABLE 2A\n \n \n \n \n \n \n \n \nTripping-Out Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nDriller/\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'handling:\n \nPipe\n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nTBR 254,\n \nHandler\n \nemergency stop for all pipe handling\n \nsetup wizard.', 'SGA 262,\n \n \nequipment.', 'After startup: Check for\n \n \n \nUTC 242,\n \n \nSelect Trip Out mode.', 'green light in\n \n \n \nLTC 244,\n \n \nSelect setup wizard to open pop-up on\n \nConstruction Program\n \n \n \nITC 236,\n \n \nfront screen 532, 534, 536.', 'Verify\n \nstatus header on front\n \n \n \nTHP 207,\n \n \nsettings:\n \nscreen 532, 534, 536.', 'TDA 202,\n \n \nSelect slot, direction for picking\n \n \n \nLSA 228,\n \n \npipe.', 'RN 151\n \n \nSelect pipe type.', 'Select RN 151 to use in the\n \n \n \n \n \noperations.', 'Select pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'DW 119,\n \n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nMP 144,\n \n \nemergency stop for all pipe handling\n \nsetup wizard.', 'Trip tank\n \n \nequipment.', 'After startup: Check for\n \n \n \n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \n \n \nSelect Trip Out mode.', 'status header on front\n \n \n \n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \n \n \nsettings:\n \n \n \n \n \nStick-up target.', 'Set DW 119 upper/lower stops.', 'Set maximum lowering speed.', 'Set over pull.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator screen,\n \n \n \n \n \ncompleted pre-checks.', 'system status/alarms.', 'Activate TD 116 from touchscreen 522,\n \n \n \n \n \n524.', 'Select Operation screen on touchscreen\n \n \n \n \n \n522, 524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator screen,\n \n \n \n \n \n524.\n \nsystem status/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled\n \nVerify operator screen,\n \n \n \nmachines\n \n \nin zone management system and\n \nsystem status/alarms.', 'tubular interlock system.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example trip-out sequence may start with the TD \n116\n in lower position over WC \n203\n with closed slips \n161\n and elevator \n129\n, with a stick-up of about one meter.', 'The TDA \n202\n and LSA \n228\n are open in THP position \n207\n (tubular \n111\n delivered from WC \n203\n to THP \n207\n).', 'The UTC \n242\n and LTC \n244\n are closed on the tubular \n111\n in the THP \n207\n.', 'The TBR \n254\n and SGA \n262\n are empty, on the way from the FIB \n166\n to get a new tubular \n111\n in the THP \n207\n.', 'Example steps of the trip-out sequence may be as set forth below in Table 2B.\n \n \n \n \n \n \n \n \nTABLE 2B\n \n \n \n \n \n \n \n \nTripping-Out Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nOpen slips 161 and\n \nVisual/\n \nElevator 129 must be\n \nSlips 161 Open is\n \nSlips 161 to\n \n \n \n \n \nhoist to upper stop:\n \nCCTV\n \nclosed before opening\n \nnot selectable if\n \nOpen state.', 'Verify that elevator 129\n \n \nslips 161.', 'elevator 129 is not\n \nSettings:\n \n \n \n \n \nis closed.\n \n \n \nclosed.', 'DW 119\n \n \n \n \n \nOpen slips 161\n \n \n \nThe slips 161\n \nhoisting\n \n \n \n \n \n(command).', 'Open command is\n \nspeed and\n \n \n \n \n \nHoist to take weight\n \n \n \nreset after a set time\n \nmaximum\n \n \n \n \n \nand verify slips 161\n \n \n \nif the slips 161 are\n \noverpull.', 'opening.\n \n \n \nnot opened.\n \n \n \n \n1.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA 262\n \n \nTBR 254 and\n \n \n \n \nHandler\n \npick up next tubular 111\n \nCCTV\n \nopen.', 'SGA 262 grips/\n \n \n \n \n \nfrom THP 207:\n \n \n \n \nguides to Closed\n \n \n \n \n \nTBR 254 and SGA 262\n \n \n \n \nstate.', 'move to tubular 111 in\n \n \n \n \n \n \n \n \n \nTHP 207.', 'Close TBR 254 and\n \n \n \n \n \n \n \n \n \nSGA 262 guides/clamps\n \n \n \n \n \n \n \n \n \non tubular 111.\n \n \n \n \n \n \n \n1.2.', 'Pipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA 262\n \nUTC 242 and LTC 244\n \nUTC 242 and\n \n \n \n \nHandler\n \nopen and retract:\n \nCCTV\n \nclosed on tubular 111\n \nopen and retract.', 'LTC 244 to Open\n \n \n \n \n \nUTC 242 and LTC\n \n \nin THP 207.\n \n \nstate - retracted.', '244 open.', 'UTC 242 and LTC\n \n \n \n \n \n \n \n \n \n244 retract from THP\n \n \n \n \n \n \n \n \n \n207.\n \n \n \n \n \n \n \n1.3.', 'Pipe\n \nTBR 254 and SGA 262', 'Visual/\n \nValid FIB 166 position\n \nTBR 254 and SGA\n \nTBR 254 load.', 'Handler\n \nmove toward FIB 166\n \nCCTV\n \nselected.', '262 will follow\n \n \n \n \n \n \nwith tubular 111:\n \n \n \npredefined path.', 'Lift tubular 111 from\n \n \n \nFIB 166 latches will\n \n \n \n \n \n \nTHP 207.', 'open when tubular 111\n \n \n \n \n \n \nMove to selected\n \n \n \nis outside selected FIB\n \n \n \n \n \n \nposition in FIB 166.\n \n \n \n166 row.', 'FIB 166 latches will\n \n \n \n \n \n \n \n \n \nclose prior to setting\n \n \n \n \n \n \n \n \n \ndown the tubular 111.', 'Set down tubular 111\n \n \n \n \n \n \n \n \n \non selected position.', '1.4.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \n \nTDA 202 retract to\n \nTDA 202 load\n \n \n \n \nHandler\n \nmove to WC 203:\n \nCCTV\n \n \nvertical, hoist, and\n \nindication.', 'TDA 202 move to WC\n \n \n \nrotate, extend to WC\n \n \n \n \n \n \n203.\n \n \n \n203 at about two\n \n \n \n \n \n \nLSA 228 move to WC\n \n \n \nmeters below stick-up.', '203.', 'TDA 202 and LSA\n \n \n \n \n \n \n \n \n \n228 will stop/wait\n \n \n \n \n \n \n \n \n \noutside WC 203 area\n \n \n \n \n \n \n \n \n \nif TD 116 is moving.', '1.5.\n \nPipe\n \nMove RN 151 to WC\n \n \nRN 151 tongs open.', 'RN 151 will move to\n \nTJ (Stick-up)\n \n \n \n \nHandler\n \n203:\n \n \nWC 203 selected.', 'WC 203.', 'assist indication.', 'Verify TD 116 is\n \n \n \nElevate RN 151 to\n \n \n \n \n \n \nhoisted above RN 151\n \n \n \nstick-up.\n \n \n \n \n \n \nworking area.', 'RN 151 will stop/\n \n \n \n \n \n \nStart 151 RN break-\n \n \n \nwait outside WC 203\n \n \n \n \n \n \nout sequence to move\n \n \n \narea if TD 116 is\n \n \n \n \n \n \nRN 151 to WC 203.\n \n \n \nmoving.', '2.\n \nDriller\n \nSet slips 161:\n \nVisual/\n \n \n \nDW 119 upper\n \n \n \n \n \nVerify required stick-up\n \nCCTV\n \n \n \nstop setting.', 'height.', 'Set slips 161\n \n \n \n \n \n \n \n \n \n(command).', 'Set off weight.\n \n \n \n \n \n \n \n2.1.', 'Pipe\n \nTDA 202 close and LSA\n \nVisual/\n \nSlips 161 closed.', 'TDA 202 and LSA 228\n \nTDA 202 to\n \n \n \n \nHandler\n \n228 guide close:\n \nCCTV\n \n \nwill not close in WC\n \nClosed state.', 'Verify TDA 202 and\n \n \n \n203 if slips 161 are not\n \nTDA 202 and\n \n \n \n \n \nLSA 228 at WC 203.\n \n \n \nclosed.', 'LSA 228 in WC\n \n \n \n \n \nClose TDA 202.\n \n \n \n \n203.', 'Close LSA 228 guide\n \n \n \n \nLSA 228 guide\n \n \n \n \n \nfunnel.\n \n \n \n \nfunnel to Closed\n \n \n \n \n \n \n \n \n \nstate.', '2.2.\n \nPipe\n \nRN 151 break-out and\n \nCCTV\n \nSlips 161 closed.', 'Break-out and spin-\n \nRN 151\n \n \n \n \nHandler\n \nspin-out:\n \n \n \nout.', 'Double break-out\n \nindication.', 'Verify slips 161 closed\n \n \n \navailable if required.\n \n \n \n \n \n \nand weight set off.', 'Open RN 151\n \n \n \n \n \n \nAdjust RN 151\n \n \n \nspinner, guide, and\n \n \n \n \n \n \nelevation if required.\n \n \n \nclamps.', 'Continue RN 151\n \n \n \nReturn RN 151 to\n \n \n \n \n \n \nsequence.', 'park position.', 'RN 151 may wait in\n \n \n \n \n \n \n \n \n \nWC 203 until TDA 202\n \n \n \n \n \n \n \n \n \nhas lifted tubular 111.', '3.\n \nDriller\n \nOpen TD elevator 129,\n \nVisual/\n \nTDA 202 closed.', 'TD elevator\n \n \n \n \n \nretract, and lower:\n \nCCTV\n \nSlips 161 closed.', '129 to Closed\n \n \n \n \n \nVerify TDA 202 is\n \n \n \n \nstate.\n \n \n \n \n \nclosed.', 'TD 116\n \n \n \n \n \nOpen TD elevator 129\n \n \n \n \nretracted\n \n \n \n \n \nand retract.\n \n \n \n \nposition.', 'Lower TD 116 (e.g., to\n \n \n \n \n \n \n \n \n \nrig floor 114.\n \n \n \n \n \n \n \n3.1.', 'Pipe\n \nTDA 202 lift tubular 111\n \nVisual/\n \nRN 151 finished\n \nTDA 202 will hoist\n \nTDA 202 load\n \n \n \n \nHandler\n \nout of stick-up:\n \nCCTV\n \nspin-out, RN 151\n \nabout two meters\n \nindication.', 'Hoist TDA 202 to pick\n \n \nBUT is open.', 'before lifting tubular\n \nLSA 228\n \n \n \n \n \nup weight.', 'TD 116 retracted.\n \n111.\n \ncentralizer.', 'LSA 228 centralizer\n \n \n \nTubular 111 is lifted\n \n \n \n \n \n \nwill close on tubular 111\n \n \n \ncarefully.', 'Lifting is\n \n \n \n \n \n \nabove stick-up.', 'stopped if tubular\n \n \n \n \n \n \nRN 151 may return to\n \n \n \n111 is catching on\n \n \n \n \n \n \npark position when\n \n \n \nthreads in TJ.', 'tubular 111 is lifted.', 'LSA 228 centralizer\n \n \n \n \n \n \n \n \n \ncloses after lifted\n \n \n \n \n \n \n \n \n \nabove the box.\n \n \n \n \n3.2.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTDA 202 closed.', 'TDA 202 will retract\n \nTDA 202 load\n \n \n \n \nHandler\n \nmove tubular 111 to\n \nCCTV\n \nLTC 244 closed when\n \nto vertical position\n \nindication.', 'THP 207:\n \n \ntubular 111 is below\n \nabove MOH (or rig\n \nTDA 202 and\n \n \n \n \n \nTDA 202 and LSA 228\n \n \nLTC 244.\n \nfloor 114), then rotate,\n \nLSA 228\n \n \n \n \n \nmove toward THP 207.\n \n \n \nlower, and extend to\n \nposition.', 'LTC 244 extends to\n \n \n \nTHP 207.', 'LSA 228\n \n \n \n \n \nTHP 207 and closes\n \n \n \nTDA 202 will slow\n \nextend.\n \n \n \n \n \nguide when tubular is\n \n \n \ndown above THP\n \nLTC 244 to\n \n \n \n \n \nclose to THP 207.\n \n \n \n207.', 'Closed state.\n \n \n \n \n \nSet down tubular at\n \n \n \nLTC 244 is extended\n \n \n \n \n \n \nTHP 207.\n \n \n \nand closed.', 'Wash and dope pin if\n \n \n \nLSA 228 is open.\n \n \n \n \n \n \npreselected.\n \n \n \n \n \n \n \n3.3.', 'Pipe\n \nUTC 242 extend to THP\n \nVisual/\n \nTDA 202 and LSA 228\n \nUTC 242 extend to\n \nUTC 242 and\n \n \n \n \nHandler\n \n207 and close.', 'CCTV\n \nin THP 207 with tubular\n \nTHP 207.', 'LTC 244 to\n \n \n \n \n \n \n \n111.', 'UTC 242 guide\n \nclosed state.', 'close.', '4.\n \nDriller\n \nExtend TD 116 and\n \nVisual\n \nRN 151 parked.', 'Elevator 129\n \n \n \n \n \nlatch elevator 129:\n \n \n \n \nClosed state.', 'Extend TD 116 to WC\n \n \n \n \nIndicate TD\n \n \n \n \n \n203.\n \n \n \n \n116 in WC 203.', 'Latch elevator 129\n \n \n \n \n \n \n \n \n \n(automatic close on\n \n \n \n \n \n \n \n \n \nimpact).', '5.\n \nDriller\n \nCheck trip tank volume,\n \nVisual\n \n \nTrip tank gain/loss is\n \nTrip sheet/\n \n \n \n \n \nGain/Loss:\n \n \n \ndetermined and\n \nvolume control.', 'Determine trip tank\n \n \n \ndisplayed.', 'gain/loss.', 'Repeat all steps for\n \n \n \n \n \n \n \n \n \nnext tubular 111.', 'Continue on step 1.\n \n \n \n \n \n \n \n5.1.', 'Pipe\n \nTDA 202 open and\n \nVisual/\n \nUTC 242 closed.', 'TDA 202 to\n \n \n \n \nHandler\n \nretract from THP 207:\n \nCCTV\n \n \n \nOpen state.', 'Verify UTC 242 and\n \n \n \n \n \n \n \n \n \nLTC 244 are closed.', 'Open TDA 202.', 'Open LSA 228 guide\n \n \n \n \n \n \n \n \n \nfunnel.', 'Continue on step 1.4.\n \n \n \n \n \n \n \n5.2.', 'Pipe\n \nTBR 254 and SGA 262\n \n \nUTC 242 and LTC 244\n \nTBR 254 clamp and\n \nTBR 254 clamp\n \n \n \n \nHandler\n \nmove to THP 207:\n \n \nclosed on tubular 111.\n \nguide and SGA 262\n \nand guide and\n \n \n \n \n \nOpen TBR 254 and\n \n \n \nguide will open.', 'SGA 262 guide\n \n \n \n \n \nSGA 262.', 'TBR 254 will hoist\n \nto Open state.', 'Move TBR 254 and\n \n \n \nbefore it retracts out of\n \n \n \n \n \n \nSGA 262 toward THP\n \n \n \nFIB 166.', '207/next tubular.', 'Continue step 1.1.', 'When a drilling connection is to be made, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth above in Table 1A. The well construction system \n100\n, \n200\n can then be set-up for making the drilling connection.', 'Examples of such set-up may be as set forth below in Table 3A.\n \n \n \n \n \n \n \n \nTABLE 3A\n \n \n \n \n \n \n \n \nDrilling Connection Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nDriller/\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nPipe\n \ncompleted pre-checks and deactivated\n \nscreen.', 'TBR 254,\n \nHandler\n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nSGA 262,\n \n \nequipment.', 'Program setup\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \nwizard.', 'LTC 244,\n \n \ntouchscreen 522, 524.', 'After startup: Check\n \n \n \nITC 236,\n \n \nSelect Drilling Connection mode.', 'for green light in\n \n \n \nTHP 207,\n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \nTDA 202,\n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \nLSA 228,\n \n \nSelect slot, direction for picking pipe.', 'header on front\n \n \n \nRN 151\n \n \nSelect pipe type.', 'screen 532, 534,\n \n \n \n \n \nSelect RN 151 to use in the operations.', '536.', 'Select RN 151 as back-up only (only\n \n \n \n \n \nselectable for THT).', 'RN 151 MU torque.', 'Select pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nDW 119,\n \n \ncompleted pre-checks and deactivated\n \nscreen.', 'MP 144\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \n \n \nequipment.', 'Program setup\n \n \n \n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Drilling mode.', 'for green light in\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \n \n \nStick-up target.', 'header on front\n \n \n \n \n \nSet DW 119 upper/lower stops.', 'screen 532, 534,\n \n \n \n \n \nSet relevant Autodriller parameters\n \n536.', '(ROP, WOB, delta-P, torque, etc.)\n \n \n \n \n \nVerify correct TD 116 make-up torque\n \n \n \n \n \nsetting.', 'Assign TD 116 rotation to armrest\n \n \n \n \n \ncontrol 514, 515, 516.', 'Verify/set TD 116 ramp parameters.', 'Verify correct drilling torque setting.', 'Verify liner size setting and pump\n \n \n \n \n \nefficiency.', 'Verify MP 144 pressure limit setting.', 'Assign pumps to MP 144 master slider.', 'Verify/set MP 144 ramp-up parameters.', 'Verify active tanks are selected and\n \n \n \n \n \nlined up.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in\n \nVerify operator\n \n \n \nmachines\n \n \nzone management system and tubular\n \nscreen, system\n \n \n \n \n \ninterlock system.\n \nsettings.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example drilling connection sequence may start with the drill string \n120\n drilled all the way down, reaming, survey, up/down weights, etc., performed according to drilling program.', 'A tubular \n111\n to be added to the drill string \n120\n and in the TDA \n202\n/LSA \n228\n is lifted from stick-up level above the MOH \n204\n.', 'The THP \n207\n is empty, and the UTC \n242\n and LTC \n244\n are open and retracted.', 'The TBR \n254\n and SGA \n262\n are empty, on the way to pick a new tubular \n111\n from the FIB \n166\n.', 'Example steps of the drilling connection sequence may be as set forth below in Table 3B.\n \n \n \n \n \n \n \n \nTABLE 3B\n \n \n \n \n \n \n \n \nDrilling Connection Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nSet slips 161:\n \nVisual\n \n \n \nSlips 161 to\n \n \n \n \n \nVerify MPs 144 are\n \n \n \n \nClosed state.\n \n \n \n \n \nstopped and torque is\n \n \n \n \nDW 119 hook\n \n \n \n \n \nreleased from drill\n \n \n \n \nload.', 'string 120.\n \n \n \n \nTD 116 torque\n \n \n \n \n \nSet slips 161 at\n \n \n \n \nrelease.', 'required stick-up\n \n \n \n \n \n \n \n \n \nheight.', 'Set off weight.', '2.\n \nDriller\n \nTD 116 break-out\n \nVisual\n \nSlips 161 must be\n \nTD 116 Break-Out\n \nTD 116 thread\n \n \n \n \n \nconnection:\n \n \nclosed before TD 116\n \nfunction will activate\n \ncompensator\n \n \n \n \n \nVerify slips 161 are\n \n \nBUT Break-Out\n \nthe clamp and\n \nindication.', 'closed.', 'function is available.', 'increase the torque to\n \nTD 116 not\n \n \n \n \n \nBreak-out connection\n \n \n \nbreak the connection.', 'connected.', '(joystick button +\n \n \n \nTD 116 break-out\n \nTD 116 Break-\n \n \n \n \n \njoystick).\n \n \n \nwill activate the TD\n \nOut function-\n \n \n \n \n \nDeactivate break-out\n \n \n \n116 thread\n \njoystick button-\n \n \n \n \n \nbutton when\n \n \n \ncompensator and\n \npush and hold.', 'connection is broken\n \n \n \npipe handler lock.', 'Clamp on/\n \n \n \n \n \n(torque dropping and', 'When connection is\n \nbreak-out may\n \n \n \n \n \nshaft rotating).', 'broken, release\n \nbe operated\n \n \n \n \n \n \n \n \nbutton.', 'The torque will\n \nseparately on\n \n \n \n \n \n \n \n \nbe released and\n \ntouch screen\n \n \n \n \n \n \n \n \nbackup clamp (BUC)\n \n522, 524.\n \n \n \n \n \n \n \n \nopened.', 'TD 116 torque\n \n \n \n \n \n \n \n \nDW 119 is\n \ndropping and\n \n \n \n \n \n \n \n \ninterlocked from\n \nshaft rotating.', 'hoisting when the\n \n \n \n \n \n \n \n \n \nBUC is closed.', '3.\n \nDriller\n \nTD 116 spin-out:\n \nVisual\n \nSlips 161 must be\n \nSpin-Out will\n \nTD 116 thread\n \n \n \n \n \nVerify break-out is\n \n \nclosed.', 'activate the TD 116\n \ncompensator\n \n \n \n \n \ncompleted.', 'Break-Out not\n \nthread compensator\n \nindication.', 'Spin-out.', '(Direct\n \n \nactive.\n \nsystem.\n \n \n \n \n \n \ncontinue from break-\n \n \nBUC open.', 'Spin-Out function\n \n \n \n \n \n \nout)', '.', 'will spin-out per\n \n \n \n \n \n \nHoist out of stick-up.\n \n \n \nsettings.', 'Deactivate TD 116\n \n \n \n \n \n \n \n \n \nthread compensator.', '4.\n \nDriller\n \nRetract and move TD\n \nVisual/\n \nHoisting will be\n \nTD 116 pipe handler\n \nIndicate upper\n \n \n \n \n \n116 to connection\n \nCCTV\n \nstopped if TD 116 is\n \nhas pre-set position\n \nstop position.', 'height:\n \n \nretracted and links\n \nfacing TDA 202.', 'Link tilt\n \n \n \n \n \nVerify TD 116 is\n \n \ntilted to parked\n \n \nposition.', 'above stick-up.\n \n \nposition.', 'Retract TD 116 and\n \n \n \n \n \n \n \n \n \nactivate link tilt float.', 'Hoist TD 116 to\n \n \n \n \n \n \n \n \n \ntubular 111 connection\n \n \n \n \n \n \n \n \n \nheight (upper stop).', '4.1.\n \nPipe\n \nMove RN 151 to WC\n \n \nOnly possible with\n \nRN 151 will move to\n \nTJ assist\n \n \n \n \nHandler\n \n203:\n \n \nTHT.', 'If THA is used,\n \nWC 203.\n \nindication.', 'Verify TD 116 is\n \n \nthen wait for tubular\n \nElevate to stick-up.\n \n \n \n \n \n \nhoisted above RN 151\n \n \n111 located above\n \n \n \n \n \n \n \nworking area.', 'stick-up.', 'Start RN 151 make-\n \n \nRN 151 tongs open.', 'up', 'sequence to move\n \n \nWC 203 selected.', 'RN 151 to WC 203.\n \n \n \n \n \n \n \n4.2.', 'Pipe\n \nTDA 202 move tubular\n \nVisual/\n \nTD 116 retracted.', 'Tilt towards WC\n \nTDA 202 Load\n \n \n \n \nHandler\n \n111 to WC 203:\n \nCCTV\n \n \n203.\n \nindication.', 'Continue to lift TDA\n \n \n \nTDA 202 dope top\n \n \n \n \n \n \n202 and extend to WC\n \n \n \nbox.\n \n \n \n \n \n \n203 (above stick-up).', 'LSA 228 guide to WC\n \n \n \n \n \n \n \n \n \n203 when pin end\n \n \n \n \n \n \n \n \n \nabove rig floor 114.', '4.3.\n \nPipe\n \nGuide tubular 111 with\n \nCCTV\n \nTubular 111 held by\n \nClose RN 151 BUT.', 'Stabbing\n \n \n \n \nHandler\n \nRN 151 in WC 203:\n \n \nTDA 202/LSA 228\n \nClose stabbing\n \nguide closed\n \n \n \n \n \nVerify tubular 111 is\n \n \nabove stick-up in WC\n \nguide.', 'indication.\n \n \n \n \n \nlocated in WC 203.\n \n \n203.\n \n \nBUT closed\n \n \n \n \n \nAdjust RN 151\n \n \n \n \nindication.\n \n \n \n \n \nelevation if required.', 'Continue RN 151\n \n \n \n \n \n \n \n \n \nsequence.', '4.4.\n \nPipe\n \nTDA 202 lower to stab\n \nVisual/\n \nRN 151 in WC 203\n \nContinue lowering\n \nTDA load\n \n \n \n \nHandler\n \ntubular 111 in stick-up:\n \nCCTV\n \nwith stabbing guide\n \nabout two meters\n \nindication\n \n \n \n \n \nLower tubular 111 to\n \n \nclosed.', 'after verifying set of\n \n(unloading).', 'stab into stick-up.\n \n \n \nweight (to allow room\n \n \n \n \n \n \nContinue lowering\n \n \n \nfor TD 116 to latch on\n \n \n \n \n \n \nabout two meters after\n \n \n \ntop).', 'stabbing complete.', 'LSA 228 open and\n \n \n \n \n \n \n \n \n \nretract when RN 151\n \n \n \n \n \n \n \n \n \nstabbing guide closed\n \n \n \n \n \n \n \n \n \non tubular 111.', '4.5.', 'Pipe\n \nRN 151 back-up (pre-\n \nVisual/\n \nTubular 111 stabbed\n \nOption:\n \nTorque log\n \n \n \n \nHandler\n \nselected):\n \nCCTV\n \nin stick-up.', 'Spin-in and make-up\n \nupdated.', 'Option: Spin-in and\n \n \nTDA 202 unloaded.\n \nconnection.', 'MU torque\n \n \n \n \n \nmake-up with RN 151:\n \n \n \nOpen spinner,\n \npresented to\n \n \n \n \n \nRN 151 BUT will stay\n \n \n \nguide, and clamps.\n \ndriller.', 'on for back-up.\n \n \n \nReturn to park\n \n \n \n \n \n \nOption: Make-Up with\n \n \n \nposition.', 'RN 151:\n \n \n \n \n \n \n \n \n \nContinue RN 151\n \n \n \n \n \n \n \n \n \nsequence to spin-in\n \n \n \n \n \n \n \n \n \nand make-up.', '5.\n \nDriller\n \nExtend TD 116 to WC\n \nVisual/\n \nTDA 202 below TJ.', 'Indicate TD\n \n \n \n \n \n203:\n \nCCTV\n \n \n \n116 in WC 203.', 'Extend TD 116 to WC\n \n \n \n \nLink tilt.\n \n \n \n \n \n203.', 'Deactivate link tilt\n \n \n \n \n \n \n \n \n \nfloat.', 'Tilt elevator 129 to\n \n \n \n \n \n \n \n \n \nparked position.', '6.\n \nDriller\n \nTD 116 spin-in (both\n \nVisual/\n \nTD 116 in WC 203.\n \nSpin-in with spin-in\n \nThread\n \n \n \n \n \nconnections):\n \nCCTV\n \nTHT/DPT BUC on.\n \nsettings (RPM/\n \ncompensator\n \n \n \n \n \nVerify RN 151/THT\n \n \n \ntorque).', 'indication (mid\n \n \n \n \n \nBUT closed.', 'Spin-in will activate\n \nstroke).', 'Activate TD 116 spin-\n \n \n \nthe TD 116 thread\n \n \n \n \n \n \nin.\n \n \n \ncompensator system.', 'Lower TD 116 to stab\n \n \n \n \n \n \n \n \n \nand spin-in.', 'Optional: Lower\n \n \n \n \n \n \n \n \n \nconnection made-up by\n \n \n \n \n \n \n \n \n \nRN 151: See step 7.\n \n \n \n \n \n \n \n7.\n \nDriller\n \nTD 116 make-up (both\n \nVisual/\n \nTD 116 spin-in\n \nTD 116 Make-up\n \nRN 151 BUC\n \n \n \n \n \nconnections):\n \nCCTV\n \ncompleted.\n \nfunction will change\n \non.', 'Verify TD 116 spin-in\n \n \nTHT BUT closed.', 'TD 116 torque to set\n \nTD 116 make-\n \n \n \n \n \nfunction is finished.\n \n \n \nmake-up torque.', 'up torque.\n \n \n \n \n \nMake-up the\n \n \n \nRelease torque\n \nTD 116/RN\n \n \n \n \n \nconnection(s) (joystick\n \n \n \nwhen button is\n \n151 torque log\n \n \n \n \n \nbutton + joystick).\n \n \n \nreleased and joystick\n \nupdated (both\n \n \n \n \n \nRelease button when\n \n \n \nto center.', 'connections).', 'make-up torque is\n \n \n \nDW 119 is\n \nTD 116\n \n \n \n \n \nreached.', 'interlocked from\n \nconnected state\n \n \n \n \n \n \n \n \nhoisting when RN 151\n \nwhen make-up\n \n \n \n \n \n \n \n \nBUC is closed.', '(Rig\n \ntorque is\n \n \n \n \n \n \n \n \ntong or slips 161 may\n \nreached.\n \n \n \n \n \n \n \n \nbe used as backup\n \nMake-up\n \n \n \n \n \n \n \n \nper setting).', 'function may be\n \n \n \n \n \n \n \n \nTD 116 thread\n \noperated\n \n \n \n \n \n \n \n \ncompensator system\n \nmanually from\n \n \n \n \n \n \n \n \nis deactivated.', 'touchscreen\n \n \n \n \n \n \n \n \n \n522, 524.\n \n \n \n8.\n \nDriller\n \nOption: TD 116 spin-in\n \nVisual/\n \nTD 116 in WC 203.', 'Spin-in with spin-in\n \nThread\n \n \n \n \n \nupper connection\n \nCCTV\n \nRN 151 finished/\n \nsettings (RPM/\n \ncompensator\n \n \n \n \n \n(lower connection\n \n \nopen (retracted).\n \ntorque).', '(mid stoke).', 'made-up by RN 151):\n \n \n \nSpin-in will activate\n \n \n \n \n \n \nVerify RN 151/THT\n \n \n \nthe TD 116 thread\n \n \n \n \n \n \nfinished (tubular 111\n \n \n \ncompensator system.\n \n \n \n \n \n \nconnected).', 'Activate TD 116 Spin-\n \n \n \n \n \n \n \n \n \nin.', 'Lower TD 116 to stab\n \n \n \n \n \n \n \n \n \nand spin-in.\n \n \n \n \n \n \n \n9.\n \nDriller\n \nOption: TD 116 make-\n \nVisual/\n \nRN 151 make-up\n \nTD 116 make-up will\n \nTD 116 BUC\n \n \n \n \n \nup upper connection\n \nCCTV\n \nfinished.', 'automatically activate\n \non.', '(lower connection\n \n \nTD 116 spin-in\n \npipe handler lock,\n \nTD 116 MU\n \n \n \n \n \nmade-up by RN 151):\n \n \nfinished.', 'close the TD 116\n \ntorque.', 'Verify TD 116 spin-in\n \n \nClamp on - make-\n \nBUC, and increase\n \nTD 116 torque\n \n \n \n \n \nis finished.', 'up available from\n \nTD 116 torque to set\n \nupdated.\n \n \n \n \n \nMake-up connection\n \n \ntouch panel 522, 524\n \nmake-up torque.', 'TD 116\n \n \n \n \n \n(joystick button +\n \n \nwithout spin-in.', 'Release button (and\n \nConnected\n \n \n \n \n \njoystick).\n \n \n \njoystick to center) to\n \nstate when MU\n \n \n \n \n \nRelease button when\n \n \n \nopen BUC and\n \ntorque is\n \n \n \n \n \nmake-up torque is\n \n \n \nrelease torque.\n \nreached.\n \n \n \n \n \nreached.', 'DW 119 is\n \nTD 116 MU\n \n \n \n \n \n \n \n \ninterlocked from\n \nmaybe\n \n \n \n \n \n \n \n \nmoving when BUC is\n \noperated\n \n \n \n \n \n \n \n \nclosed.', 'manually on\n \n \n \n \n \n \n \n \nTD thread\n \ntouchscreen\n \n \n \n \n \n \n \n \ncompensator system\n \n522, 524.\n \n \n \n \n \n \n \n \nis deactivated.', '9.1.\n \nPipe\n \nTDA 202 open and\n \n \nTD 116 spin-in\n \nTDA 202 will tilt to\n \nTDA 202 to\n \n \n \n \nHandler\n \nmove to THP 207:\n \n \nfinished.', 'vertical, rotate to face\n \nOpen state.', 'Verify TD 116 is\n \n \n \ntoward THP 207, and\n \n \n \n \n \n \nconnected.', 'lower to pick up next\n \n \n \n \n \n \nOpen TDA 202.', 'tubular 111.\n \n \n \n \n \n \nRetract and rotate\n \n \n \n \n \n \n \n \n \nTDA 202 towards THP\n \n \n \n \n \n \n \n \n \n207.\n \n \n \n \n \n \n \n10.', 'Driller\n \nOpen slips 161:\n \nVisual/\n \nTD 116 connected.', 'Slips 161 to\n \n \n \n \n \nOpen slips 161.\n \nCCTV\n \n \n \nOpen state.', 'Hoist to open slips\n \n \n \n \nDW 119 hook\n \n \n \n \n \n161.\n \n \n \n \nload.', '11.', 'Driller\n \nContinue drilling per\n \nVisual\n \nSlips 161 open.', 'IBOP to Open\n \n \n \n \n \ndrilling program:\n \n \n \n \nstatus.', 'Open IBOP.', 'TD 116 RPM.\n \n \n \n \n \nContinue drilling per\n \n \n \n \nTD 116\n \n \n \n \n \ndrilling program.\n \n \n \n \ntorque.', 'MP 144\n \n \n \n \n \n \n \n \n \nstrokes per\n \n \n \n \n \n \n \n \n \nminute (SPM).', 'Standpipe\n \n \n \n \n \n \n \n \n \npressure.\n \n \n \n11.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA\n \nTBR 254 will move\n \nTBR 254 and\n \n \n \n \nHandler\n \npick up new tubular\n \nCCTV\n \n262 grip/guide open.\n \ninto FIB 166 elevated\n \nSGA 262 grip/\n \n \n \n \n \n111:\n \n \nSelected FIB 166\n \nabove open latches.\n \nguide to Closed\n \n \n \n \n \nMove TBR 254 and\n \n \nposition is “valid.”\n \nAdjustments\n \nstate.\n \n \n \n \n \nSGA 262 to selected\n \n \n \navailable.', 'finger/slot in FIB 166.', 'TBR 254 and SGA\n \n \n \n \n \n \nClose guides and\n \n \n \n262 grip/guide will\n \n \n \n \n \n \nclamp on tubular 111.\n \n \n \nclose.', '11.2.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTHP 207 empty.', 'TBR 254 cannot\n \nIndicate open\n \n \n \n \nHandler\n \nmove tubular 111 to\n \nCCTV\n \nUTC 242 and LTC\n \nopen with weight.', 'FIB 166 latches.', 'THP 207:\n \n \n244 are open.', 'TBR 254 gripper\n \nTBR 254 load\n \n \n \n \n \nOpen FIB 166 latches\n \n \nCorrect pipe\n \nopen when unloaded.\n \nindication.', 'for selected row.\n \n \ndetected in TBR 254\n \nFIB 166 latches will\n \n \n \n \n \n \nVerify latches open\n \n \nand SGA 262.\n \nnot open with TBR\n \n \n \n \n \n \n(visual/CCTV).', '254 head in low\n \n \n \n \n \n \nTBR 254 lifts tubular\n \n \n \nposition.\n \n \n \n \n \n \n111 and moves to THP\n \n \n \n \n \n \n \n \n \n207.', 'FIB 166 latches will\n \n \n \n \n \n \n \n \n \nclose as the tubular\n \n \n \n \n \n \n \n \n \n111 moves out of FIB\n \n \n \n \n \n \n \n \n \n166.', 'Set down tubular in\n \n \n \n \n \n \n \n \n \nTHP 207.', 'Wash and dope pin if\n \n \n \n \n \n \n \n \n \npreselected.', '11.3.', 'Pipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nextend to THP 207 and\n \nCCTV\n \n262 with tubular in\n \n244 extend and close.', 'LTC 244 to\n \n \n \n \n \nclose.', 'THP 207.\n \n \nClosed state.\n \n \n \n11.4.', 'Pipe\n \nTBR 254 and SGA 262\n \n \nUTC 242 and LTC\n \n \n \n \n \n \nHandler\n \nopen and move toward\n \n \n244 closed on tubular\n \n \n \n \n \n \n \nFIB 166:\n \n \n111.', 'Open TBR 254\n \n \n \n \n \n \n \n \n \nclamps and guide and\n \n \n \n \n \n \n \n \n \nSGA 262 guide.', 'Move toward FIB 166/\n \n \n \n \n \n \n \n \n \nnext tubular 111.', 'It is noted that the example drilling connection sequence set forth above describes the RN \n151\n and THT used as the BUT for the TD \n116\n during make-up, as well as the option of making-up the lower connection with the RN \n151\n and the upper connection with the TD \n116\n.', 'Different combinations of the aspects described above may also be utilized for building stands of two or more tubulars \n111\n.', 'Such stand building may be performed during drilling and other operations performed at WC \n203\n.', 'Such simultaneous operations, however, are coordinated to avoid conflicts and obstructions between the different machines and systems.', 'For example, the elevator of the TDA \n202\n may have two different sizes of inserts to permit building casing stands while drilling.', "The change of head size may be done remote from the Pipe Handler's workstation \n450\n (or \n452\n or \n454\n).", 'When a stand building operation is to be performed, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth below in Table 4A.\n \n \n \n \n \n \n \n \nTABLE 4A\n \n \n \n \n \n \n \n \nStand Building Preparations\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nCatwalk\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n(CW) 131\n \nrig floor 114.', 'Feeding table (FT) indexer pins.', 'FIB 166\n \nPipe Handler\n \nStands in FIB 166 slots per HMI.', 'Fingers closed.', 'Travel path is unobstructed.', 'TBR 254\n \nPipe Handler\n \nTravel path is unobstructed.', 'SGA 262\n \nPipe Handler\n \nTravel path is unobstructed.', 'LTC 244\n \nOperator 195 on\n \nTravel path is unobstructed.', 'ITC 236\n \nrig floor 114.', 'Dies are clean and not worn.', 'UTC 242\n \n \n \nTHP\n \nOperator 195 on\n \nTravel path is unobstructed.', 'Doper 209\n \nrig floor 114.', 'Water and correct dope available for doper 209.', 'LSA 228\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'TDA 202\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Correct dope is available for associated doper 209.', 'Correct inserts installed.', 'RN 151:\n \nOperator 195 on\n \nDPT is assembled.', 'THA-DPT\n \nrig floor 114.', 'Dies are clean and not worn.', 'Travel path is unobstructed.', 'Tubulars\n \nOperator 195 on\n \nTubular 111 to be loaded on FT.\n \n \n \n111\n \nrig floor 114.', 'Tubulars 111 to be cleaned and doped, protectors removed.', 'The well construction system \n100\n, \n200\n can then be set-up for the stand building operation.', 'Examples of such set-up may be as set forth below in Table 4B.\n \n \n \n \n \n \n \n \nTABLE 4B\n \n \n \n \n \n \n \n \nStand Building Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'TBR 254,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nSGA 262,\n \n \nequipment.', 'Program setup\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \nwizard.', 'LTC 244,\n \n \ntouchscreen 522, 524.', 'After startup: Check\n \n \n \nITC 236,\n \n \nSelect Stand Building mode.', 'for green light in\n \n \n \nTHP 207,\n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \nTDA 202,\n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \nLSA 228,\n \n \nSelect slot, direction for racking stands\n \nheader on front\n \n \n \nRN 151,\n \n \n111.\n \nscreen 532, 534,\n \n \n \nCW 131\n \n \nSelect pipe size/type.\n \n536.', 'Select RN 151 (with THA) to use in the\n \n \n \n \n \noperations.', 'RN 151 MU torque.', 'Perform pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'All\n \nPipe\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \nHandler\n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nAll tubulars 111 to be registered in\n \n \n \n111\n \nHandler\n \nelectronic tally system.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example stand building sequence may start with the MOH \n204\n and THP \n207\n empty, the ITC \n236\n retracted, and the CW \n131\n feeding table pre-loaded with tubulars (perhaps already cleaned and doped).', 'Example steps of the stand building sequence may be as set forth below in Table 4C.', 'In such example, among others within the scope of the present disclosure, the pipe handling equipment may be operated automatically via the Construction Program, and the step execution of the pipe handling equipment may be controlled automatically by one or two operators \n195\n at the associated workstation(s) \n450\n, \n452\n, \n454\n.', 'The Construction Program may also feature configurable step confirmations.', 'The stand building sequence controlled by the Construction Program may be stopped or interrupted at any time, and some or all functions may be operated manually by the one or two operators \n195\n at the associated workstation(s) \n450\n, \n452\n, \n454\n.', 'TABLE 4C\n \n \n \n \n \n \n \n \nStand Building Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nPipe\n \nLoad tubular 111 into\n \nVisual/\n \nFT pre-loaded with\n \n \n \n \n \n \nHandler\n \nthe CW 131:\n \nCCTV\n \npipe (cleaned and\n \n \n \n \n \n \n \nVerify that CW 131 is\n \n \ndoped).', 'empty and in position.', 'CWM in loading\n \n \n \n \n \n \n \nUse FT of CW 131 to\n \n \nposition.\n \n \n \n \n \n \n \nload tubular 111 into\n \n \n \n \n \n \n \n \n \nCW 131.\n \n \n \n \n \n \n \n2.\n \nPipe\n \nRun tubular 111 in CW\n \nVisual/\n \nTubular 111 loaded in\n \nRamp 149 will tilt to\n \n \n \n \n \nHandler\n \n131 to pick-up position:\n \nCCTV\n \nramp 149.\n \nrig floor 114 tubular\n \n \n \n \n \n \nVerify tubular 111 is\n \n \n \nposition.', 'loaded in ramp 149.', 'Skate 133 will move\n \n \n \n \n \n \nMove skate 133 to\n \n \n \ntowards rig floor 114.\n \n \n \n \n \n \nmove tubular 111\n \n \n \nSkate 133 will stop\n \n \n \n \n \n \ntoward pick-up\n \n \n \nwith tubular 111 box\n \n \n \n \n \n \nposition.\n \n \n \non ramp 149.\n \n \n \n \n3.\n \nPipe\n \nMove TDA 202 to pick-\n \nVisual\n \nTDA 202 open.', 'Handler\n \nup position:\n \n \n \n \n \n \n \n \n \nTilt TDA 202.\n \n \n \n \n \n \n \n \n \nLower and extend\n \n \n \n \n \n \n \n \n \nTDA 202 to CW 131\n \n \n \n \n \n \n \n \n \npick-up position (above\n \n \n \n \n \n \n \n \n \nTHP 207).', '4.\n \nPipe\n \nPresent tubular 111 for\n \nVisual\n \nRamp 149 in pick-up\n \nSkate 133 will move\n \nCW 131\n \n \n \n \nHandler\n \nTDA 202:\n \n \nposition.', 'forward a defined\n \nposition.', 'Run skate 133 until\n \n \nTDA 202 in pipe-\n \ndistance depending\n \n \n \n \n \n \ntubular 111 is\n \n \nreceive position.', 'on pipe size.\n \n \n \n \n \n \npositioned for TDA\n \n \n \n \n \n \n \n \n \n202.\n \n \n \n \n \n \n \n5.\n \nPipe\n \nLatch TDA 202:\n \nVisual\n \nTubular 111 is\n \nTubular interlock\n \nTDA 202\n \n \n \n \nHandler\n \nHoist TDA 202 to\n \n \npositioned correctly\n \nprevents hoisting\n \nto Closed state.', 'latch onto tubular 111.\n \n \nfor TDA 202.\n \nwithout closed TDA\n \n \n \n \n \n \nClose TDA 202.\n \n \n \n202 (above preset\n \n \n \n \n \n \n \n \n \nheight).', '6.\n \nPipe\n \nLift tubular 111 to\n \nVisual\n \nTDA 202 closed.', 'Hoisting will stop\n \nLSA 228 guide\n \n \n \n \nHandler\n \nvertical position above\n \n \nVerify LSA 228 is\n \nprior to lifting tubular\n \nto Closed state.', 'MOH 204:\n \n \npositioned to receive\n \n111 out of CW 131\n \nLSA 228\n \n \n \n \n \nVerify TDA 202 is\n \n \npipe bottom before\n \nwithout guiding.', 'centralizer to\n \n \n \n \n \nclosed.', 'hoisting.', 'LSA 228 centralizer\n \nClosed state.', 'Hoist TDA 202 to pick\n \n \nTDA 202 above LSA\n \ncloses when tubular\n \nIndicate TDA\n \n \n \n \n \nup single tubular joint\n \n \n228 operating area.\n \n111 nears vertical.', '202/LSA 228 in\n \n \n \n \n \nfrom CW 131.', 'TDA 202 and LSA\n \nMOH 204\n \n \n \n \n \nMove LSA 228 to\n \n \n \n228 will position\n \nposition.', 'preset position to\n \n \n \ntubular 111 above\n \n \n \n \n \n \nprepare for guiding.', 'MOH 204/ITC 236.', 'Before the tubular\n \n \n \n \n \n \n \n \n \n111 lower end leaves\n \n \n \n \n \n \n \n \n \nCW 131, close LSA\n \n \n \n \n \n \n \n \n \n228 funnel.', 'Dope box when pipe\n \n \n \n \n \n \n \n \n \nis vertical (If selected).', 'Continue hoisting\n \n \n \n \n \n \n \n \n \nTDA 202 until tubular\n \n \n \n \n \n \n \n \n \n111 is above MOH\n \n \n \n \n \n \n \n \n \n204.\n \n \n \n \n \n \n \n6.1.\n \nPipe\n \nSkate 133 retract to\n \nVisual/\n \n \nSkate 133 will move\n \n \n \n \n \nHandler\n \nloading position:\n \nCCTV\n \n \nto loading position.', 'Verify tubular 111 pin\n \n \n \nRamp 149 will tilt to\n \n \n \n \n \n \nend is clear of ramp\n \n \n \nloading position.', '149.', 'Move skate 133\n \n \n \n \n \n \n \n \n \ntoward FT loading\n \n \n \n \n \n \n \n \n \nposition.', '6.2.\n \nPipe\n \nCW 131 load and\n \nVisual/\n \n \nSee steps 1 and 2.\n \n \n \n \n \nHandler\n \npresent next tubular\n \nCCTV\n \n \n \n \n \n \n \n \n111:\n \n \n \n \n \n \n \n \n \nPick up next tubular\n \n \n \n \n \n \n \n \n \n111 per steps 1 and 2.\n \n \n \n \n \n \n \n7.\n \nPipe\n \nStab/position first\n \nVisual\n \nPipe bottom clear of\n \nTDA 202 is rotated\n \nIndicate LSA\n \n \n \n \nHandler\n \ntubular 111 in MOH\n \n \nCW 131.', 'when the single 111\n \n228, ITC 236,\n \n \n \n \n \n204/ITC 236:\n \n \nLSA 228 close when\n \nis lowered into the\n \nLTC 244 guide/\n \n \n \n \n \nIf THP 207 (pin)\n \n \ntubular 111 nears\n \nMOH 204 to permit\n \ngrip states.', 'doping is selected:\n \n \nvertical.', 'open and retract\n \nIndicated LSA\n \n \n \n \n \nMove single 111 to\n \n \n \noutside WC 203\n \n228, ITC 236,\n \n \n \n \n \nTHP 207.\n \n \n \narea.', 'LTC 244\n \n \n \n \n \nExtend and close\n \n \n \n \npositions.', 'LSC 228 for guiding.', 'Open and retract\n \n \n \n \n \n \n \n \n \nLSA 228.', 'Wash and dope\n \n \n \n \n \n \n \n \n \npin.', 'TDA 202 move\n \n \n \n \n \n \n \n \n \nsingle 111 to ITC\n \n \n \n \n \n \n \n \n \n236/MOH 204.', 'LSC 228 guide\n \n \n \n \n \n \n \n \n \nopen and retract.', 'Verify TDA 202/LSA\n \n \n \n \n \n \n \n \n \n228 is above MOH\n \n \n \n \n \n \n \n \n \n204.', 'Lower single 111 into\n \n \n \n \n \n \n \n \n \nLSC 228.', 'Open LSA 228 and\n \n \n \n \n \n \n \n \n \nretract.', 'Close LSC 228 guide\n \n \n \n \n \n \n \n \n \nwhen pin end below\n \n \n \n \n \n \n \n \n \nguide.', 'Continue lowering\n \n \n \n \n \n \n \n \n \ntubular 111 inside\n \n \n \n \n \n \n \n \n \nMOH 204 until stick-up\n \n \n \n \n \n \n \n \n \nof about one meter.\n \n \n \n \n \n \n \n8.', 'Pipe\n \nClose ITC 236 on\n \nVisual/\n \n \n \nITC 236 head\n \n \n \n \nHandler\n \ntubular 111:\n \nCCTV\n \n \n \nextend.', 'Verify tubular 111\n \n \n \n \nITC 236/LTC\n \n \n \n \n \ninside ITC 236/LTC\n \n \n \n \n244 Closed\n \n \n \n \n \n244.\n \n \n \n \nstate.', 'Extend ITC 236 head.', 'Close ITC 236 guide\n \n \n \n \n \n \n \n \n \nand clamps.', 'Open and retract LTC\n \n \n \n \n \n \n \n \n \n244 (if doping next\n \n \n \n \n \n \n \n \n \npin).', '9.\n \nPipe\n \nTransfer weight to ITC\n \nVisual/\n \nITC 236 closed.', 'Verify weight\n \nTDA 202 load\n \n \n \n \nHandler\n \n236 and open TDA\n \nCCTV\n \n \ntransferred prior to\n \nindicator.', '202:\n \n \n \nopen TDA 202.', 'TDA 202 to\n \n \n \n \n \nLower TDA 202 to\n \n \n \n \nOpen state.', 'transfer tubular 111\n \n \n \n \n \n \n \n \n \nweight to ITC 236.', 'Open TDA 202 and\n \n \n \n \n \n \n \n \n \nretract from stick-up.', 'Move TDA 202 to CW\n \n \n \n \n \n \n \n \n \n131 pick-up position.', '10.\n \nPipe\n \nPresent second tubular\n \nVisual\n \nRamp 149 in tubular\n \nSkate 133 will move\n \n \n \n \n \nHandler\n \n111 above TDA 202:\n \n \n111 pick-up position.', 'forward a\n \n \n \n \n \n \nVerify TDA 202 open\n \n \nTDA 202 in tubular\n \npredetermined\n \n \n \n \n \n \nand below tubular 111\n \n \n111 pick-up position.', 'distance depending\n \n \n \n \n \n \npick-up position.', 'on tubular 111 size\n \n \n \n \n \n \nMove skate 133 until\n \n \n \n(see step 4).', 'tubular 111 is\n \n \n \n \n \n \n \n \n \npositioned above TDA\n \n \n \n \n \n \n \n \n \n202 elevator.', '11.\n \nPipe\n \nLatch TDA 202 on\n \nVisual\n \nTubular 111 is\n \nTubular interlock to\n \nTDA 202 to\n \n \n \n \nHandler\n \nsecond tubular 111:\n \n \npositioned correctly\n \nprevent hoisting\n \nClosed state.', 'Hoist TDA 202 to\n \n \nfor TDA 202.\n \nwithout closed TDA\n \n \n \n \n \n \nlatch onto tubular 111.', '202 (above preset\n \n \n \n \n \n \nClose TDA 202.\n \n \n \nheight).', '12.\n \nPipe\n \nLift tubular 111 to\n \nVisual\n \nTDA 202 closed.', 'Hoisting will stop\n \nIndicate LSA\n \n \n \n \nHandler\n \nvertical above MOH\n \n \nVerify LSA 228 is\n \nprior to lifting tubular\n \n228 guide\n \n \n \n \n \n204:\n \n \npositioned to receive\n \n111 out of CW 131\n \nposition.', 'Verify TDA 202 is\n \n \ntubular 111 bottom\n \nwithout guiding.', 'Indicate TDA\n \n \n \n \n \nclosed.', 'before hoisting.', 'LSA 228 centralizer\n \n202/LSA 228 in\n \n \n \n \n \nHoist TDA 202 to\n \n \nTDA 202 above LSA\n \ncloses when tubular\n \nMOH 204\n \n \n \n \n \npick-up single 111 from\n \n \n228 operating area.', '111 nears vertical.\n \nposition.', 'CW 131.', 'TDA 202 and LSA\n \n \n \n \n \n \nMove LSA 228 to\n \n \n \n228 will position\n \n \n \n \n \n \npreset position to\n \n \n \ntubular 111 above\n \n \n \n \n \n \nprepare for guiding.', 'MOH 204/ITC 236.', 'Before the tubular\n \n \n \n \n \n \n \n \n \n111 lower end leaves\n \n \n \n \n \n \n \n \n \nCW 131, close LSA\n \n \n \n \n \n \n \n \n \n228 funnel.', 'Dope box when\n \n \n \n \n \n \n \n \n \ntubular 111 is vertical\n \n \n \n \n \n \n \n \n \n(if selected).', 'Continue hoisting\n \n \n \n \n \n \n \n \n \nTDA 202 until tubular\n \n \n \n \n \n \n \n \n \n111 is above MOH\n \n \n \n \n \n \n \n \n \n204.\n \n \n \n \n \n \n \n13.', 'Pipe\n \nCW 131 retract to\n \nVisual/\n \n \nSkate 133 will move\n \n \n \n \n \nHandler\n \nloading position:\n \nCCTV\n \n \nto loading position.', 'Verify tubular 111 pin\n \n \n \nRamp 149 will tilt to\n \n \n \n \n \n \nend is clear of ramp\n \n \n \nloading position.', '149.\n \n \n \n \n \n \n \n \n \nMove CW 131 toward\n \n \n \n \n \n \n \n \n \nFT loading position.\n \n \n \n \n \n \n \n14.', 'Pipe\n \nCW 131 load and\n \nVisual/\n \n \nReference steps 1\n \n \n \n \n \nHandler\n \npresent third tubular\n \nCCTV\n \n \nand 2.\n \n \n \n \n \n \n111 (if needed):\n \n \n \n \n \n \n \n \n \nPick up next tubular\n \n \n \n \n \n \n \n \n \n111 per steps 1 and 2.\n \n \n \n \n \n \n \n15.\n \nPipe\n \nMove RN 151 to MOH\n \nVisual\n \nTDA 202/LSA 228 in\n \nRN 151 (THA) will\n \n \n \n \n \nHandler\n \n204 position:\n \n \nMOH 204 position.', 'move to MOH 204\n \n \n \n \n \n \nActivate RN 151\n \n \n \nand elevate to\n \n \n \n \n \n \nsequence.', 'selected stick-up\n \n \n \n \n \n \nActivate RN 151\n \n \n \nheight.', 'stabbing guide.\n \n \n \n \n \n \n \n16.\n \nPipe\n \nStab second tubular\n \nVisual\n \nTubular 111 bottom\n \n \nIndicate weight\n \n \n \n \nHandler\n \n111 in MOH 204 stick-\n \n \nclear of CW 131.\n \n \ntransfer.', 'up:\n \n \nLSA 228 open, RN\n \n \n \n \n \n \n \nOpen and retract LSA\n \n \n151 stabbing guide\n \n \n \n \n \n \n \n228.\n \n \nactive.', 'Lower single 111 into\n \n \n \n \n \n \n \n \n \nMOH 204 stick-up.', 'Continue lowering\n \n \n \n \n \n \n \n \n \n(e.g., at least about 0.2\n \n \n \n \n \n \n \n \n \nmeters to permit spin-\n \n \n \n \n \n \n \n \n \nin).', '17.\n \nPipe\n \nRN 151 spin-in and\n \nVisual/\n \nSingle 111 stabbed in\n \nRN 151 will\n \nTorque log\n \n \n \n \nHandler\n \nmake-up:\n \nCCTV\n \nstick-up (TDA 202\n \nautomatically spin-in\n \nupdated.', 'Verify pin is stabbed\n \n \nunloaded, elevator\n \nand make-up to\n \n \n \n \n \n \nin the box.\n \n \nbelow TJ).', 'preset torque.', 'Activate RN 151\n \n \n \nOpen RN 151\n \n \n \n \n \n \nsequence to continue\n \n \n \nspinner, guide, and\n \n \n \n \n \n \nmake-up sequence.', 'clamps.', 'Return RN 151 to\n \n \n \n \n \n \n \n \n \npark position.', '18.\n \nPipe\n \nLower double 111 into\n \nVisual/\n \nRN 151 has\n \n \nTDA 202/LSA\n \n \n \n \nHandler\n \nMOH 204 (if needed):\n \nCCTV\n \ncompleted MU\n \n \n228 Closed/\n \n \n \n \n \nVerify connection is\n \n \nsequence with correct\n \n \nOpen status.', 'made-up.\n \n \ntorque.', 'TDA 202 load.', 'Hoist TDA 202 to pick\n \n \n \n \nLTC 244/ITC\n \n \n \n \n \nup weight.', '236 status.', 'Open ITC 236 guide\n \n \n \n \n \n \n \n \n \nand clamps.', 'Lower double 111 to\n \n \n \n \n \n \n \n \n \ncorrect stick-up.', 'LTC 244 in position\n \n \n \n \n \n \n \n \n \nfor guiding if doping not\n \n \n \n \n \n \n \n \n \nselected (else, LTC\n \n \n \n \n \n \n \n \n \n244 retracted).', 'Stop at selected', 'stick-\n \n \n \n \n \n \n \n \n \nup (e.g., about one\n \n \n \n \n \n \n \n \n \nmeter).', 'Close ITC 236 guide\n \n \n \n \n \n \n \n \n \nand clamps.', 'Lower TDA 202 to\n \n \n \n \n \n \n \n \n \ntransfer tubular 111\n \n \n \n \n \n \n \n \n \nweight to ITC 236.', 'Open TDA 202 and\n \n \n \n \n \n \n \n \n \nretract from stick-up.\n \n \n \n \n \n \n \n19.', 'Pipe\n \nRepeat steps 10-17 for\n \n \n \n \n \n \n \n \nHandler\n \nthird single 111 (if\n \n \n \n \n \n \n \n \n \nneeded)\n \n \n \n \n \n \n \n20.\n \nPipe\n \nMove stand 111 to\n \nVisual/\n \nRN 151 has\n \n \nWeight\n \n \n \n \nHandler\n \nTHP 207:\n \nCCTV\n \ncompleted MU\n \n \ntransfer.', 'LTC 244 extends to\n \n \nsequence with correct\n \n \nITC 236\n \n \n \n \n \nstand 111 in MOH 204\n \n \ntorque.', 'Retracted.\n \n \n \n \n \nposition and closes\n \n \nComplete stand 111\n \n \nLTC 244\n \n \n \n \n \nguide.\n \n \nin MOH 204.', 'Extended.', 'Hoist TDA 202 to pick\n \n \n \n \nLTC 244\n \n \n \n \n \nup stand 111 weight.', 'Closed.', 'Open ITC 236 guide\n \n \n \n \nITC 236 Open.\n \n \n \n \n \nand clamps.', 'UTC 242\n \n \n \n \n \nITC 236 head\n \n \n \n \nExtended.\n \n \n \n \n \nretracted.', 'UTC 242\n \n \n \n \n \nTDA 202 will lift stand\n \n \n \n \nClosed.\n \n \n \n \n \n111 from MOH 204\n \n \n \n \nTDA 202\n \n \n \n \n \nuntil pin end above\n \n \n \n \nOpen.', 'THP doper 209.', 'TDA 202 and LTC\n \n \n \n \n \n \n \n \n \n244 move stand 111\n \n \n \n \n \n \n \n \n \nabove THP 207.', 'Stab stand 111 in\n \n \n \n \n \n \n \n \n \nTHP 207 and initiate\n \n \n \n \n \n \n \n \n \nwash and dope, if\n \n \n \n \n \n \n \n \n \nselected.', 'UTC 242 extends to\n \n \n \n \n \n \n \n \n \nstand 111 and closes\n \n \n \n \n \n \n \n \n \nguide.', 'TDA 202 opens and\n \n \n \n \n \n \n \n \n \nretracts from stand\n \n \n \n \n \n \n \n \n \n111.\n \n \n \n \n \n \n \n21.', 'Pipe\n \nSet back stand 111:\n \nVisual/\n \nUTC 242 and LTC\n \n \nTBR 254/SGA\n \n \n \n \nHandler\n \nTBR 254 and SGA\n \nCCTV\n \n244 closed on stand\n \n \n262 status.', '262 move to THP 207\n \n \n111 in THP 207.', 'TBR 254 load.', 'and close guide and\n \n \nTDA 202 retracted\n \n \n \n \n \n \n \nclamps on stand 111.', 'from stand 111 in\n \n \n \n \n \n \n \nUTC 242 and LTC\n \n \nTHP 207.\n \n \n \n \n \n \n \n244 open and retract.', 'TBR 254 and SGA\n \n \n \n \n \n \n \n \n \n262 set back stand 111\n \n \n \n \n \n \n \n \n \nto selected position in\n \n \n \n \n \n \n \n \n \nFIB 166.', 'To lay down stands (offline), an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth above in Table 4A.', 'The well construction system \n100\n, \n200\n can then be set-up for performing the lay-down operation.', 'Examples of such set-up may be as set forth below in Table 5A.\n \n \n \n \n \n \n \n \nTABLE 5A\n \n \n \n \n \n \n \n \nStand Lay-Down Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'TBR 254,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nSGA 262,\n \n \nequipment.', 'Program setup\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \nwizard.', 'LTC 244,\n \n \ntouchscreen 522, 524.', 'After startup: Check\n \n \n \nITC 236,\n \n \nSelect Stand Building mode.', 'for green light in\n \n \n \nTHP 207,\n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \nTDA 202,\n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \nLSA 228,\n \n \nSelect slot, direction for racking stands\n \nheader on front\n \n \n \nRN 151,\n \n \n111.\n \nscreen 532, 534,\n \n \n \nCW 131\n \n \nSelect Pipe size/type.\n \n536.', 'Select RN 151 (with THA) to use in the\n \n \n \n \n \noperations.', 'Select pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'All\n \nPipe\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \nHandler\n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nElectronic tally system to be updated.', '111\n \nHandler\n \n \n \n \n \n \n \n \n \n \nAfter such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example stand lay-down sequence may start with all machines empty, the ITC \n236\n retracted, and the CW \n131\n FT empty and ready to receive single tubulars \n111\n.', 'Example steps of the stand lay-down sequence may be as set forth below in Table 5B.\n \n \n \n \n \n \n \n \nTABLE 5B\n \n \n \n \n \n \n \n \nStand Lay-Down Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA\n \nTBR 254 will move\n \nTBR 254 and\n \n \n \n \nHandler\n \npick up new stand 111:\n \nCCTV\n \n262 grip/guide open.\n \ninto FIB 166 elevated\n \nSGA 262 grip/\n \n \n \n \n \nMove TBR 254 and\n \n \nSelected FIB 166\n \nabove open latches.', 'guide to Closed\n \n \n \n \n \nSGA 262 to selected\n \n \nposition “valid.”', 'Adjustments available.', 'state.', 'finger/slot in FIB 166.', 'TBR 254 and SGA\n \n \n \n \n \n \nClose guides and\n \n \n \n262 grip/guide will\n \n \n \n \n \n \nclamp on stand 111.\n \n \n \nclose.', '2.\n \nPipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTHP 207 empty.', 'TBR 254 cannot\n \nIndicate open\n \n \n \n \nHandler\n \nmove stand 111 to THP\n \nCCTV\n \nUTC 242 and LTC\n \nopen with weight.\n \nlatches.', '207:', '244 open.', 'TBR 254 grip open\n \nTBR 254 load\n \n \n \n \n \nOpen FIB 166 latches\n \n \nCorrect pipe\n \nwhen unloaded.\n \nindication.\n \n \n \n \n \nfor selected row.\n \n \ndetected in TBR 254\n \nFIB 166 latches will\n \n \n \n \n \n \nVerify latches open\n \n \nand SGA 262.', 'not open with TBR\n \n \n \n \n \n \n(Visual/CCTV).', '254 head in low\n \n \n \n \n \n \nTBR 254 lift stand\n \n \n \nposition.\n \n \n \n \n \n \n111 and move out of\n \n \n \n \n \n \n \n \n \nFIB 166 to THP 207.', 'FIB 166 latches will\n \n \n \n \n \n \n \n \n \nclose as the stand 111\n \n \n \n \n \n \n \n \n \nmoves out of FIB 166.', 'Set stand 111 on\n \n \n \n \n \n \n \n \n \nTHP 207.', 'Wash and dope pin if\n \n \n \n \n \n \n \n \n \npreselected.', '3.\n \nPipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nextend to THP 207 and\n \nCCTV\n \n262 with stand 111 in\n \n244 extend and\n \nLTC 244 to\n \n \n \n \n \nclose:\n \n \nTHP 207.', 'close.', 'Closed state.', 'UTC 242 and LTC\n \n \n \n \n \n \n \n \n \n244 extend to THP\n \n \n \n \n \n \n \n \n \n207.\n \n \n \n \n \n \n \n \n \nUTC 242 and LTC', '244 close.', '4.\n \nPipe\n \nTBR 254 and SGA 262\n \n \nUTC 242 and LTC\n \n \n \n \n \n \nHandler\n \nopen and move toward\n \n \n244 closed on stand\n \n \n \n \n \n \n \nFIB 166:\n \n \n111.', 'Open TBR 254\n \n \n \n \n \n \n \n \n \nclamps and guide and\n \n \n \n \n \n \n \n \n \nSGA 262 guide.', 'Move toward FIB 166\n \n \n \n \n \n \n \n \n \n(next stand 111).', 'Continue step 1.\n \n \n \n \n \n \n \n5.\n \nPipe\n \nTDA 202 extend to\n \nVisual/\n \nTDA 202 must be\n \nTDA 202 tilt/extend\n \n \n \n \n \nHandler\n \nstand 111 in THP 207:\n \nCCTV\n \nopen.', 'until contact with\n \n \n \n \n \n \nTilt/extend TDA 202\n \n \n \nstand 111 in THP\n \n \n \n \n \n \nuntil contact with stand\n \n \n \n207.\n \n \n \n \n \n \n111 in THP 207, below\n \n \n \n \n \n \n \n \n \nTJ.', 'Note: LSA 228\n \n \n \n \n \n \n \n \n \nused for guiding pin\n \n \n \n \n \n \n \n \n \nend.', '6.\n \nPipe\n \nTDA 202 latch onto\n \nVisual/\n \nTDA 202 must be in\n \nThe closing sequence\n \nConfirm TDA\n \n \n \n \nHandler\n \nstand 111 in THP 207:\n \nCCTV\n \nTHP 207 position.\n \nis verified to assure\n \n202 closed on\n \n \n \n \n \nClose TDA 202.\n \n \n \nproper grip.', 'tubular 111.', '7.\n \nPipe\n \nUTC 242 open and\n \nVisual/\n \nTDA 202 must be\n \nUTC 242 open and\n \nUTC 242 to\n \n \n \n \nHandler\n \nretract:\n \nCCTV\n \nclosed.\n \nretract.', 'Open state.', 'UTC 242 opens.', 'LSA 228 to\n \n \n \n \n \nUTC 242 retracts.', 'Guide mode.', 'LSA 228 to guide\n \n \n \n \n \n \n \n \n \nmode.', '8.\n \nPipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nUTC 242 open.', 'TDA 202 hoist, tilt to\n \nTDA 202 Load\n \n \n \n \nHandler\n \nmove stand 111 to MOH\n \nCCTV\n \n \nvertical.\n \nindication.', '204:\n \n \n \nTDA 202 dope top\n \n \n \n \n \n \nTDA 202 lift stand\n \n \n \nbox if preselected\n \n \n \n \n \n \n111 guided by the LSA\n \n \n \n(automatic).', '228 to MOH 204.', '9.\n \nPipe\n \nLower stand 111 in\n \nVisual/\n \nLSA 228 guide mode.', 'Indicate ITC\n \n \n \n \nHandler\n \nMOH 204/ITC 236:\n \nCCTV\n \n \n \n236 and LSA\n \n \n \n \n \nVerify LSA 228 is\n \n \n \n \n228 position\n \n \n \n \n \nguiding above MOH\n \n \n \n \nand guide/grip\n \n \n \n \n \n204.\n \n \n \n \nstates.', 'TDA 202 lowers\n \n \n \n \n \n \n \n \n \nstand 111 into MOH\n \n \n \n \n \n \n \n \n \n204.', 'Stop with one single\n \n \n \n \n \n \n \n \n \n111 above rig floor 114\n \n \n \n \n \n \n \n \n \nand stick-up of about\n \n \n \n \n \n \n \n \n \none meter.', '10.\n \nPipe\n \nClose ITC 236 on\n \nVisual/\n \n \n \nITC 236\n \n \n \n \nHandler\n \nstand 111:', 'CCTV\n \n \n \nExtended.\n \n \n \n \n \nVerify stand 111\n \n \n \n \nITC 236 in\n \n \n \n \n \ninside ITC 236.', 'Closed state.', 'Extend ITC 236.', 'Close ITC 236.\n \n \n \n \n \n \n \n11.', 'Pipe\n \nTransfer stand 111\n \nVisual/\n \nITC 236 closed.', 'TDA 202 load\n \n \n \n \nHandler\n \nweight to ITC 236:\n \nCCTV\n \n \n \nindicator.', 'Lower TDA 202 to\n \n \n \n \nTDA 202 to\n \n \n \n \n \ntransfer stand 111\n \n \n \n \nOpen state.', 'weight to ITC 236.\n \n \n \n \n \n \n \n12.', 'Pipe\n \nOpen and retract LTC\n \nVisual/\n \n \n \nLTC 244 in\n \n \n \n \nHandler\n \n244:\n \nCCTV\n \n \n \nOpen and\n \n \n \n \n \nOpen and retract LTC\n \n \n \n \nRetracted state.\n \n \n \n \n \n244 to THP 207.\n \n \n \n \n \n \n \n13.', 'Pipe\n \nMove second RN 151\n \nVisual\n \nITC 236 closed.', 'Second RN 151\n \n \n \n \n \nHandler\n \nto MOH 204 (stand):\n \n \n \n(with THA) will\n \n \n \n \n \n \nVerify TDA 202\n \n \n \nmove to MOH 204\n \n \n \n \n \n \nunloaded in MOH 204.\n \n \n \nand elevate to\n \n \n \n \n \n \nMove second RN 151\n \n \n \nselected stick-up\n \n \n \n \n \n \nto MOH 204.\n \n \n \nheight.\n \n \n \n \n14.', 'Pipe\n \nMove LSA 228 to MOH\n \nVisual\n \nITC 236 closed.', 'Handler\n \n204 (stand):\n \n \n \n \n \n \n \n \n \nMove LSA 228 to\n \n \n \n \n \n \n \n \n \nMOH 204.', 'Close LSA 228 guide\n \n \n \n \n \n \n \n \n \nfunnel.', '15.\n \nPipe\n \nTilt CW 131 ramp 149\n \nVisual/\n \nTubular 111 loaded\n \n \n \n \n \n \nHandler\n \nand move skate 133 to\n \nCCTV\n \nonto ramp 149.\n \n \n \n \n \n \n \nrig floor 114 lay-down\n \n \n \n \n \n \n \n \n \nposition:\n \n \n \n \n \n \n \n \n \nVerify tubular 111 is\n \n \n \n \n \n \n \n \n \nunloaded from ramp\n \n \n \n \n \n \n \n \n \n149 (CW 131 ready).', 'Activate CW 131\n \n \n \n \n \n \n \n \n \nsequence.', '16.\n \nDriller\n \nRN 151 break-out and\n \nVisual/\n \nITC 236 closed (TDA\n \nRN 151 will\n \n \n \n \n \n \nspin-out (upper single\n \nCCTV\n \n202 unloaded, gripper\n \nautomatically break-\n \n \n \n \n \n \n111):\n \n \nbelow TJ).', 'out and spin-out the\n \n \n \n \n \n \nVerify ITC 236 is\n \n \n \nupper single 111.\n \n \n \n \n \n \nclosed and TDA 202\n \n \n \nOpen RN 151\n \n \n \n \n \n \nunloaded.', 'spinner, guide, and\n \n \n \n \n \n \nActivate RN 151\n \n \n \nclamps.\n \n \n \n \n \n \nsequence to continue\n \n \n \nReturn RN 151 to\n \n \n \n \n \n \nbreak-out sequence.', 'park position.', '17.\n \nPipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nRN 151 has\n \n \n \n \n \n \nHandler\n \nmove upper single 111\n \nCCTV\n \ncompleted break-out\n \n \n \n \n \n \n \nfrom MOH 204 to CW\n \n \nsequence.', '131:\n \n \nCW 131 in lay-down\n \n \n \n \n \n \n \nVerify connection is\n \n \nposition.\n \n \n \n \n \n \n \nspun-out.', 'Hoist TDA 202 to lift\n \n \n \n \n \n \n \n \n \nupper tubular 111 from\n \n \n \n \n \n \n \n \n \nstick-up and above\n \n \n \n \n \n \n \n \n \nCW 131, guided by\n \n \n \n \n \n \n \n \n \nLSA 228.', 'Rotate TDA 202 to\n \n \n \n \n \n \n \n \n \nface CW 131.', 'Tilt TDA 202 toward\n \n \n \n \n \n \n \n \n \nCW 131.\n \n \n \n \n \n \n \n18.', 'Pipe\n \nLSA 228 guide upper\n \nVisual/\n \nCW 131 in lay-down\n \n \nLSA 228\n \n \n \n \nHandler\n \ntubular 111 pin to CW\n \nCCTV\n \nposition.\n \n \nposition.', '131:\n \n \n \n \n \n \n \n \n \nVerify pin is above\n \n \n \n \n \n \n \n \n \nCW 131.', 'Guide pin above\n \n \n \n \n \n \n \n \n \nskate 133.\n \n \n \n \n \n \n \n19.', 'Pipe\n \nLay down upper single\n \nVisual/\n \nCW 131 in lay-down\n \n \n \n \n \n \nHandler\n \n111 on CW 131:\n \nCCTV\n \nposition.', 'Verify TDA 202 is\n \n \n \n \n \n \n \n \n \nrotated and tilted\n \n \n \n \n \n \n \n \n \ntoward CW 131.', 'Lower TDA 202 and\n \n \n \n \n \n \n \n \n \nset upper tubular 111\n \n \n \n \n \n \n \n \n \npin on skate 133.\n \n \n \n \n \n \n \n \n \nContinue lowering\n \n \n \n \n \n \n \n \n \nuntil upper tubular 111\n \n \n \n \n \n \n \n \n \nrests on CW 131.\n \n \n \n \n \n \n \n20.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \n \n \nLSA 228 to\n \n \n \n \nHandler\n \n(upper single 111):\n \nCCTV\n \n \n \nOpen state.', 'Verify pin rests on\n \n \n \n \n \n \n \n \n \nCW 131.', 'Open and retract LSA\n \n \n \n \n \n \n \n \n \n228.\n \n \n \n \n \n \n \n21.', 'Pipe\n \nLay down upper single\n \nVisual/\n \n \nSkate 133 will move\n \n \n \n \n \nHandler\n \n111 on CW 131 and\n \nCCTV\n \n \nout synchronized\n \n \n \n \n \n \nopen TDA 202:\n \n \n \nwith TDA 202.', 'Verify TDA 202 is\n \n \n \n \n \n \n \n \n \ntilted toward CW 131\n \n \n \n \n \n \n \n \n \nand LSA 228 is out of\n \n \n \n \n \n \n \n \n \nTDA 202 area.', 'Lower TDA 202 until\n \n \n \n \n \n \n \n \n \nupper single 111 rests\n \n \n \n \n \n \n \n \n \non ramp 149.\n \n \n \n \n \n \n \n22.', 'Pipe\n \nOpen TDA 202:\n \nVisual\n \n \n \nTDA 202 to\n \n \n \n \nHandler\n \nVerify upper single\n \n \n \n \nOpen state.', '111 is resting on CW\n \n \n \n \n \n \n \n \n \n131.', 'Open TDA 202.', 'Tilt TDA 202 to\n \n \n \n \n \n \n \n \n \nvertical above MOH\n \n \n \n \n \n \n \n \n \n204 stick-up.', 'Rotate TDA 202\n \n \n \n \n \n \n \n \n \n(e.g., 90 degrees).', '23.\n \nPipe\n \nMove upper tubular\n \nVisual/\n \nTDA 202 open.', 'Skate 133 will pull\n \nSkate 133 to\n \n \n \n \nHandler\n \n111 to FT and unload:\n \nCCTV\n \n \nupper tubular 111 to\n \nunloading\n \n \n \n \n \nActivate CW 131\n \n \n \nunloading position.\n \nposition.\n \n \n \n \n \nsequence to move out\n \n \n \nRamp 149 will tilt to\n \nCW 131 to\n \n \n \n \n \nand unload upper\n \n \n \nunloading position.', 'unloading\n \n \n \n \n \ntubular 111.\n \n \n \nFT will unload upper\n \nposition.', 'tubular 111.', 'FT unloading\n \n \n \n \n \n \n \n \n \nactive.', 'Second Single 111 of Stand:\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n24.', 'Pipe\n \nLower TDA 202 to\n \nVisual\n \n \n \nTDA 202 to\n \n \n \n \nHandler\n \nstick-up and close:\n \n \n \n \nClosed state.', 'Lower TDA 202 to\n \n \n \n \n \n \n \n \n \nstick-up.', 'Close TDA 202 on\n \n \n \n \n \n \n \n \n \nstick-up.\n \n \n \n \n \n \n \n25.\n \nPipe\n \nHoist double in MOH\n \nVisual/\n \n \n \nTDA 202/LSA\n \n \n \n \nHandler\n \n204 (not applicable for\n \nCCTV\n \n \n \n228 close/open\n \n \n \n \n \ntripe stands):\n \n \n \n \nstatus.', 'Hoist TDA 202 to pick\n \n \n \n \nTDA 202 load.', 'up weight.', 'LTC 244/ITC\n \n \n \n \n \nOpen ITC 236 guide\n \n \n \n \n236 status.\n \n \n \n \n \nand clamps.', 'Stop at selected\n \n \n \n \n \n \n \n \n \nstick-up (e.g., about\n \n \n \n \n \n \n \n \n \none meter).', 'Close ITC 236 guide\n \n \n \n \n \n \n \n \n \nand clamps.', 'Lower TDA 202 to\n \n \n \n \n \n \n \n \n \ntransfer weight to ITC\n \n \n \n \n \n \n \n \n \n236.\n \n \n \n \n \n \n \n26.', 'Driller\n \nMove second RN 151\n \nVisual\n \nITC 236 closed.', 'Second RN 151 (with\n \n \n \n \n \n \nto MOH 204:\n \n \n \nTHA) will move to\n \n \n \n \n \n \nVerify TDA 202\n \n \n \nMOH 204 and elevate\n \n \n \n \n \n \nunloaded in MOH 204.\n \n \n \nto selected stick-up\n \n \n \n \n \n \nMove second RN2 to\n \n \n \nheight.', 'MOH 204.\n \n \n \n \n \n \n \n27.\n \nPipe\n \nMove LSA 228 to MOH\n \nVisual\n \nITC 236 closed.', 'Handler\n \n204:\n \n \n \n \n \n \n \n \n \nMove LSA 228 to\n \n \n \n \n \n \n \n \n \nMOH 204.', 'Close LSA 228 guide\n \n \n \n \n \n \n \n \n \nfunnel.', '28.\n \nPipe\n \nTilt ramp 149 and\n \nVisual/\n \nTubular 111 loaded\n \nSkate 133 will move\n \nCW 131 lay-\n \n \n \n \nHandler\n \nmove skate 133 to lay-\n \nCCTV\n \nonto ramp 149.\n \nto lay-down position.\n \ndown ready.', 'down position:\n \n \n \n \n \n \n \n \n \nVerify tubular 111 is\n \n \n \n \n \n \n \n \n \nunloaded from ramp\n \n \n \n \n \n \n \n \n \n149 (CW 131 ready).', 'Activate CW 131\n \n \n \n \n \n \n \n \n \nsequence.\n \n \n \n \n \n \n \n29.', 'Driller\n \nRN 151 break-out and\n \nVisual/\n \nITC 236 closed (TDA\n \nRN 151 will\n \n \n \n \n \n \nspin-out:\n \nCCTV\n \n202 unloaded, gripper\n \nautomatically break-\n \n \n \n \n \n \nVerify ITC 236 is\n \n \nbelow TJ).', 'out and spin-out the\n \n \n \n \n \n \nclosed and', 'TDA 202 is\n \n \n \nsingle 111.\n \n \n \n \n \n \nunloaded.', 'Open RN 151\n \n \n \n \n \n \nActivate RN 151\n \n \n \nspinner, guide, and\n \n \n \n \n \n \nsequence to continue\n \n \n \nclamps.\n \n \n \n \n \n \nbreak-out sequence.', 'Return RN 151 to\n \n \n \n \n \n \n \n \n \npark position.', '30.\n \nPipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nRN 151 has\n \n \n \n \n \n \nHandler\n \nmove pipe from MOH\n \nCCTV\n \ncompleted break-out\n \n \n \n \n \n \n \n204 to CW 131:\n \n \nsequence.', 'Verify connection is\n \n \nCW 131 in lay-down\n \n \n \n \n \n \n \nspun-out.\n \n \nposition.', 'Hoist TDA 202 to lift\n \n \n \n \n \n \n \n \n \ntubular 111 from stick-\n \n \n \n \n \n \n \n \n \nup and above CW 131\n \n \n \n \n \n \n \n \n \n(guided by LSA 228).', 'Rotate TDA 202 to\n \n \n \n \n \n \n \n \n \nface CW 131.', 'Tilt TDA 202 toward\n \n \n \n \n \n \n \n \n \nCW 131.\n \n \n \n \n \n \n \n31.', 'Pipe\n \nLSA 228 will guide pin\n \nVisual/\n \nCW 131 in lay-down\n \n \nLSA 228\n \n \n \n \nHandler\n \nto CW 131:\n \nCCTV\n \nposition.\n \n \nposition.', 'Verify pin end is\n \n \n \n \n \n \n \n \n \nabove CW 131.', 'Guide pin to above\n \n \n \n \n \n \n \n \n \nskate 133.\n \n \n \n \n \n \n \n32.', 'Pipe\n \nLay down pipe on CW\n \nVisual/\n \nCW 131 in lay-down\n \n \n \n \n \n \nHandler\n \n131:\n \nCCTV\n \nposition.', 'Verify TDA 202 is\n \n \n \n \n \n \n \n \n \nrotated and tilted\n \n \n \n \n \n \n \n \n \ntoward CW 131.', 'Lower TDA 202 and\n \n \n \n \n \n \n \n \n \nset pin on skate 133.\n \n \n \n \n \n \n \n \n \nContinue lowering\n \n \n \n \n \n \n \n \n \nuntil pipe rests on CW\n \n \n \n \n \n \n \n \n \n131.\n \n \n \n \n \n \n \n33.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \n \n \nLSA 228 to\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \n \n \nOpen state.', 'Verify pin is resting\n \n \n \n \n \n \n \n \n \non CW 131.', 'Open and retract LSA\n \n \n \n \n \n \n \n \n \n228.\n \n \n \n \n \n \n \n34.', 'Pipe\n \nMove pipe to FT and\n \nVisual/\n \nTDA 202 open.', 'Skate 133 will pull\n \nSkate 133 to\n \n \n \n \nHandler\n \nunload:\n \nCCTV\n \n \nthe pipe to unloading\n \nunloading\n \n \n \n \n \nActivate CW 131\n \n \n \nposition.\n \nposition.\n \n \n \n \n \nsequence to move out\n \n \n \nRamp 149 will tilt to\n \nCW 131 to\n \n \n \n \n \nand unload the pipe.', 'unloading position.', 'unloading\n \n \n \n \n \n \n \n \nFT will unload the\n \nposition.\n \n \n \n \n \n \n \n \npipe.', 'FT unloading\n \n \n \n \n \n \n \n \n \nactive.', 'Third Single 111 of Stand (If Applicable):\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n35.', 'Pipe\n \nLower TDA 202 to\n \nVisual\n \n \n \nTDA to Closed\n \n \n \n \nHandler\n \nstick-up and close:\n \n \n \n \nstate.', 'Lower TDA 202 to\n \n \n \n \n \n \n \n \n \nstick-up.', 'Close TDA 202 on\n \n \n \n \n \n \n \n \n \nstick-up.\n \n \n \n \n \n \n \n36.\n \nPipe\n \nHoist single 111 from\n \nVisual/\n \n \n \nTDA 202/LSA\n \n \n \n \nHandler\n \nMOH 204:\n \nCCTV\n \n \n \n228 close/open\n \n \n \n \n \nHoist TDA 202 to pick\n \n \n \n \nstatus.', 'up weight.', 'TDA 202 load.', 'Open ITC 236 guide\n \n \n \n \nLTC 244 and\n \n \n \n \n \nand clamps.', 'ITC 236 status.', 'Retract ITC 236\n \n \n \n \n \n \n \n \n \n(Note: pipe not\n \n \n \n \n \n \n \n \n \nguided).', '37.\n \nPipe\n \nMove LSA 228 to MOH\n \nVisual\n \nITC 236 closed.', 'Handler\n \n204:\n \n \n \n \n \n \n \n \n \nVerify TDA 202\n \n \n \n \n \n \n \n \n \nabove LSA 228\n \n \n \n \n \n \n \n \n \nworking height.', 'Move LSA 228 to\n \n \n \n \n \n \n \n \n \nMOH 204.', 'Close LSA 228 guide\n \n \n \n \n \n \n \n \n \nfunnel.', '38.\n \nPipe\n \nTilt ramp 149 and\n \nVisual/\n \nTubular 111 loaded\n \nSkate 133 will move\n \nCW 131 lay-\n \n \n \n \nHandler\n \nmove skate 133 to lay-\n \nCCTV\n \nonto ramp 149.\n \nto lay-down position.\n \ndown ready.', 'down position:\n \n \n \n \n \n \n \n \n \nVerify tubular 111 is\n \n \n \n \n \n \n \n \n \nunloaded from ramp\n \n \n \n \n \n \n \n \n \n149 (CW 131 ready).', 'Activate CW 131\n \n \n \n \n \n \n \n \n \nsequence.', '39.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nCW 131 in lay-down\n \n \n \n \n \n \nHandler\n \nmove pipe from MOH\n \nCCTV\n \nposition.\n \n \n \n \n \n \n \n204 to CW 131:\n \n \n \n \n \n \n \n \n \nVerify ITC 236 is\n \n \n \n \n \n \n \n \n \nopen.', 'Hoist TDA 202 to lift\n \n \n \n \n \n \n \n \n \ntubular 111 above CW\n \n \n \n \n \n \n \n \n \n131 (guided by LSA\n \n \n \n \n \n \n \n \n \n228).', 'Rotate TDA 202 to\n \n \n \n \n \n \n \n \n \nface CW 131.', 'Tilt TDA 202 toward\n \n \n \n \n \n \n \n \n \nCW 131.\n \n \n \n \n \n \n \n40.', 'Pipe\n \nLSA 228 will guide pin\n \nVisual/\n \nCW 131 in lay-down\n \n \nLSA 228\n \n \n \n \nHandler\n \nto CW 131:\n \nCCTV\n \nposition.\n \n \nposition.', 'Verify pin end is\n \n \n \n \n \n \n \n \n \nabove CW 131.', 'Guide pin end to\n \n \n \n \n \n \n \n \n \nabove skate 133.\n \n \n \n \n \n \n \n41.', 'Pipe\n \nLay down tubular 111\n \nVisual/\n \nCW 131 in lay-down\n \n \n \n \n \n \nHandler\n \non CW 131:\n \nCCTV\n \nposition.', 'Verify TDA 202 is\n \n \n \n \n \n \n \n \n \nrotated and tilted\n \n \n \n \n \n \n \n \n \ntoward CW 131.', 'Lower TDA 202 and\n \n \n \n \n \n \n \n \n \nset pin on skate 133.\n \n \n \n \n \n \n \n \n \nContinue lowering\n \n \n \n \n \n \n \n \n \nuntil tubular 111 rests\n \n \n \n \n \n \n \n \n \non CW 131.\n \n \n \n \n \n \n \n42.', 'Pipe\n \nOpen and retract LSA\n \nVisual/\n \n \n \nLSA 228 to\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \n \n \nOpen state.', 'Verify pin is resting\n \n \n \n \n \n \n \n \n \non CW 131.', 'Open and retract LSA\n \n \n \n \n \n \n \n \n \n228.\n \n \n \n \n \n \n \n43.', 'Pipe\n \nMove tubular 111 to FT\n \nVisual/\n \nTDA 202 open.', 'Skate 133 will pull\n \nSkate 133 to\n \n \n \n \nHandler\n \nand unload:\n \nCCTV\n \n \ntubular 111 to\n \nunloading\n \n \n \n \n \nActivate CW 131\n \n \n \nunloading position.\n \nposition.\n \n \n \n \n \nsequence to move out\n \n \n \nRamp 149 will tilt to\n \nCW 131 to\n \n \n \n \n \nand unload tubular\n \n \n \nunloading position.', 'unloading\n \n \n \n \n \n111.', 'FT will unload the\n \nposition.', 'Continue step 1.\n \n \n \ntubular 111.', 'FT unloading\n \n \n \n \n \n \n \n \n \nactive.', 'Different combinations of the aspects described above may also be utilized for picking up single tubulars \n111\n before assembly into stands of two or more tubulars.', 'Such operations may be performed during drilling and other operations performed at WC \n203\n.', 'Such simultaneous operations, however, are coordinated to avoid conflicts and obstructions between the different machines and systems.', 'Preparations for picking up single tubulars \n111\n may include the examples set forth below in Table 6A.\n \n \n \n \n \n \n \n \nTABLE 6A\n \n \n \n \n \n \n \n \nSingles Pick-Up Preparations\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nCW 131\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Feeding table (FT) indexer pins adjusted for pipe size.', 'Prepare to pick up pipe.', 'RN 151\n \nOperator 195 on\n \nDPT is rigged up in THT.', '(THT + DPT\n \nrig floor 114.', 'Travel path is unobstructed.', 'as primary,\n \n \nDies are clean and not worn.', 'THA + DPT\n \n \n \nas backup)\n \n \n \nLSA 228\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Slips 161\n \nOperator 195 on\n \nCorrect inserts in slips 161.', 'Rotary\n \nrig floor 114.', 'Dies are clean and not worn.', 'Table\n \n \nRotary table rotation lock activated.', 'TD 116\n \nOperator 195 on\n \nCorrect inserts in elevator 129.\n \n \n \n \nrig floor 114.', 'Elevator rotator (tilt) installed.', 'Operator screen, system status.', 'Travel path is unobstructed.', 'DW 119\n \nOperator 195 on\n \nChecked.\n \n \n \n \nrig floor 114.\n \n \n \nTubulars\n \nOperator 195 on\n \nTubular 111 to be loaded on FT.\n \n \n \n111\n \nrig floor 114.', 'Tubulars 111 to be cleaned and doped, protectors removed.', 'The well construction system \n100\n, \n200\n can then be set-up for the pick-up operation.', 'Examples of such set-up may be as set forth below in Table 6B.\n \n \n \n \n \n \n \n \nTABLE 6B\n \n \n \n \n \n \n \n \nSingles Pick-Up Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'LSA 228,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nRN 151,\n \n \nequipment.', 'Program setup\n \n \n \nCW 131\n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Trip In mode.', 'for green light in\n \n \n \n \n \nSelect target: CW 131\n \nConstruction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nSelect pipe size/type.', 'screen 532, 534,\n \n \n \n \n \nSelect RN 151 to use in the operations.', '536.', 'RN 151 MU torque.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nDW 119,\n \n \ncompleted pre-checks and deactivated\n \nscreen.\n \n \n \nMP 144,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nTrip tank\n \n \nequipment.', 'Program setup\n \n \n \n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Trip In mode.', 'for green light in\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \n \n \nStick-up target.', 'header on front\n \n \n \n \n \nSet DW 119 upper/lower stops.', 'screen 532, 534,\n \n \n \n \n \nSet maximum lowering speed.', '536.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator\n \n \n \n \n \ncompleted pre-checks.\n \nscreen, system\n \n \n \n \n \nActivate TD 116 from touchscreen 522,\n \nstatus/alarms.', '524.\n \n \n \n \n \nVerify correct elevator 129 setting\n \n \n \n \n \n(manual/remote).', 'Select Operation screen on touchscreen 522,\n \n \n \n \n \n524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator\n \n \n \n \n \n524.\n \nscreen, system\n \n \n \n \n \nSet maximum lowering speed.', 'status/alarms.', 'Set minimum slack off weight.', 'Slips 161,\n \nDriller\n \nVerify correct setting for slips 161\n \nVerify operator\n \n \n \nRotary\n \n \n(manual/remote).', 'screen, system\n \n \n \ntable\n \n \n \nstatus/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nAll types of tubulars 111 are registered.', '111\n \nHandler\n \n \n \n \n \n \n \n \n \n \nAfter such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example singles pick-up sequence may start with a stick-up at WC \n203\n, and the CW \n131\n FT pre-loaded with a tubular \n111\n, perhaps cleaned and doped.', 'Example steps of the stand building sequence may be as set forth below in Table 6C.\n \n \n \n \n \n \n \n \nTABLE 6C', 'Singles Pick-Up Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nPipe\n \nLoad tubular 111 to\n \nVisual/\n \nFT pre-loaded with\n \n \n \n \n \n \nHandler\n \nramp 149:\n \nCCTV\n \ntubular 111 (e.g.,\n \n \n \n \n \n \n \nUse FT to load\n \n \ncleaned and doped).', 'tubular to ramp 149.', 'CW 131 in loading\n \n \n \n \n \n \n \n \n \nposition.\n \n \n \n \n \n1.1.', 'Pipe\n \nMove ramp 149 to rig\n \nVisual/\n \nTubular 111 loaded to\n \n \nCW 131\n \n \n \n \nHandler\n \nfloor 114/WC 203:\n \nCCTV\n \nramp 149.\n \n \nanimated.', 'Verify tubular 111 is\n \n \n \n \n \n \n \n \n \nloaded in ramp 149\n \n \n \n \n \n \n \n \n \nand run skate 133\n \n \n \n \n \n \n \n \n \ntowards WC 203.', '2.\n \nDriller\n \nOpen TD 116 elevator\n \nVisual/\n \nSlips 161 must be\n \nElevator 129 Open not\n \nElevator 129 to\n \n \n \n \n \n129:\n \nCCTV\n \nclosed before opening\n \nselectable if slips 161\n \nOpen state.', 'Verify slips 161 are\n \n \nelevator 129.\n \nare not closed.\n \n \n \n \n \n \nclosed.', 'Open elevator 129.', '3.\n \nDriller\n \nMove TD 116 to pick-\n \nVisual\n \nElevator 129 is open.', 'TD 116 pipe handler\n \n \n \n \n \n \nup position:\n \n \nElevator 129 is\n \nhas pre-set position\n \n \n \n \n \n \nTilt links back to clear\n \n \nrotated to receive\n \nfacing CW 131.\n \n \n \n \n \n \nTJ.', 'tubular 111.', 'Hoist elevator 129\n \n \n \n \n \n \n \n \n \nabove stick-up.', 'Tilt out elevator 129\n \n \n \n \n \n \n \n \n \nand move TD 116 to\n \n \n \n \n \n \n \n \n \npick-up position.\n \n \n \n \n \n \n \n3.1.', 'Pipe\n \nPush tubular 111 to\n \nVisual\n \nRamp 149 in rig floor\n \nCW 131 will push\n \nCW 131 in pick-\n \n \n \n \nHandler\n \npick-up position:\n \n \n114 position.', 'tubular 111 a preset\n \nup position.', 'Run skate 133 until\n \n \n \ndistance forward (up\n \n \n \n \n \n \ntubular 111 is\n \n \n \nramp 149).', 'positioned above\n \n \n \n \n \n \n \n \n \nelevator 129.', '4.\n \nDriller\n \nLatch elevator 129:\n \nVisual\n \nTubular 111 is\n \nTubular interlock will\n \nElevator 129 to\n \n \n \n \n \nHoist/tilt TD 116 to\n \n \npositioned correctly\n \nprevent hoisting\n \nClosed state.', 'latch elevator 129.', 'above elevator 129.\n \nwithout closed\n \n \n \n \n \n \n \n \n \nelevator 129 (above\n \n \n \n \n \n \n \n \n \npreset height).', '5.\n \nDriller\n \nLift tubular 111:\n \nVisual\n \nElevator 129 closed.', 'Hoisting will stop prior\n \n \n \n \n \n \nHoist TD 116 to pick\n \n \nLink tilt float:\n \nto lifting tubular 111\n \n \n \n \n \n \nup single 111 from CW\n \n \nelevator 129 above\n \nout of CW 131 without\n \n \n \n \n \n \n131.', 'RN 151 working area.', 'guiding.', 'Activate TD 116 to\n \n \n \n \n \n \n \n \n \nmove elevator 129 to\n \n \n \n \n \n \n \n \n \nvertical position.\n \n \n \n \n \n \n \n5.1.', 'Pipe\n \nLSA 228 extend to\n \nVisual/\n \nTD 116 above LSA\n \n \nLSA 228 funnel\n \n \n \n \nHandler\n \nguide tubular 111\n \nCCTV\n \n228 operating area.\n \n \nto Closed state.\n \n \n \n \n \nabove CW 131:\n \n \n \n \n \n \n \n \n \nMove LSA 228 to\n \n \n \n \n \n \n \n \n \npreset position to\n \n \n \n \n \n \n \n \n \nreceive tubular 111\n \n \n \n \n \n \n \n \n \nabove CW 131.', 'Before tubular 111\n \n \n \n \n \n \n \n \n \nlower end leaves CW\n \n \n \n \n \n \n \n \n \n131, close LSA 228\n \n \n \n \n \n \n \n \n \nfunnel.\n \n \n \n \n \n \n \n5.2.', 'Pipe\n \nMove RN 151 to WC\n \n \nOnly possible with\n \nRN 151 will move to\n \n \n \n \n \nHandler\n \n203:\n \n \nTHT.', 'If THA is used,\n \nWC 203.', 'Verify TD 116 above\n \n \nwait for stand located\n \nElevate RN 151 to\n \n \n \n \n \n \nRN 151 working area.', 'above stick-up.\n \nstick-up.\n \n \n \n \n \n \nStart RN 151\n \n \nRN 151 clamps open.', 'ZMS will prevent RN\n \n \n \n \n \n \nsequence to move RN\n \n \nWC 203 selected.', '151 start if TD 116 is\n \n \n \n \n \n \n151 to WC 203.\n \n \n \ntoo low.', '5.3.\n \nPipe\n \nLSA 228 tail in tubular\n \nVisual\n \nTubular 111 bottom\n \nLSA 228 centralizer\n \nLSA 228\n \n \n \n \nHandler\n \n111 to WC 203:\n \n \nclear of CW 131 and\n \nwill close when\n \ncentralizer to\n \n \n \n \n \nTD 116 continue\n \n \nelevated above stick-\n \ntubular 111 nears\n \nClosed state.', 'hoisting.', 'up.', 'WC 203.', 'LSA 228 guide closes\n \n \nLSA 228 centralizer\n \n \n \n \n \n \n \nand tails in tubular 111\n \n \nclose: Tubular 111\n \n \n \n \n \n \n \ntoward WC 203 when\n \n \nnear vertical.', 'pin end is above stick-\n \n \n \n \n \n \n \n \n \nup.', '5.4.\n \nPipe\n \nGuide single 111 with\n \nVisual/\n \nRN 151 in WC 203.', 'Close RN 151 BUT.\n \n \n \n \n \nHandler\n \nRN 151 in WC 203:\n \nCCTV\n \nLSA 228 in WC 203.', 'Close RN 151\n \n \n \n \n \n \nVerify single 111 is\n \n \n \nstabbing guide.', 'located in WC 203.', 'Continue RN 151\n \n \n \n \n \n \n \n \n \nsequence.', '6.\n \nDriller\n \nStab tubular 111:\n \nVisual/\n \nTD 116 link tilt float.', 'Lower TD 116 to stab\n \nCCTV\n \nRN 151 in WC 203\n \n \n \n \n \n \n \ntubular 111.\n \n \nwith stabbing guide\n \n \n \n \n \n \n \n \n \nclosed.', '6.1.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \nRN 151 stabbing\n \n \nLSA 228 to\n \n \n \n \nHandler\n \n228.\n \nCCTV\n \nguide closed.', 'Open status.', '6.2.\n \nPipe\n \nRN 151 spin-in and\n \nVisual/\n \nSingle 111 stabbed\n \nRN 151 will\n \nTally update.', 'Handler\n \nmake-up:\n \nCCTV\n \nin stick-up.', 'automatically spin-in\n \nTorque log\n \n \n \n \n \nContinue RN 151\n \n \nTD 116 unloaded,\n \nand make-up.\n \nupdated.\n \n \n \n \n \nsequence.', 'elevator 129 below TJ\n \nOpen RN 151\n \nMU torque\n \n \n \n \n \n \n \nto permit spinning.', 'spinner, guide, and\n \npresented to\n \n \n \n \n \n \n \n \nclamps.\n \nDriller.\n \n \n \n \n \n \n \n \nReturn RN 151 to\n \n \n \n \n \n \n \n \n \npark position.', '7.\n \nDriller\n \nOpening slips 161:\n \nVisual\n \nElevator 129 must be\n \n \nSlips 161 to\n \n \n \n \n \nOpen slips 161\n \n \nclosed.', 'Open state.', '(command).', 'RN 151 has\n \n \nDW 119 load.', 'Hoist to open slips\n \n \ncompleted MU\n \n \n \n \n \n \n \n161.\n \n \nsequence with correct\n \n \n \n \n \n \n \n \n \ntorque.', '8.\n \nDriller\n \nLower drill string 120:\n \nVisual\n \nSlips 161 open.', 'Verify slips 161 are\n \n \n \n \n \n \n \n \n \nopen before lowering\n \n \n \n \n \n \n \n \n \ndrill string 120.\n \n \n \n \n \n \n \n9.\n \nDriller\n \nSet slips 161:\n \nVisual\n \nStick-up at correct\n \n \nSlips 161 to\n \n \n \n \n \nSet slips 161 at\n \n \nheight.', 'Closed state.', 'correct stick-up height.', 'DW 119 load\n \n \n \n \n \nSet-off weight.', 'indicator.', 'Tally update.', '10.\n \nDriller\n \nCheck trip tank\n \nVisual\n \n \nTrip tank gain is\n \nVolume control.', 'volume, gain/loss.\n \n \n \ndetermined and\n \n \n \n \n \n \n \n \n \ndisplayed.', '11.\n \n \nRepeat sequence for\n \n \n \n \n \n \n \n \n \nnext single 111.', 'Different combinations of the aspects described above may also be utilized for laying down single tubulars \n111\n from WC \n203\n using the top drive \n116\n.', 'Such operations may be performed during drilling and other operations performed at WC \n203\n.', 'Such simultaneous operations, however, are coordinated to avoid conflicts and obstructions between the different machines and systems.', 'Preparations for this lay-down operation may include the examples set forth below in Table 7A.\n \n \n \n \n \n \n \n \nTABLE 7A\n \n \n \n \n \n \n \n \nPreparations for Singles Lay-Down from WC to CW with TD\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nCW 131\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Feeding table (FT) indexer pins adjusted for pipe size.', 'Prepare for lay-down tubulars 111.', 'Adjust skate 133 and other aspects of CW 131 for tubulars 111.\n \n \n \nRN 151\n \nOperator 195 on\n \nDPT is rigged up in THT.', '(THT + DPT)\n \nrig floor 114.', 'Travel path is unobstructed.', 'Dies are clean and not worn.', 'THT + Mud\n \nOperator 195 on\n \nMB is connected.', 'bucket (MB)\n \nrig floor 114.', 'Inserts are correct size, not worn or damaged.', 'Travel path is unobstructed.', 'LSA 228\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Slips 161\n \nOperator 195 on\n \nCorrect inserts in slips 161.\n \n \n \n \nrig floor 114.', 'Dies are clean and not worn.', 'Rotary table rotation lock activated.', 'Pipe viper mounted inside or on top of slips 161.\n \n \n \nTD 116\n \nOperator 195 on\n \nCorrect inserts in elevator 129.\n \n \n \n \nrig floor 114.\n \nElevator rotator (tilt) installed.', 'Operator screen, system status.', 'Travel path is unobstructed.', 'DW 119\n \nOperator 195 on\n \nChecked.\n \n \n \n \nrig floor 114.\n \n \n \nTubulars\n \nOperator 195 on\n \nTubular 111 to be loaded on FT.\n \n \n \n111\n \nrig floor 114.', 'The well construction system \n100\n, \n200\n can then be set-up for the pick-up operation.', 'Examples of such set-up may be as set forth below in Table 7B.\n \n \n \n \n \n \n \n \nTABLE 7B\n \n \n \n \n \n \n \n \nSet-Up for Singles Lay-Down from WC to CW with TD\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'LSA 228,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nRN 151,\n \n \nequipment.', 'Program setup\n \n \n \nCW 131\n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Trip Out mode.', 'for green light in\n \n \n \n \n \nSelect target: CW 131\n \nConstruction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nSelect pipe size/type.', 'screen 532, 534,\n \n \n \n \n \nSelect MB (THA), if applicable.\n \n536.', 'Select RN 151 to use in the operations.', 'RN 151 MU torque.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nDW 119,\n \n \ncompleted pre-checks and deactivated\n \nscreen.\n \n \n \nMP 144,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nTrip tank\n \n \nequipment.', 'Program setup\n \n \n \n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Trip Out mode.', 'for green light in\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \n \n \nStick-up target.', 'header on front\n \n \n \n \n \nSet DW 119 upper/lower stops.', 'screen 532, 534,\n \n \n \n \n \nSet maximum hoisting speed.', '536.', 'Set maximum pull/overpull.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator\n \n \n \n \n \ncompleted pre-checks.\n \nscreen, system\n \n \n \n \n \nActivate TD 116 from touchscreen 522,\n \nstatus/alarms.', '524.\n \n \n \n \n \nVerify correct elevator 129 setting\n \n \n \n \n \n(manual/remote).', 'Select Operation screen on touchscreen 522,\n \n \n \n \n \n524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator\n \n \n \n \n \n524.\n \nscreen, system\n \n \n \n \n \n \nstatus/alarms.', 'Slips 161,\n \nDriller\n \nVerify correct setting for slips 161\n \nVerify operator\n \n \n \nRotary\n \n \n(manual/remote).', 'screen, system\n \n \n \ntable\n \n \n \nstatus/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nAll types of tubulars 111 are registered.', 'Verify operator\n \n \n \n111\n \nHandler\n \n \nscreen, system\n \n \n \n \n \n \nsettings.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'This sequence may start with the top drive \n116\n in lower position at WC \n203\n with the elevator \n129\n closed, with the slips \n161\n closed, and with the catwalk ramp \n149\n empty and in rig floor \n114\n loading position (ready to move to the rig floor \n114\n).', 'The catwalk feeding table may be unloaded and ready to receive tubulars \n111\n, and the TDA \n202\n may be parked outside of the potential collision area.', 'Example steps of the sequence may be as set forth below in Table 7C.\n \n \n \n \n \n \n \n \nTABLE 7C\n \n \n \n \n \n \n \n \nSequence for Set-Up for Singles Lay-Down from WC to CW with TD\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nOpen slips 161 and\n \nVisual/\n \nElevator 129 must be\n \nSlips 161 Open not\n \nSlips 161 to\n \n \n \n \n \nhoist drill string 120:\n \nCCTV\n \nclosed before opening\n \nselectable if elevator\n \nOpen state.', 'Verify elevator 129 is\n \n \nslips 161.\n \n129 is not closed.', 'Settings: DW\n \n \n \n \n \nclosed.', 'Slips 161 Open\n \n119 hoisting\n \n \n \n \n \nOpen slips 161\n \n \n \ncommand is reset\n \nspeed and\n \n \n \n \n \n(command).', 'after a preset time if\n \nmaximum\n \n \n \n \n \nHoist to take weight\n \n \n \nslips 161 are not\n \noverpull.\n \n \n \n \n \nand verify slips 161\n \n \n \nopened.', 'opening.', 'Hoist one single 111.\n \n \n \n \n \n \n \n \n \nStop with required\n \n \n \n \n \n \n \n \n \nstick-up.\n \n \n \n \n \n \n \n1.1.', 'Pipe\n \nTilt ramp 149 and\n \nVisual/\n \nTubular 111 loaded\n \nSkate 133 will tilt\n \nCW 131 lay-\n \n \n \n \nHandler\n \nmove skate 133 to lay-\n \nCCTV\n \nonto Ramp 149.\n \nto WC 203\n \ndown ready.', 'down position:\n \n \n \n(straight).', 'Verify tubular 111 is\n \n \n \nCW 131 will\n \n \n \n \n \n \nunloaded from ramp\n \n \n \nmove to lay-down\n \n \n \n \n \n \n149 (CW 131 ready).\n \n \n \nposition.', 'Activate CW 131\n \n \n \n \n \n \n \n \n \nsequence.', '2.\n \nDriller\n \nSet slips 161:\n \nVisual/\n \n \n \nDW 119 upper\n \n \n \n \n \nVerify required stick-\n \nCCTV\n \n \n \nstop setting.', 'up height.', 'Slips 161 to\n \n \n \n \n \nSet slips 161\n \n \n \n \nClosed state.', '(command).', 'Set-off weight.\n \n \n \n \n \n \n \n2.1.', 'Pipe\n \nMove RN 151 to WC\n \n \nRN 151 tongs open.', 'RN 151 will move to\n \nTJ (stick-up)\n \n \n \n \nHandler\n \n203:\n \n \nWC 203 selected.', 'WC 203.', 'assist indication.', 'Verify TD 116 is\n \n \nLSA 228 outside\n \nElevate RN 151 to\n \nRN 151 in WC\n \n \n \n \n \nhoisted above RN 151\n \n \nworking area.', 'stick-up.', '203.\n \n \n \n \n \nworking area.', 'Activate RN 151 BUC\n \nRN 151 BUC\n \n \n \n \n \nStart RN 151 break-\n \n \n \nand position tong\n \nto Closed state.\n \n \n \n \n \nout sequence to move\n \n \n \n(when slips 161\n \n \n \n \n \n \nRN 151 to WC 203.\n \n \n \nclosed).', 'RN 151 will stop/wait\n \n \n \n \n \n \n \n \n \noutside WC 203 area if\n \n \n \n \n \n \n \n \n \nTD 116 is moving.\n \n \n \n \n2.2.', 'Pipe\n \nLSA 228 move to WC\n \nVisual/\n \nTD 116 above\n \nLSA 228 will stop/wait\n \nLSA 228 funnel\n \n \n \n \nHandler\n \n203:\n \nCCTV\n \nworking area.', 'outside WC 203 area\n \nto Closed state.', 'Verify TD 116 is\n \n \nRN 151 outside\n \nif TD 116 is moving.\n \n \n \n \n \n \nhoisted above LSA 228\n \n \nworking area.', 'working area.', 'LSA 228 move to WC\n \n \n \n \n \n \n \n \n \n203.', 'LSA 228 guide funnel\n \n \n \n \n \n \n \n \n \ncloses.', '2.3.', 'Pipe\n \nRN 151 break-out and\n \nCCTV\n \nSlips 161 closed.', 'Break-out and spin-\n \nRN 151\n \n \n \n \nHandler\n \nspin-out:\n \n \n \nout.', 'Double break-out\n \noperation\n \n \n \n \n \nVerify slips 161\n \n \n \navailable if required\n \nstatus.', 'closed and weight set-\n \n \n \n(per set-up).', 'off.', 'Open RN 151\n \n \n \n \n \n \nAdjust RN 151\n \n \n \nspinner, guide, and\n \n \n \n \n \n \nelevation if required.\n \n \n \nclamps.', 'Continue RN 151\n \n \n \nReturn RN 151 to\n \n \n \n \n \n \nsequence.', 'park position.', 'Option: RN 151 will\n \n \n \n \n \n \n \n \n \nwait in WC 203 until\n \n \n \n \n \n \n \n \n \nTDA 202 has lifted the\n \n \n \n \n \n \n \n \n \nstand.', '2.4.\n \nPipe\n \nOption: Wet tubular\n \nVisual\n \nRN 151 sequence\n \n \nMB to WC 203.', 'Handler\n \n111:\n \n \nfinished.', 'Verify RN 151 is out\n \n \nLSA 228 above\n \n \n \n \n \n \n \nof working area.', 'THA/MB working\n \n \n \n \n \n \n \nExtend MB to WC\n \n \narea.', '203.', 'Close MB.', 'Driller\n \nDW 119 hoist to drain\n \n \n \n \nMB to Closed', 'tubular 111.\n \n \n \n \nstate.', 'Pipe\n \nOpen and retract MB.', 'MB to Open\n \n \n \n \nHandler\n \n \n \n \n \nstate\n \n \n \n3.', 'Driller\n \nTD 116 and LSA 228\n \nVisual/\n \nElevator 129 closed.', 'TD 116\n \n \n \n \n \nmove tubular 111 from\n \nCCTV\n \nSlips 161 closed.', 'retracted\n \n \n \n \n \nWC 203 to CW 131:\n \n \n \n \nposition.', 'Verify connection is\n \n \n \n \n \n \n \n \n \nspun-out.', 'Hoist TD 116 to lift\n \n \n \n \n \n \n \n \n \ntubular 111 from stick-\n \n \n \n \n \n \n \n \n \nup to above CW 131.', 'Tilt TD 116 links\n \n \n \n \n \n \n \n \n \ntoward CW131 (guided\n \n \n \n \n \n \n \n \n \nby LSA 228).', '3.1.\n \nPipe\n \nLSA 228 will guide\n \nVisual/\n \nCW 131 in lay-down\n \n \nLSA 228\n \n \n \n \nHandler\n \ntubular 111 pin to CW\n \nCCTV\n \nposition.\n \n \nposition.', '131:\n \n \n \n \n \n \n \n \n \nVerify pin end is\n \n \n \n \n \n \n \n \n \nabove CW 131.', 'Guide pin end to\n \n \n \n \n \n \n \n \n \nabove skate 133.\n \n \n \n \n \n \n \n4.\n \nDriller\n \nSet tubular 111 on CW\n \nVisual/\n \nCW 131 in lay-down\n \nSkate 133 will move\n \n \n \n \n \n \n131:\n \nCCTV\n \nposition.', 'out as TD 116 lowers.', 'Verify elevator 129 is\n \n \n \n \n \n \n \n \n \ntilted toward CW 131.', 'Lower TD 116 and\n \n \n \n \n \n \n \n \n \nset tubular 111 pin on\n \n \n \n \n \n \n \n \n \nskate 133.\n \n \n \n \n \n \n \n \n \nContinue lowering\n \n \n \n \n \n \n \n \n \nuntil tubular 111 rests\n \n \n \n \n \n \n \n \n \non CW 131.\n \n \n \n \n \n \n \n4.1.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \n \n \nLSA 228 to\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \n \n \nOpen state.\n \n \n \n \n \nVerify tubular 111 pin\n \n \n \n \n \n \n \n \n \nis resting in CW 131.', 'Open and retract LSA\n \n \n \n \n \n \n \n \n \n228.\n \n \n \n \n \n \n \n5.\n \nDriller\n \nLay down tubular 111\n \nVisual/\n \n \nSkate 133 will move\n \n \n \n \n \n \non CW 131 and open\n \nCCTV\n \n \nout as TD 116 lowers.', 'elevator 129:\n \n \n \n \n \n \n \n \n \nVerify elevator 129 is\n \n \n \n \n \n \n \n \n \ntilted toward CW 131\n \n \n \n \n \n \n \n \n \nand LSA 228 is out of\n \n \n \n \n \n \n \n \n \nTD 116 area.', 'Lower TD 116 until\n \n \n \n \n \n \n \n \n \ntubular 111 rests on\n \n \n \n \n \n \n \n \n \nramp 149.\n \n \n \n \n \n \n \n6.\n \nDriller\n \nOpen elevator 129:\n \nVisual\n \n \n \nElevator 129 to\n \n \n \n \n \nVerify tubular 111 is\n \n \n \n \nOpen state.', 'resting on CW 131.', 'Open elevator 129.', 'Tilt TD 116 links back\n \n \n \n \n \n \n \n \n \n(link tilt float).', '6.1.\n \nPipe\n \nMove tubular 111 to FT\n \nVisual/\n \nElevator 129 open.', 'Skate 133 will pull\n \nSkate 133 to\n \n \n \n \nHandler\n \nand unload:\n \nCCTV\n \n \ntubular 111 to\n \nunloading\n \n \n \n \n \nActivate CW 131\n \n \n \nunloading position.\n \nposition.\n \n \n \n \n \nsequence to move out\n \n \n \nRamp 149 will tilt to\n \nCW 131 to\n \n \n \n \n \nand unload tubular\n \n \n \nunloading position.', 'unloading\n \n \n \n \n \n111.', 'FT will unload\n \nposition.', 'Continue step 1.1.', 'tubular 111.', 'FT unloading\n \n \n \n \n \n \n \n \n \nactive.', '7.\n \nDriller\n \nLower TD 116 to stick-\n \nVisual\n \n \n \nElevator 129 to\n \n \n \n \n \nup and close elevator\n \n \n \n \nClosed state.', '129:\n \n \n \n \n \n \n \n \n \nTD 116 links are tilted\n \n \n \n \n \n \n \n \n \nback to clear stick-up\n \n \n \n \n \n \n \n \n \n(or retract TD 116 with\n \n \n \n \n \n \n \n \n \nvertical links).', 'Lower TD 116 to\n \n \n \n \n \n \n \n \n \nstick-up.', 'Tilt links (or extend\n \n \n \n \n \n \n \n \n \nTD 116) to close\n \n \n \n \n \n \n \n \n \nelevator 129.\n \n \n \n \n \n \n \n8.\n \nDriller\n \nCheck trip tank\n \nVisual\n \n \nTrip tank gain/loss is\n \nTrip Sheet/\n \n \n \n \n \nvolume, gain/loss:\n \n \n \ndetermined and\n \nVolume control.', 'Trip tank gain/loss.\n \n \n \ndisplayed.', 'Repeat all steps for\n \n \n \n \n \n \n \n \n \nnext tubular 111.', 'Continue on step 1.\n \n \n \n \n \n \n \n \n \n \nDifferent combinations of the aspects described above may also be utilized for running casing from the CW \n131\n with a casing tong (CTO).', 'Preparations for such operation may include the examples set forth below in Table 8A.\n \n \n \n \n \n \n \n \nTABLE 8A\n \n \n \n \n \n \n \n \nPreparations for Running Casing from CW with CTO\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nCW 131\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Casings are laid out correct with aft end in line with skate 133\n \n \n \n \n \nfor correct loading.', 'Prepare to pick up casing.', 'CTO:', 'Operator 195 on\n \nCTO is rigged up in THA (or THT).', 'THA + CTO\n \nrig floor 114.', 'Correct adapters and stabbing guide funnel installed.', 'as primary,\n \n \nDies are correct, clean, and not worn.', 'THT + CTO\n \n \nTravel path is unobstructed.', 'as backup\n \n \n \nLSA 228\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Slips 161\n \nOperator 195 on\n \nCorrect inserts in slips 161.', 'Rotary\n \nrig floor 114.', 'Dies are clean and not worn.', 'Table\n \n \nRotary table rotation lock activated.', 'TD 116\n \nOperator 195 on\n \nCorrect inserts in elevator 129.\n \n \n \n \nrig floor 114.', 'Elevator rotator (tilt) installed.', 'Operator screen, system status.', 'Travel path is unobstructed.', 'DW 119\n \nOperator 195 on\n \nChecked.\n \n \n \n \nrig floor 114.\n \n \n \nTubulars\n \nOperator 195 on\n \nTubulars 111 to be laid out on CW 131.\n \n \n \n111\n \nrig floor 114.', 'Tubulars 111 to be cleaned and doped, protectors removed\n \n \n \n \n \n(other implementations may be used for casing with protectors).', 'Casings measured, marked, and tally updated.', 'The well construction system \n100\n, \n200\n can then be set-up for the operation.', 'Examples of such set-up may be as set forth below in Table 8B.\n \n \n \n \n \n \n \n \nTABLE 8B\n \n \n \n \n \n \n \n \nSet-Up for Running Casing from CW with CTO\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'LSA 228,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nCTO,\n \n \nequipment.', 'Program setup\n \n \n \nCW 131\n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Running Casing from CW with CTO\n \nfor green light in\n \n \n \n \n \nmode.', 'Construction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nSelect casing type and verify casing\n \nscreen 532, 534,\n \n \n \n \n \ndata (size, weight, MU loss, torque\n \n536.\n \n \n \n \n \nsettings, weight, etc.).', 'Select CTO to use in the operations.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nDW 119,\n \n \ncompleted pre-checks and deactivated\n \nscreen.', 'MP 144\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \n \n \nequipment.', 'Program setup\n \n \n \n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Running Casing from CW with CTO\n \nfor green light in\n \n \n \n \n \nmode.', 'Construction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nStick-up target.', 'screen 532, 534,\n \n \n \n \n \nSet DW 119 upper/lower stops.', '536.', 'Set maximum lowering speed.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Verify active tanks are selected and\n \n \n \n \n \nlined up.', 'Select MP 144 (to fill casing, optional).', 'Verify MP 144 pressure limit setting.', 'Assign pumps to master slider.', 'Set number of strokes and SPM to fill\n \n \n \n \n \ncasing (optional).', 'Set ramp-up parameters.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator\n \n \n \n \n \ncompleted pre-checks.\n \nscreen, system\n \n \n \n \n \nActivate TD 116 from touchscreen 522,\n \nstatus/alarms.', '524.\n \n \n \n \n \nVerify correct elevator 129 setting\n \n \n \n \n \n(manual/remote).', 'Select Operation screen on touchscreen 522,\n \n \n \n \n \n524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator\n \n \n \n \n \n524.\n \nscreen, system\n \n \n \n \n \nSet maximum lowering speed.', 'status/alarms.', 'Set minimum slack off weight.', 'Slips 161,\n \nDriller\n \nVerify correct setting for slips 161\n \nVerify operator\n \n \n \nRotary\n \n \n(manual/remote).', 'screen, system\n \n \n \ntable\n \n \n \nstatus/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nAll types of tubulars 111 are registered.', '111\n \nHandler\n \n \n \n \n \n \n \n \n \n \nAfter such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example of this sequence may start with a casing stick-up at WC \n203\n, with the slips \n161\n and the TD \n116\n elevator \n129\n closed.', "Casing may be laid out on the CW \n131\n casing side (e.g., Driller's side), having been cleaned, doped, and tallied, and with protectors removed.", 'The catwalk ramp \n149\n may be empty and in the loading position.', 'Example steps of the sequence may be as set forth below in Table 8C.\n \n \n \n \n \n \n \n \nTABLE 8C\n \n \n \n \n \n \n \n \nSequence for Running Casing from CW with CTO\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.1.', 'Pipe\n \nLoad casing into ramp\n \nVisual/\n \nCasing ready in\n \n \n \n \n \n \nHandler\n \n149:\n \nCCTV\n \nloading position.', 'Use loading fingers to\n \n \nCW 131 in loading\n \n \n \n \n \n \n \nload casing into ramp\n \n \nposition.\n \n \n \n \n \n \n \n149.\n \n \n \n \n \n \n \n1.2.', 'Pipe\n \nRun ramp 149 to rig\n \nVisual/\n \nCasing loaded onto\n \nRamp 149 will tilt to\n \nCW 131\n \n \n \n \nHandler\n \nfloor 114:\n \nCCTV\n \nramp 149.\n \nrig floor 114 casing\n \nanimated.', 'Verify casing is\n \n \n \nposition.', 'loaded in ramp 149.', 'Skate 133 will move\n \n \n \n \n \n \nMove ramp 149\n \n \n \ntowards rig floor 114.\n \n \n \n \n \n \ntoward pick-up\n \n \n \nSkate 133 will stop\n \n \n \n \n \n \nposition.\n \n \n \nwith casing box inside\n \n \n \n \n \n \n \n \n \nramp.', '2.\n \nDriller\n \nOpen elevator 129:\n \nVisual/\n \nSlips 161 must be\n \nElevator 129 Open not\n \nElevator 129 to\n \n \n \n \n \nVerify slips 161 are\n \nCCTV\n \nclosed before opening\n \nselectable if slips 161\n \nOpen state.', 'closed.', 'elevator 129.\n \nare not closed.', 'Open elevator 129.', '3.\n \nDriller\n \nMove TD 116 to CW\n \nVisual\n \nElevator 129 open.', 'TD 116 pipe handler\n \n \n \n \n \n \n131 pick-up position:\n \n \nElevator 129 rotated\n \nhas pre-set position\n \n \n \n \n \n \nTilt links to clear TJ.\n \n \nto receive casing.\n \nfacing CW 131.', 'Hoist elevator 129\n \n \n \n \n \n \n \n \n \nabove stick-up.', 'Tilt out elevator 129\n \n \n \n \n \n \n \n \n \nand run TD 116 to CW\n \n \n \n \n \n \n \n \n \n131 pick-up position.\n \n \n \n \n \n \n \n3.1.', 'Pipe\n \nPush casing to pick-up\n \nVisual\n \nRamp 149 in rig floor\n \nSkate 133 will push\n \nCW 131 in pick-\n \n \n \n \nHandler\n \nposition:\n \n \n114 position.', 'casing a defined\n \nup position.', 'Run skate 133 until\n \n \n \ndistance forward.', 'casing is positioned\n \n \n \n \n \n \n \n \n \nabove elevator 129.', '4.\n \nDriller\n \nLatch elevator 129:\n \nVisual\n \nCasing is positioned\n \nElevator 129 close on\n \nElevator 129 to\n \n \n \n \n \nHoist/tilt TD 116 to\n \n \ncorrectly above\n \nmechanical impact.', 'Closed state.', 'latch elevator 129.\n \n \nelevator 129.', 'Tubular interlock\n \n \n \n \n \n \n \n \n \nprevents hoisting\n \n \n \n \n \n \n \n \n \nwithout closed elevator\n \n \n \n \n \n \n \n \n \n129 (above certain\n \n \n \n \n \n \n \n \n \nheight).', '5.\n \nDriller\n \nLift casing:\n \nVisual\n \nElevator 129 closed.', 'Hoisting will stop prior\n \n \n \n \n \n \nHoist TD 116 to pick\n \n \nLink tilt float: Elevator\n \nto lifting casing out of\n \n \n \n \n \n \nup casing from CW\n \n \n129 above RN 151\n \nCW 131 without\n \n \n \n \n \n \n131.\n \n \nworking area.', 'guiding.', 'Activate link tilt float\n \n \n \n \n \n \n \n \n \nto move elevator 129\n \n \n \n \n \n \n \n \n \nto vertical position.', '5.1.', 'Pipe\n \nLSA 228 extend to\n \nVisual/\n \nTD 116 above LSA 228\n \n \nLSA 228 funnel\n \n \n \n \nHandler\n \nguide casing above\n \nCCTV\n \noperating area.', 'to Closed state.', 'CW 131:\n \n \n \n \n \n \n \n \n \nMove LSA 228 to\n \n \n \n \n \n \n \n \n \npreset position to\n \n \n \n \n \n \n \n \n \nreceive casing above\n \n \n \n \n \n \n \n \n \nCW 131.', 'Before casing lower\n \n \n \n \n \n \n \n \n \nend leaves CW 131,\n \n \n \n \n \n \n \n \n \nclose LSA 228 funnel.\n \n \n \n \n \n \n \n5.2.\n \nPipe\n \nOption: Move\n \n \nOnly possible with\n \nCTO will move to WC\n \nTHT in WC 203.', 'Handler\n \nTHT/CTO to WC 203:\n \n \nTHT.', 'If THA is used,\n \n203.\n \n \n \n \n \n \nVerify TD 116 hoisted\n \n \nwait for stand located\n \nElevate to stick-up.\n \n \n \n \n \n \nabove CTO working\n \n \nabove stick-up.', 'ZMS will prevent\n \n \n \n \n \n \narea.', 'CTO open.', 'CTO start if TD 116 is\n \n \n \n \n \n \nStart CTO sequence\n \n \nWC 203 selected.', 'too low.\n \n \n \n \n \n \nto move THT to WC\n \n \n \n \n \n \n \n \n \n203.', '5.3.', 'Pipe\n \nLSA 228 tail in casing\n \nVisual\n \nCasing bottom clear\n \nLSA 228 centralizer\n \nLSA 228\n \n \n \n \nHandler\n \nto WC 203:\n \n \nof CW 131 and\n \nwill close when casing\n \ncentralizer to\n \n \n \n \n \nTD 116 continues\n \n \nelevated above stick-\n \nnears WC 203.', 'Closed state.\n \n \n \n \n \nhoisting.', 'up.', 'LSA 228 guide closes\n \n \nLSA 228 centralizer\n \n \n \n \n \n \n \nand tail in casing\n \n \ncloses when casing\n \n \n \n \n \n \n \ntowards WC 203 when\n \n \nnears vertical.', 'pin end is above stick-\n \n \n \n \n \n \n \n \n \nup.', '5.4.\n \nPipe\n \nMove THA/CTO to WC\n \n \nCTO open.', 'CTO will move to WC\n \nTHA/CTO in\n \n \n \n \nHandler\n \n203:\n \n \nWC 203 selected.\n \n203.\n \nWC 203.', 'Verify casing is in WC\n \n \nLSA 228 in WC 203.', 'Elevate to stick-up.\n \n \n \n \n \n \n203 and LSA 228 is\n \n \n \nZMS will prevent\n \n \n \n \n \n \nabove CTO working\n \n \n \nCTO start if TD 116 or\n \n \n \n \n \n \narea.', 'LSA 228 is too low.', 'Start CTO sequence\n \n \n \n \n \n \n \n \n \nto move THT to WC\n \n \n \n \n \n \n \n \n \n203.\n \n \n \n \n \n \n \n5.5.', 'Pipe\n \nClose CTO BUT:\n \nVisual/\n \nCTO in WC 203.', 'Close CTO BUT.', 'CTO to closed\n \n \n \n \nHandler\n \nAdjust/verify correct\n \nCCTV\n \n \nClose stabbing guide.', 'state.', 'CTO elevation.', 'Continue CTO\n \n \n \n \n \n \n \n \n \nsequence.', '5.6.', 'Pipe\n \nOptional: Close make-\n \nVisual/\n \nCTO in WC 203.', 'Close MUST.', 'MUST to\n \n \n \n \nHandler\n \nup spinning tong\n \nCCTV\n \n \nMUST will take some\n \nClosed state.', '(MUST) for soft\n \n \n \nload if closed prior to\n \n \n \n \n \n \nstabbing:\n \n \n \nstabbing casing.', 'Adjust CTO elevation\n \n \n \n \n \n \n \n \n \nand TD 116 elevation if\n \n \n \n \n \n \n \n \n \nrequired.', 'Continue CTO\n \n \n \n \n \n \n \n \n \nsequence.', '6.\n \nDriller\n \nStab casing:\n \nVisual/\n \nTD 116 link tilt float.', 'Weight transferred to\n \nCTO to open\n \n \n \n \n \nLower TD 116 to stab\n \nCCTV\n \nCTO in WC 203 with\n \nMUST per casing data\n \nstate.', 'casing (soft stab).', 'stabbing guide closed.\n \ninput.', 'Open CTO stabbing\n \n \n \n \n \n \n \n \n \nguide.', '6.1.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \nCTO stabbing guide\n \n \nLSA 228 Open\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \nclosed.\n \n \nstatus.', 'Open and retract LSA\n \n \n \n \n \n \n \n \n \n228 when casing has\n \n \n \n \n \n \n \n \n \nentered stabbing guide.', '6.2.\n \nPipe\n \nCTO spin-in and make-\n \nVisual/\n \nSingle casing stabbed\n \nCTO will\n \nCasing\n \n \n \n \nHandler\n \nup:\n \nCCTV\n \nin stick-up.', 'automatically spin-in\n \nconnected state.', 'Verify casing is\n \n \nTD 116 unloaded,\n \nand make-up per\n \n \n \n \n \n \nstabbed.', 'elevator 129 below TJ\n \ncasing data settings.', 'Continue CTO\n \n \nto permit spinning.', 'If Accept: Open\n \n \n \n \n \n \nsequence.\n \n \n \nspinner, guide, and\n \n \n \n \n \n \nAccept or reject\n \n \n \nclamps.\n \n \n \n \n \n \nmake-up.\n \n \n \nReturn to park\n \n \n \n \n \n \n \n \n \nposition.\n \n \n \n \n7.\n \nDriller\n \nOpen slips 161:\n \nVisual\n \nElevator 129 must be\n \n \nSlips 161 to\n \n \n \n \n \nOpen slips 161\n \n \nclosed.', 'Open state.', '(command).', 'CTO has completed\n \n \nDW 119 load.', 'Hoist to open slips\n \n \nMU sequence with\n \n \n \n \n \n \n \n161.\n \n \naccepted connection.', '8.\n \nDriller\n \nLower casing string:\n \nVisual\n \nSlips 161 open.', 'Optional: Selected MP\n \nMP 144\n \n \n \n \n \nVerify slips 161 are\n \n \nOptional: MP 144\n \n144 will pump a set\n \nstrokes.', 'open before lowering\n \n \nready.', 'number of strokes at\n \nMP 144\n \n \n \n \n \ndrill string 120.\n \n \n \nset rate with selected\n \npressure.', 'Optional: Fill casing\n \n \n \nMP 144 and stop.', 'IBOP to Open\n \n \n \n \n \nvolume if selected.', 'state.', 'Extend fill-up tool, if\n \n \n \n \n \n \n \n \n \nmounted.', 'Open IBOP.', 'Start MP 144.', 'Close IBOP.', '9.\n \nDriller\n \nSet slips:\n \nVisual\n \nStick-up at correct\n \n \nSlips 161 to\n \n \n \n \n \nSet slips 161 at\n \n \nheight.', 'Closed state.', 'correct stick-up height.', 'DW 119 load\n \n \n \n \n \nSet-off weight.', 'indicator.', '10.\n \nDriller\n \nCheck gain/loss:\n \nVisual\n \n \nTrip tank or active\n \nVolume control.', 'Check trip tank gain/\n \n \n \ntank gain is\n \n \n \n \n \n \nloss or active gain/loss\n \n \n \ndetermined and\n \n \n \n \n \n \ndepending on selected\n \n \n \ndisplayed.\n \n \n \n \n \n \noperation.', '11.\n \n \nRepeat sequence for\n \n \n \n \n \n \n \n \n \nnext casing single.', 'When a tripping-out “wet” (while the drill string \n120\n is full of mud) operation is to be performed, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth below in Table 9A.\n \n \n \n \n \n \n \n \nTABLE 9A\n \n \n \n \n \n \n \n \nTripping-In Wet Preparations\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nFIB 166\n \nOperator 195 on rig floor 114.', 'Tubulars 111 exist per HMI/tally.', 'Setback 164\n \n \nFingers are closed.', 'Travel path is unobstructed.', 'TBR 254\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'SGA 262\n \n \nGripper inserts/dies are clean, not worn.', 'LTC 244\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'ITC 236\n \n \nGripper inserts/dies are clean, not worn.', 'UTC 242\n \n \nITC 236 is open and retracted.', 'THP\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'Doper 209\n \n \nWater, correct dope available for doper\n \n \n \n \n \n209.', 'LSA 228\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'TDA 202\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'Correct dope available for doper 209.', 'Correct inserts/dies in gripper/elevator.', 'Inserts/dies are clean, not worn.', 'RN 151\n \nOperator 195 on rig floor 114.', 'Drill pipe tong (DPT) is connected.', '(THT + DPT)', 'Gripper dies are clean, not worn.', 'Travel path is unobstructed.', 'THA + MB\n \nOperator 195 on rig floor 114; and/or\n \nMB is connected.', '“Driller” 195 at workstation 452.', 'Inserts correct size, not worn or\n \n \n \n \n \ndamaged.', 'Travel path is unobstructed.', 'Slips 161,\n \nOperator 195 on rig floor 114; and/or\n \nCorrect inserts/dies.', 'Rotary\n \n“Driller” 195 at workstation 452.', 'Inserts/dies are clean, not worn.', 'Table\n \n \nPipe viper mounted inside or on top of\n \n \n \n \n \nslips 161.\n \n \n \nTD 116\n \nOperator 195 on rig floor; and/or\n \nCorrect inserts/dies in elevator 129.', '“Driller” 195 at workstation 452.', 'Correct saver sub status.', 'Travel path is unobstructed.', 'DW 119\n \nOperator 195 on rig floor; and/or\n \nChecked.', '“Driller” 195 at workstation 452.', 'The well construction system \n100\n, \n200\n can then be set-up for the trip-out wet sequence.', 'Examples of such set-up may be as set forth below in Table 9B.\n \n \n \n \n \n \n \n \nTABLE 9B\n \n \n \n \n \n \n \n \nTripping-Out', 'Wet Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nDriller/\n \nVerify operator 195 on rig floor 114 completed\n \nVerify Setback\n \n \n \nhandling:\n \nPipe\n \npre-checks and deactivated emergency stop for\n \nscreen.', 'TBR 254,\n \nHandler\n \nall pipe handling equipment.', 'Construction\n \n \n \nSGA 262,\n \n \nOpen Construction Program screen on\n \nProgram\n \n \n \nUTC 242,\n \n \ntouchscreen 522, 524.\n \nsetup wizard.', 'LTC 244,\n \n \nSelect Trip Out Wet mode.', 'After startup:\n \n \n \nTHP 207,\n \n \nSelect setup wizard to open pop-up on front\n \nCheck for\n \n \n \nTDA 202,\n \n \nscreen 532, 534, 536.', 'Verify settings:\n \ngreen light in\n \n \n \nLSA 228,\n \n \nSelect slot, direction for storing tubulars 111.', 'Construction\n \n \n \nRN 151\n \n \nSelect pipe type.', 'Program\n \n \n \n \n \nSelect RN 151 (THT) to use, check MU\n \nstatus header\n \n \n \n \n \ntorque.', 'on front\n \n \n \n \n \nSelect MB (THA).', 'screen 532,\n \n \n \n \n \nSelect pin/box doping.', '534, 536.\n \n \n \n \n \nStick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114 completed\n \nVerify Setback\n \n \n \nDW 119,\n \n \npre-checks and deactivated emergency stop for\n \nscreen.\n \n \n \nMP 144,\n \n \nall pipe handling equipment.', 'Construction\n \n \n \nTrip tank\n \n \nOpen Construction Program screen on\n \nProgram\n \n \n \n \n \ntouchscreen 522, 524.\n \nsetup wizard.', 'Select Trip Out Wet mode.', 'After startup:\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nCheck for\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \ngreen light in\n \n \n \n \n \nStick-up target.', 'Construction\n \n \n \n \n \nSet DW 119 upper/lower stops.', 'Program\n \n \n \n \n \nSet maximum lowering speed.', 'status header\n \n \n \n \n \nSet over pull.', 'on front\n \n \n \n \n \nTrip tank 1/2/auto.\n \nscreen 532,\n \n \n \n \n \nTrip tank low/high levels.\n \n534, 536.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114 completed\n \nVerify operator\n \n \n \n \n \npre-checks.\n \nscreen, system\n \n \n \n \n \nActivate TD 116 from touchscreen 522, 524.\n \nstatus/alarms.', 'Select Operation screen on touchscreen 522,\n \n \n \n \n \n524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522, 524.\n \nVerify operator\n \n \n \n \n \n \nscreen, system\n \n \n \n \n \n \nstatus/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in zone\n \nVerify operator\n \n \n \nmachines\n \n \nmanagement system and tubular interlock\n \nscreen, system\n \n \n \n \n \nsystem.', 'status/alarms.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example trip-out wet sequence may start with the TD \n116\n in lower position over WC \n203\n with closed slips \n161\n and elevator \n129\n, with a stick-up of about one meter.', 'The TDA \n202\n and LSA \n228\n are open in THP \n207\n position (tubular \n111\n delivered from WC \n203\n to THP \n207\n).', 'The UTC \n242\n and LTC \n244\n are closed on the tubular \n111\n in the THP \n207\n, and the ITC \n236\n is open and retracted.', 'The TBR \n254\n and SGA \n262\n are empty, on the way from the FIB \n166\n to get a new tubular \n111\n in the THP \n207\n.', 'Example steps of the trip-out wet sequence may be as set forth below in Table 9C.\n \n \n \n \n \n \n \n \nTABLE 9C\n \n \n \n \n \n \n \n \nTripping-Out Wet Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nOpen slips 161 and\n \nVisual/\n \nElevator 129 must be\n \nSlips 161 Open is\n \nSlips 161 to\n \n \n \n \n \nhoist to upper stop:\n \nCCTV\n \nclosed before opening\n \nnot selectable if\n \nOpen state.', 'Verify elevator 129 is\n \n \nslips 161.\n \nelevator 129 is not\n \nSettings:\n \n \n \n \n \nclosed.\n \n \n \nclosed.', 'DW 119\n \n \n \n \n \nOpen slips 161\n \n \n \nSlips 161 Open\n \nhoisting\n \n \n \n \n \n(command).', 'command is reset\n \nspeed and\n \n \n \n \n \nHoist to take weight\n \n \n \nafter a set time if the\n \nmaximum\n \n \n \n \n \nand verify slips 161\n \n \n \nslips 161 are not\n \noverpull.', 'opening.\n \n \n \nopened.\n \n \n \n \n1.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA 262\n \n \nTBR 254 and\n \n \n \n \nHandler\n \npick up next tubular 111\n \nCCTV\n \nopen.', 'SGA 262 grips/\n \n \n \n \n \nfrom THP 207:\n \n \n \n \nguides to Closed\n \n \n \n \n \nTBR 254 and SGA 262\n \n \n \n \nstate.', 'move to tubular 111 in\n \n \n \n \n \n \n \n \n \nTHP 207.', 'Close TBR 254 and\n \n \n \n \n \n \n \n \n \nSGA 262 guides/clamps\n \n \n \n \n \n \n \n \n \non tubular 111.\n \n \n \n \n \n \n \n1.2.', 'Pipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA 262\n \nUTC 242 and LTC 244\n \nUTC 242 and\n \n \n \n \nHandler\n \nopen and retract:\n \nCCTV\n \nclosed on tubular 111\n \nopen and retract.', 'LTC 244 to Open\n \n \n \n \n \nUTC 242 and LTC\n \n \nin THP 207.\n \n \nstate - retracted.', '244 open.', 'UTC 242 and LTC\n \n \n \n \n \n \n \n \n \n244 retract from THP\n \n \n \n \n \n \n \n \n \n207.\n \n \n \n \n \n \n \n1.3.', 'Pipe\n \nTBR 254 and SGA 262', 'Visual/\n \nValid FIB 166 position\n \nTBR 254 and SGA\n \nTHP load.', 'Handler\n \nmove toward FIB 166\n \nCCTV\n \nselected.', '262 will follow\n \n \n \n \n \n \nwith tubular 111:\n \n \n \npredefined path.', 'Lift tubular 111 from\n \n \n \nFIB 166 latches will\n \n \n \n \n \n \nTHP 207.', 'open when tubular 111\n \n \n \n \n \n \nMove to selected\n \n \n \nis outside selected FIB\n \n \n \n \n \n \nposition in FIB 166.\n \n \n \n166 row.', 'FIB 166 latches will\n \n \n \n \n \n \n \n \n \nclose prior to setting\n \n \n \n \n \n \n \n \n \ndown tubular 111.', 'Set down tubular 111\n \n \n \n \n \n \n \n \n \non selected position.', '1.4.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \n \nTDA 202 retracts to\n \nTDA 202 load\n \n \n \n \nHandler\n \nmove to WC 203:\n \nCCTV\n \n \nvertical, hoists, and\n \nindication.', 'TDA 202 moves to\n \n \n \nrotates, extending to\n \n \n \n \n \n \nWC 203.', 'WC 203 at about two\n \n \n \n \n \n \nLSA 228 moves to\n \n \n \nmeters below stick-up.', 'WC 203.', 'TDA 202 and LSA\n \n \n \n \n \n \n \n \n \n228 will stop/wait\n \n \n \n \n \n \n \n \n \noutside WC 203 area\n \n \n \n \n \n \n \n \n \nif TD 116 is moving.', '1.5.\n \nPipe\n \nMove RN 151 to WC\n \n \nRN 151 tongs open.', 'RN 151 will move to\n \nTJ (Stick-up)\n \n \n \n \nHandler\n \n203:\n \n \nWC 203 selected.', 'WC 203.', 'assist indication.', 'Verify TD 116 is\n \n \n \nElevate RN 151 to\n \n \n \n \n \n \nhoisted above RN 151\n \n \n \nstick-up.\n \n \n \n \n \n \nworking area.', 'RN 151 will stop/\n \n \n \n \n \n \nStart 151 RN break-\n \n \n \nwait outside WC 203\n \n \n \n \n \n \nout sequence to move\n \n \n \narea if TD 116 is\n \n \n \n \n \n \nRN 151 to WC 203.\n \n \n \nmoving.', '2.\n \nDriller\n \nSet slips 161:\n \nVisual/\n \n \n \nDW 119 upper\n \n \n \n \n \nVerify required stick-up\n \nCCTV\n \n \n \nstop setting.', 'height.', 'Set slips 161\n \n \n \n \n \n \n \n \n \n(command).', 'Set off weight.\n \n \n \n \n \n \n \n2.1.', 'Pipe\n \nTDA 202 close and LSA\n \nVisual/\n \nSlips 161 closed.', 'TDA 202 and LSA 228\n \nTDA 202 to\n \n \n \n \nHandler\n \n228 guide close:\n \nCCTV\n \n \nwill not close in WC\n \nClosed state.', 'Verify TDA 202 and\n \n \n \n203 if slips 161 are not\n \nTDA 202 and\n \n \n \n \n \nLSA 228 at WC 203.\n \n \n \nclosed.', 'LSA 228 in WC\n \n \n \n \n \nClose TDA 202.\n \n \n \n \n203.', 'Close LSA 228 guide\n \n \n \n \nLSA 228 guide\n \n \n \n \n \nfunnel.\n \n \n \n \nfunnel to Closed\n \n \n \n \n \n \n \n \n \nstate.', '2.2.\n \nPipe\n \nRN 151 break-out and\n \nCCTV\n \nSlips 161 closed.', 'Break-out and spin-\n \nRN 151\n \n \n \n \nHandler\n \nspin-out:\n \n \n \nout.', 'Double break-out\n \nindication.', 'Verify slips 161 closed\n \n \n \navailable if required.\n \n \n \n \n \n \nand weight set off.', 'Open RN 151\n \n \n \n \n \n \nAdjust RN 151\n \n \n \nspinner, guide, and\n \n \n \n \n \n \nelevation if required.\n \n \n \nclamps.', 'Continue RN 151\n \n \n \nReturn RN 151 to\n \n \n \n \n \n \nsequence.', 'park position.', 'RN 151 may wait in\n \n \n \n \n \n \n \n \n \nWC 203 until TDA 202\n \n \n \n \n \n \n \n \n \nhas lifted tubular 111.', '3.\n \nDriller\n \nOpen TD elevator 129,\n \nVisual/\n \nTDA 202 closed.', 'TD elevator\n \n \n \n \n \nretract, and lower:\n \nCCTV\n \nSlips 161 closed.', '129 to Closed\n \n \n \n \n \nVerify TDA 202 is\n \n \n \n \nstate.\n \n \n \n \n \nclosed.', 'TD 116\n \n \n \n \n \nOpen TD elevator 129\n \n \n \n \nretracted\n \n \n \n \n \nand retract.\n \n \n \n \nposition.', 'Lower TD 116 (e.g., to\n \n \n \n \n \n \n \n \n \nrig floor 114.\n \n \n \n \n \n \n \n3.1.', 'Pipe\n \nMB (THA) extend to WC\n \nVisual/\n \nRN 151/THT\n \nMB will extend to\n \nMB in WC\n \n \n \n \nHandler\n \n203:\n \nCCTV\n \nretracted.\n \nWC 203 and close.', '203.', 'Verify THT is out of the\n \n \nMB open.', 'MB to Closed\n \n \n \n \n \narea.', 'state.', 'Continue MB\n \n \n \n \n \n \n \n \n \nsequence.\n \n \n \n \n \n \n \n3.2.', 'Pipe\n \nTDA 202 lift tubular 111\n \nVisual/\n \nRN 151 in parked\n \nTDA 202 will hoist\n \nTDA 202 load\n \n \n \n \nHandler\n \nout of stick-up:\n \nCCTV\n \nposition.', 'about two meters\n \nindication.', 'Hoist TDA 202 to pick\n \n \nMB in WC 203.', 'before lifting tubular\n \nTDA 202\n \n \n \n \n \nup weight.', 'TD 116 retracted.\n \n111.\n \nposition\n \n \n \n \n \nLSA 228 centralizer\n \n \n \nTubular 111 is lifted\n \nindicator.', 'will close on tubular 111\n \n \n \ncarefully.', 'Lifting is\n \nLSA 228\n \n \n \n \n \nabove stick-up.', 'stopped if tubular\n \ncentralizer.', 'Hold stand above\n \n \n \n111 is catching on\n \n \n \n \n \n \nstick-up until drained.\n \n \n \nthreads in TJ.', 'LSA 228 centralizer\n \n \n \n \n \n \n \n \n \ncloses after lifted\n \n \n \n \n \n \n \n \n \nabove the box.\n \n \n \n \n3.3.', 'Pipe\n \nMB open and retract:\n \nVisual/\n \n \nMB will open and\n \nMB to Closed\n \n \n \n \nHandler\n \nVerify tubular 111 is\n \nCCTV\n \n \nretract.\n \nstate.\n \n \n \n \n \ndrained.', 'MB parked.', 'Continue MB\n \n \n \n \n \n \n \n \n \nsequence.', '3.4.\n \nPipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTDA 202 closed.', 'TDA 202 will retract\n \nTDA 202 load\n \n \n \n \nHandler\n \nmove tubular 111 to\n \nCCTV\n \n \nto vertical position\n \nindication.', 'THP 207:\n \n \n \nabove MOH 204 (or\n \nTDA 202\n \n \n \n \n \nTDA 202 and LSA 228\n \n \n \nrig floor 114), then\n \nposition\n \n \n \n \n \nmove toward THP 207.\n \n \n \nrotate, lower, and\n \nindicator.', 'LTC 244 extends to\n \n \n \nextend to THP 207.', 'LSA 228\n \n \n \n \n \nTHP 207 and closes\n \n \n \nTDA 202 will slow\n \nextend.\n \n \n \n \n \nguide when tubular 111\n \n \n \ndown above THP\n \nLTC 244 to\n \n \n \n \n \nis close to THP 207.\n \n \n \n207.', 'Closed state.\n \n \n \n \n \nSet down tubular 111\n \n \n \nLTC 244 is extended\n \n \n \n \n \n \nat THP 207.\n \n \n \nand closed.', 'Wash and dope pin if\n \n \n \nLSA 228 is open.\n \n \n \n \n \n \npreselected.', '3.5.\n \nPipe\n \nUTC 242 extend to THP\n \nVisual/\n \nTDA 202 and LSA 228\n \nUTC 242 extend and\n \nUTC 242 and\n \n \n \n \nHandler\n \n207 and close.', 'CCTV\n \nin THP 207 with tubular\n \nclose.', 'LTC 244 to\n \n \n \n \n \nUTC 242 extends to\n \n \n111.', 'LTC 244 continue\n \nClosed state.', 'THP 207.\n \n \n \nclose.', 'UTC 242 and LTC 244\n \n \n \n \n \n \n \n \n \nclose.', '4.\n \nDriller\n \nExtend TD 116 and\n \nVisual\n \nRN 151 parked.', 'Elevator 129\n \n \n \n \n \nlatch elevator 129:\n \n \n \n \nto Closed state.', 'Extend TD 116 to WC\n \n \n \n \nIndicate TD\n \n \n \n \n \n203.\n \n \n \n \n116 in WC 203.', 'Latch elevator 129\n \n \n \n \n \n \n \n \n \n(automatic close on\n \n \n \n \n \n \n \n \n \nimpact).', '5.\n \nDriller\n \nCheck trip tank volume,\n \nVisual\n \n \nTrip tank gain/loss is\n \nTrip sheet/\n \n \n \n \n \ngain/loss:\n \n \n \ndetermined and\n \nvolume control.', 'Determine trip tank\n \n \n \ndisplayed.', 'gain/loss.', 'Repeat all steps for\n \n \n \n \n \n \n \n \n \nnext tubular 111.', 'Continue on step 1.\n \n \n \n \n \n \n \n5.1.', 'Pipe\n \nTDA 202 open and\n \nVisual/\n \nUTC 242 closed.', 'TDA 202 to\n \n \n \n \nHandler\n \nretract from THP 207:\n \nCCTV\n \n \n \nOpen state.', 'Verify UTC 242 and\n \n \n \n \nLSA 228 open.', 'LTC 244 are closed.', 'Open TDA 202.', 'Open LSA 228 guide\n \n \n \n \n \n \n \n \n \nfunnel.', 'Continue on step 1.4.\n \n \n \n \n \n \n \n5.2.', 'Pipe\n \nTBR 254 and SGA 262\n \n \nUTC 242 and LTC 244\n \n \n \n \n \n \nHandler\n \nmove to FIB 166:\n \n \nclosed on tubular 111.', 'Open TBR 254 and\n \n \n \n \n \n \n \n \n \nSGA 262.', 'Move TBR 254 and\n \n \n \n \n \n \n \n \n \nSGA 262 toward THP\n \n \n \n \n \n \n \n \n \n207/', 'next tubular 111.', 'Continue step 1.1.', 'When a back-reaming operation is to be performed, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth above in Table 9A.', 'The well construction system \n100\n, \n200\n can then be set-up for the back-reaming sequence.', 'Examples of such set-up may be as set forth below in Table 10A.\n \n \n \n \n \n \n \n \nTABLE 10A\n \n \n \n \n \n \n \n \nBack-Reaming Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nDriller/\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nPipe\n \ncompleted pre-checks and deactivated\n \nscreen.', 'TBR 254,\n \nHandler\n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nSGA 262,\n \n \nequipment.', 'Program setup\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \nwizard.', 'LTC 244,\n \n \ntouchscreen 522, 524.', 'After startup: Check\n \n \n \nITC 236,\n \n \nSelect Back-Reaming mode.', 'for green light in\n \n \n \nTHP 207,\n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \nTDA 202,\n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \nLSA 228,\n \n \nSelect slot, direction for setting back\n \nheader on front\n \n \n \nRN 151\n \n \npipe.', 'screen 532, 534,\n \n \n \n \n \nSelect pipe type.', '536.', 'Select RN 151 (THT) and MB (THA).', 'Check RN 151 MU torque.', 'Select pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nDW 119,\n \n \ncompleted pre-checks and deactivated\n \nscreen.', 'MP 144\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \n \n \nequipment.', 'Program setup\n \n \n \n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Drilling mode.', 'for green light in\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \n \n \nStick-up target.', 'header on front\n \n \n \n \n \nSet DW 119 upper/lower stops.', 'screen 532, 534,\n \n \n \n \n \nSet relevant Autodriller parameters\n \n536.', '(ROP, WOB, delta-P, torque, etc.)\n \n \n \n \n \nSet maximum pull.', 'Verify correct TD 116 MU torque\n \n \n \n \n \nsetting.', 'Verify correct drilling torque setting.', 'Verify spin-in speed and torque setting.', 'Verify spin-out time.', 'Verify MP 144 liner size setting and\n \n \n \n \n \nefficiency.', 'Verify MP 144 pressure limit setting.', 'Assign pumps to MP 144 master slider.', 'Verify/set MP 144 ramp-up parameters.', 'Verify active tanks are selected and\n \n \n \n \n \nlined up.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in\n \nVerify operator\n \n \n \nmachines\n \n \nzone management system and tubular\n \nscreen, system\n \n \n \n \n \ninterlock system.\n \nsettings.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example back-reaming sequence may start with the top drive \n116\n in lower position and retracted (with elevator links vertical), the slips \n161\n closed, and the TDA \n202\n and LSA \n228\n open in the THP \n207\n.', 'The UTC \n242\n and LTC \n244\n may be closed on a tubular \n111\n in the THP \n207\n, with the ITC \n236\n being open and retracted, and the TBR \n254\n and SGA \n262\n empty (on the way from the FIB \n166\n to get the next tubular \n111\n in the THP \n207\n).', 'Example steps of the back-reaming sequence may be as set forth below in Table 10B.\n \n \n \n \n \n \n \n \nTABLE 10B\n \n \n \n \n \n \n \n \nBack-Reaming Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.', 'Driller\n \nExtend TD 116, tilt up\n \nVisual\n \n \n \nTD 116 to WC\n \n \n \n \n \nlinks:\n \n \n \n \n203.\n \n \n \n \n \nVerify tubular 111 is\n \n \n \n \nLinks to\n \n \n \n \n \nout of WC 203.\n \n \n \n \nparked position.', 'Extend TD 116 to WC\n \n \n \n \n \n \n \n \n \n203.', 'Tilt elevator 129 to\n \n \n \n \n \n \n \n \n \nparked position.', '2.\n \nDriller\n \nTD 116 spin-in:\n \nVisual\n \nSlips 161 closed.', 'Spin-in will activate\n \nTD 116 to WC\n \n \n \n \n \nApply dope on saver\n \n \n \nTD 116 thread\n \n203.\n \n \n \n \n \nsub (manual).', 'compensator system.', 'Links to\n \n \n \n \n \nStart spin-in.', 'Spin-in with spin-in\n \nparked position.', 'Lower TD 116 and\n \n \n \nsettings (e.g., RPM/\n \nThread\n \n \n \n \n \nspin to stick-up.\n \n \n \ntorque).', 'compensator.', 'Spin-in will stop at\n \n \n \n \n \n \n \n \n \nset torque and\n \n \n \n \n \n \n \n \n \nrelease the spin-in\n \n \n \n \n \n \n \n \n \ntorque.', '3.\n \nDriller\n \nTD 116 make-up:\n \nVisual\n \nTD 116 spin-in\n \nTD 116 MU will\n \nTD 116 BUC\n \n \n \n \n \nActivate TD 116 MU\n \n \nfinished.', 'automatically close\n \nclose.', '(joystick button and\n \n \n \nBUC and increase TD\n \nTD 116 MU\n \n \n \n \n \njoystick) (may be\n \n \n \n116 torque to set MU\n \ntorque.\n \n \n \n \n \noperated manually on\n \n \n \ntorque.', 'TD 116 torque\n \n \n \n \n \ntouchscreen 522, 524).', 'Release torque and\n \nlog updated.', 'Release button when\n \n \n \nopen BUC when\n \nTD 116\n \n \n \n \n \nMU torque is reached.', 'button is released.', 'connected state\n \n \n \n \n \n \n \n \nDW 119 is\n \nwhen MU\n \n \n \n \n \n \n \n \ninterlocked from\n \ntorque is\n \n \n \n \n \n \n \n \nmoving when BUC is\n \nreached.\n \n \n \n \n \n \n \n \nclosed.', 'TD thread\n \n \n \n \n \n \n \n \nTD 116 thread\n \ncompensator\n \n \n \n \n \n \n \n \ncompensator system\n \ndeactivated.', 'is deactivated.', '3.1.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nUTC 242 closed.', 'TDA 202 will retract,\n \nTDA 202 to\n \n \n \n \nHandler\n \nmove from THP 207 to\n \nCCTV\n \nTDA 202 open.\n \nhoist, and rotate when\n \nOpen state.', 'rig floor 114:\n \n \nLSA 228 open.', 'moving from THP 207\n \nLSA 228 to\n \n \n \n \n \nVerify UTC 242 and\n \n \nITC 236 open and\n \nto rig floor 114\n \nOpen state.', 'LTC 244 are closed.\n \n \nretracted.', 'standby.', 'TDA 202 and LSA\n \n \n \n \n \n \n \n \n \n228 move to rig floor\n \n \n \n \n \n \n \n \n \n114 standby.\n \n \n \n \n \n \n \n3.2.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA\n \n \nTBR 254 and\n \n \n \n \nHandler\n \nget tubular 111 from\n \nCCTV\n \n262 open.', 'SGA 262 to\n \n \n \n \n \nTHP 207:\n \n \n \n \nClosed states.', 'TBR 254 and SGA\n \n \n \n \n \n \n \n \n \n262 move to tubular\n \n \n \n \n \n \n \n \n \n111 in THP 207.', 'Close TBR 254 and\n \n \n \n \n \n \n \n \n \nSGA 262 on tubular\n \n \n \n \n \n \n \n \n \n111.\n \n \n \n \n \n \n \n3.3.', 'Pipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nopen and retract:\n \nCCTV\n \n262 closed on tubular\n \n244 open and retract.', 'LTC 244 to\n \n \n \n \n \nUTC 242 and LTC\n \n \n111 in THP 207.', 'Open state -\n \n \n \n \n \n244 open.\n \n \n \n \nretracted.', 'UTC 242 and LTC\n \n \n \n \n \n \n \n \n \n244 retract from THP\n \n \n \n \n \n \n \n \n \n207.\n \n \n \n \n \n \n \n3.4.', 'Pipe\n \nTBR 254 and SGA 262', 'Visual/\n \nValid FIB 166 position\n \nTBR 254 and SGA\n \nTHP load.', 'Handler\n \nmove toward FIB 166\n \nCCTV\n \nselected.', '262 will follow\n \n \n \n \n \n \nwith tubular 111:\n \n \n \npredefined path.', 'Lift tubular 111 from\n \n \n \nFIB 166 latches will\n \n \n \n \n \n \nTHP 207.\n \n \n \nopen when tubular\n \n \n \n \n \n \nMove to selected\n \n \n \n111 is outside\n \n \n \n \n \n \nposition in FIB 166.\n \n \n \nselected FIB 166 row.', 'FIB 166 latches will\n \n \n \n \n \n \n \n \n \nclose prior to setting\n \n \n \n \n \n \n \n \n \ndown tubular 111.', 'Set down tubular\n \n \n \n \n \n \n \n \n \n111 in selected\n \n \n \n \n \n \n \n \n \nposition.', '4.\n \nDriller\n \nOpen slips 161 and\n \nVisual/\n \nTD 116 connected.', 'Slips 161 to\n \n \n \n \n \nream out tubular 111:\n \nCCTV\n \nTD thread\n \n \nOpen state.', 'Verify TD 116 is\n \n \ncompensator\n \n \nIBOP to Open\n \n \n \n \n \nconnected.', 'deactivated.', 'state.', 'Open slips 161.\n \n \n \n \nTD 116 RPM.', 'Open IBOP.', 'TD 116\n \n \n \n \n \nContinue to ream out\n \n \n \n \ntorque.', 'tubular 111 per drilling\n \n \n \n \nMP 144 SPM.\n \n \n \n \n \nprogram.', 'Standpipe\n \n \n \n \n \n \n \n \n \npressure.', '5.\n \nDriller\n \nSet slips 161:\n \nVisual\n \n \n \nSlips 161 to\n \n \n \n \n \nStop rotation and\n \n \n \n \nClosed state.', 'release torque.', 'Stop MP 144 and\n \n \n \n \n \n \n \n \n \nclose IBOP.', 'Set slips 161 at\n \n \n \n \n \n \n \n \n \nrequired stick-up (e.g.,\n \n \n \n \n \n \n \n \n \nabout 1-2 meters).', '5.1.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTDA 202 open.', 'TDA 202 retract to\n \nTDA 202 Load\n \n \n \n \nHandler\n \nmove to WC 203 (from\n \nCCTV\n \nLSA 228 open.', 'vertical, hoist, rotate,\n \nindication.\n \n \n \n \n \nrig floor 114 standby).', 'and extend to WC\n \n \n \n \n \n \n \n \n \n203 about two meters\n \n \n \n \n \n \n \n \n \nbelow stick-up.', 'TDA 202 and LSA\n \n \n \n \n \n \n \n \n \n228 will stop/wait\n \n \n \n \n \n \n \n \n \noutside WC 203 area\n \n \n \n \n \n \n \n \n \nif TD 116 is moving.', '5.2.', 'Pipe\n \nMove RN 151 to WC\n \n \nRN 151 clamps open.', 'RN 151 will move to\n \nTJ (stick-up)\n \n \n \n \nHandler\n \n203:\n \n \nWC 203 selected.', 'WC 203.', 'assist\n \n \n \n \n \nStart RN 151 break-\n \n \n \nElevate RN 151 to\n \nindication.\n \n \n \n \n \nout', 'sequence to move\n \n \n \nstick-up.', 'RN 151 to WC 203.\n \n \n \nRN 151 will stop/\n \n \n \n \n \n \n \n \n \nwait outside WC 203\n \n \n \n \n \n \n \n \n \narea if TD 116 is\n \n \n \n \n \n \n \n \n \nmoving.', '5.3.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nSlips 161 closed.', 'TDA 202 and LSA\n \nTDA 202 to\n \n \n \n \nHandler\n \nguide close.', 'CCTV\n \n \n228 will not close in\n \nClosed state.', 'Verify TDA 202 and\n \n \n \nWC 203 if slips 161\n \nTDA 202 and\n \n \n \n \n \nLSA 228 in WC 203.\n \n \n \nare not closed.', 'LSA 228 in WC\n \n \n \n \n \nClose TDA 202.\n \n \n \n \n203.', 'Close LSA 228 guide\n \n \n \n \nLSA 228 guide\n \n \n \n \n \nfunnel.\n \n \n \n \nfunnel to Closed\n \n \n \n \n \n \n \n \n \nstate.', '6.\n \nDriller\n \nTD 116 break-out\n \nVisual\n \nSlips 161 must be\n \nTD 116 Break-Out\n \nTD 116 thread\n \n \n \n \n \nconnection:\n \n \nclosed before TD 116\n \nfunction will activate\n \ncompensator.', 'Verify slips 161 are\n \n \nBUT/Break-Out\n \nclamp and increase\n \nTD 116 not\n \n \n \n \n \nclosed.', 'function is available.', 'torque to break\n \nconnected.', 'Activate TD 116\n \n \n \nconnection.', 'TD 116 BUC.\n \n \n \n \n \nbreak-out function\n \n \n \nTD 116 break-out\n \n \n \n \n \n \n(joystick button +\n \n \n \nwill activate TD 116\n \n \n \n \n \n \njoystick).', '(Clamp on/\n \n \n \nthread compensator\n \n \n \n \n \n \nbreak-out may be\n \n \n \nand TD 116 pipe\n \n \n \n \n \n \noperated manually on\n \n \n \nhandler lock.', 'touchscreen 522, 524).', 'When connection is\n \n \n \n \n \n \nDeactivate break-out\n \n \n \nbroken, release\n \n \n \n \n \n \nbutton when\n \n \n \nbutton.', 'Torque will be\n \n \n \n \n \n \nconnection is broken\n \n \n \nreleased and TD 116\n \n \n \n \n \n \n(torque dropping and\n \n \n \nBUC opened.', 'shaft rotating).', 'DW 119 is\n \n \n \n \n \n \n \n \n \ninterlocked from\n \n \n \n \n \n \n \n \n \nhoisting when TD 116\n \n \n \n \n \n \n \n \n \nBUC is closed.', '7.\n \nDriller\n \nTD 116 spin-out:\n \nVisual\n \nSlips 161 must be\n \nSpin-Out will\n \nTD 116 thread\n \n \n \n \n \nVerify break-out is\n \n \nclosed.', 'activate TD 116\n \ncompensator.', 'completed.', 'Break-Out not active.', 'thread compensator\n \n \n \n \n \n \nSpin-out.', 'TD 116 BUC open.\n \nsystem.', 'Hoist out of stick-up.\n \n \n \nSpin-Out function\n \n \n \n \n \n \n \n \n \nwill spin-out per\n \n \n \n \n \n \n \n \n \nsettings.', 'TD 116 thread\n \n \n \n \n \n \n \n \n \ncompensator is\n \n \n \n \n \n \n \n \n \ndeactivated.', '8.\n \nDriller\n \nRetract and lower TD\n \nVisual/\n \nLowering will be\n \nLinks will tilt down\n \nTD 116\n \n \n \n \n \n116 to stick-up:\n \nCCTV\n \nstopped if TD 116 is\n \nwhen TD 116 is\n \nretracted.', 'Verify TD 116 is\n \n \nretracted and links\n \nretracted.', 'Indicate TD\n \n \n \n \n \nabove tubular 111.\n \n \nare tilted to parked\n \nTD 116 pipe handler\n \n116 lower stop\n \n \n \n \n \nRetract TD 116 and\n \n \nposition.', 'has preset position\n \nposition.', 'tilt links down (float).', 'facing TDA 202.', 'Link tilt\n \n \n \n \n \nLower TD 116 to\n \n \n \n \nposition.', 'stick-up (lower stop).', '8.1.', 'Pipe\n \nRN 151 break-out and\n \nCCTV\n \nSlips 161 closed.', 'Break-out and spin-\n \nRN 151\n \n \n \n \nHandler\n \nspin-out:\n \n \n \nout.', 'Double break-\n \nindication.', 'TD 116 disconnected\n \n \n \nout available if\n \n \n \n \n \n \nand hoisted above\n \n \n \nrequired.', 'tubular 111.', 'Open RN 151\n \n \n \n \n \n \nAdjust RN 151\n \n \n \nspinner, guide, and\n \n \n \n \n \n \nelevation if required.\n \n \n \nclamps.\n \n \n \n \n \n \nContinue RN 151\n \n \n \nReturn RN 151 to\n \n \n \n \n \n \nsequence.', 'park position.', '8.2.\n \nPipe\n \nMB (THA) extend to\n \nVisual/\n \nRN 151/THT\n \nMB will extend to WC\n \nMB in WC\n \n \n \n \nHandler\n \nWC 203:\n \nCCTV\n \nretracted.\n \n203 and close.', '203.', 'Verify THT is out of\n \n \nMB open.', 'MB to Closed\n \n \n \n \n \nthe area.', 'state.', 'Continue the MB\n \n \n \n \n \n \n \n \n \nsequence.', '8.3.', 'Pipe\n \nTDA 202 lift tubular\n \nVisual/\n \nRN 151 in parked\n \nTDA 202 will hoist\n \nTDA 202 load\n \n \n \n \nHandler\n \nfrom stick-up:\n \nCCTV\n \nposition.', 'about two meters\n \nindication.', 'Hoist TDA 202 to pick\n \n \nMB in WC 203.', 'before lifting tubular\n \nTDA 202\n \n \n \n \n \nup weight.', 'TD 116 retracted.\n \n111.\n \nposition\n \n \n \n \n \nLSA 228 centralizer\n \n \n \nTubular 111 is lifted\n \nindicator.\n \n \n \n \n \nclosed on tubular 111\n \n \n \ncarefully.', 'Lifting is\n \nLSA 228\n \n \n \n \n \nin WC 203.\n \n \n \nstopped if tubular 111\n \ncentralizer.', 'Hold tubular 111\n \n \n \ncatches on TJ\n \n \n \n \n \n \nabove stick-up until\n \n \n \nthreads.\n \n \n \n \n \n \ndrained.', 'LSA 228 centralizer\n \n \n \n \n \n \n \n \n \ncloses after lifted\n \n \n \n \n \n \n \n \n \nabove box.', '8.4.\n \nPipe\n \nMB open and retract:\n \nVisual/\n \n \nMB will open and\n \nMB to Open\n \n \n \n \nHandler\n \nVerify tubular 111 is\n \nCCTV\n \n \nretract.\n \nstate.\n \n \n \n \n \ndrained.', 'MB parked.', 'Continue MB\n \n \n \n \n \n \n \n \n \nsequence.\n \n \n \n \n \n \n \n8.5.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTD 116 elevator 129\n \nTDA 202 will retract\n \nTDA 202 load\n \n \n \n \nHandler\n \nmove tubular 111 to\n \nCCTV\n \nclosed.', 'to vertical position\n \nindication.', 'THP 207:\n \n \n \nabove MOH 204 (rig\n \nTDA 202\n \n \n \n \n \nTDA 202 and LSA\n \n \n \nfloor 114 standby),\n \nposition\n \n \n \n \n \n228 will move towards\n \n \n \nthen rotate, lower,\n \nindicator.', 'THP 207.\n \n \n \nand extend to THP\n \nLSA 228\n \n \n \n \n \nLTC 244 extends to\n \n \n \n207.\n \nextend.', 'THP 207 and closes\n \n \n \nTDA 202 will slow\n \nLTC 244 to\n \n \n \n \n \nguide when tubular 111\n \n \n \ndown above THP\n \nClosed state.', 'is close to THP 207.\n \n \n \n207.', 'Wash and\n \n \n \n \n \nSet down tubular 111\n \n \n \nLTC 244 is extended\n \ndope (if\n \n \n \n \n \non THP 207.\n \n \n \nand closed.\n \nselected).', 'Wash and dope pin if\n \n \n \nLSA 228 open.\n \n \n \n \n \n \npreselected.', '8.6.', 'Pipe\n \nUTC 242 extend THP\n \nVisual/\n \nTDA 202 and LSA\n \nUTC 242 extend and\n \nUTC 242 and\n \n \n \n \nHandler\n \n207 and close:\n \nCCTV\n \n228 in THP 207 with\n \nclose.', 'LTC 244 to\n \n \n \n \n \nUTC 242 extends to\n \n \ntubular 111.', 'LTC 244 continue\n \nClosed states.', 'THP 207.\n \n \n \nclose.', 'UTC 242 and LTC\n \n \n \n \n \n \n \n \n \n244 close.\n \n \n \n \n \n \n \n8.7.', 'Pipe\n \nTDA 202 open and\n \nVisual/\n \nUTC 242 closed.', 'TDA 202 to\n \n \n \n \nHandler\n \nretract from THP 207:\n \nCCTV\n \n \n \nOpen state.', 'Verify UTC 242 and\n \n \n \n \nLSA 228 open.', 'LTC 244 are closed.', 'Open TDA 202.', 'Open LSA 228 guide\n \n \n \n \n \n \n \n \n \nfunnel.', 'Continue on step 3.1.\n \n \n \n \n \n \n \n8.8.', 'Pipe\n \nTBR 254 and SGA 262\n \n \nFIB 166 latches\n \n \nFIB 166\n \n \n \n \nHandler\n \nmove toward THP 207:\n \n \nclosed.', 'latches closed.', 'Open TBR 254\n \n \n \n \nTBR 254 and\n \n \n \n \n \nclamps and guide and\n \n \n \n \nSGA 262 open.', 'SGA 262 guide (in FIB\n \n \n \n \n \n \n \n \n \n166).', 'Move toward THP\n \n \n \n \n \n \n \n \n \n207/', 'next tubular 111.', 'Continue step 3.2.', 'For tripping-in drill collar stands, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth below in Table 11A.\n \n \n \n \n \n \n \n \nTABLE 11A\n \n \n \n \n \n \n \n \nPreparations for Tripping-In Drill Collar Stands\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nFIB 166\n \nOperator 195 on rig floor 114.', 'Tubulars 111 exist in FIB 166 slots per\n \n \n \nSetback 164\n \n \nHMI/tally.', 'Fingers are closed.', 'Travel path is unobstructed.', 'TBR 254\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'SGA 262\n \n \nGripper inserts/dies are clean, not worn.', 'LTC 244\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'ITC 236\n \n \nGripper inserts/dies are clean, not worn.', 'UTC 242\n \n \n \nTHP\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'Doper 209\n \n \nWater, correct dope available for doper\n \n \n \n \n \n209.', 'LSA 228\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'TDA 202\n \nOperator 195 on rig floor 114.', 'TDA 202 is parked outside collision\n \n \n \n \n \narea.', 'RN 151\n \nOperator 195 on rig floor 114.', 'DPT is connected.', 'THT-DPT\n \n \nGripper dies are clean, not worn.', 'THA-DPT\n \n \nTravel path is unobstructed.', 'Slips 161\n \nOperator 195 on rig floor 114; and/or\n \nCorrect inserts/dies.', '“Driller” 195 at workstation 452.', 'Inserts/dies are clean, not worn.', 'TD 116\n \nOperator 195 on rig floor; and/or\n \nCorrect inserts/dies in elevator 129.\n \n \n \n \n“Driller” 195 at workstation 452.', 'Correct saver sub status.', 'Travel path is unobstructed.', 'DW 119\n \nOperator 195 on rig floor; and/or\n \nChecked.', '“Driller” 195 at workstation 452.', 'The well construction system \n100\n, \n200\n can then be set-up for the trip-in sequence.', 'Examples of such set-up may be as set forth below in Table 11B.\n \n \n \n \n \n \n \n \nTABLE 11B\n \n \n \n \n \n \n \n \nSet-Up for Tripping-In Drill Collar Stands\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nDriller/\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'handling:\n \nPipe\n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nTBR 254,\n \nHandler\n \nemergency stop for all pipe handling\n \nsetup wizard.', 'SGA 262,\n \n \nequipment.', 'After startup: Check for\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \nLTC 244,\n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \nTHP 207,\n \n \nSelect Trip In mode.', 'status header on front\n \n \n \nLSA 228,\n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \nRN 151\n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \n \n \nsettings:\n \n \n \n \n \nSelect slot, direction for picking\n \n \n \n \n \npipe.', 'Select pipe type.', 'Select RN 151 to use.', 'RN 151 MU torque.', 'Select pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'DW 119,\n \n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nMP 144,\n \n \nemergency stop for all pipe handling\n \nsetup wizard.', 'Trip tank\n \n \nequipment.', 'After startup: Check for\n \n \n \n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \n \n \nSelect Trip In mode.', 'status header on front\n \n \n \n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \n \n \nsettings:\n \n \n \n \n \nStick-up target.', 'Set DW 119 upper/lower stops.', 'Set maximum lowering speed.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator screen,\n \n \n \n \n \ncompleted pre-checks.', 'system status/alarms.', 'Activate TD 116 from touchscreen 522,\n \n \n \n \n \n524.', 'Select Operation screen on touchscreen\n \n \n \n \n \n522, 524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator screen,\n \n \n \n \n \n524.\n \nsystem status/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled\n \nVerify operator screen,\n \n \n \nmachines\n \n \nin zone management system and\n \nsystem status/alarms.', 'tubular interlock system.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'The sequence for tripping-in drill collar stands may start with a drill collar stand \n111\n stick-up at WC \n203\n, with the top drive \n116\n elevator \n129\n closed on the stick-up and the slips \n161\n closed.', 'The UTC \n242\n and LTC \n244\n may be closed on another drill collar stand \n111\n in the THP \n207\n, with washing and doping of the pin already completed.', 'The TDA \n202\n, LSA \n228\n, TBR \n254\n, and SGA \n262\n may each be empty.', 'Example steps of the drill collar stand tripping-in sequence may be as set forth below in Table 11C.\n \n \n \n \n \n \n \n \nTABLE 11C\n \n \n \n \n \n \n \n \nTripping-In Drill Collar Stands Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nOpen elevator 129:\n \nVisual/\n \nSlips 161 must be\n \nElevator 129 Open is\n \nElevator 129 to\n \n \n \n \n \nVerify slips 161 are\n \nCCTV\n \nclosed before opening\n \nnot selectable if slips\n \nOpen state.\n \n \n \n \n \nclosed.', 'elevator 129.', '161 are not closed.', 'Open elevator 129.\n \n \n \n1.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA\n \nTBR 254 will move\n \nTBR 254 and\n \n \n \n \nHandler\n \npick up new stand 111:\n \nCCTV\n \n262 grip/guide open.\n \ninto FIB 166 elevated\n \nSGA 262 grip/\n \n \n \n \n \nMove TBR 254 and\n \n \nSelected FIB 166\n \nabove open latches.', 'guide to Closed\n \n \n \n \n \nSGA 262 to selected\n \n \nposition “valid.”', 'Adjustments available.', 'state.', 'finger/slot in FIB 166.', 'TBR 254 and SGA\n \n \n \n \n \nClose guides and\n \n \n \n262 grip/guide will\n \n \n \n \n \nclamp on stand 111.\n \n \n \nclose.', '2.\n \nDriller\n \nTilt back elevator 129\n \nVisual/\n \nTD 116 pipe handler\n \nElevator 129 will be\n \nDW 119 upper\n \n \n \n \n \nand move TD 116 to\n \nCCTV\n \npositioned facing UTC\n \ntilted back and then\n \nstop setting.', 'latching height:\n \n \n242.\n \nslide back to vertical\n \n \n \n \n \nVerify elevator 129 is\n \n \n \nposition (float).', 'open.', 'Tilt back (or retract)\n \n \n \n \n \nTD 116 to clear TJ.', 'Hoist elevator 129 to\n \n \n \n \n \nstand 111 latch height\n \n \n \n \n \n(upper stop).', '2.1.', 'Pipe\n \nUTC 242 and LTC 244\n \nVisual/\n \n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \ntilt stand 111 to drill\n \nCCTV\n \n \n244 will stop at\n \nLTC 244 closed.', 'collar handover\n \n \n \ncorrect angle, DCH.\n \nUTC 242 and\n \n \n \n \n \nposition (DCH):\n \n \n \n \nLTS 244 to DCH.', 'UTC 242 and LTC\n \n \n \n \n \n244 extend to tilt stand\n \n \n \n \n \n111 toward WC 203.\n \n \n \n2.2.', 'Pipe\n \nLSA 228 extend to\n \nVisual/\n \nLSA 228 guide funnel\n \n \nLSA 228 funnel\n \n \n \n \nHandler\n \nstand 111 in THP 207:\n \nCCTV\n \nmust be open.', 'to Closed state.', 'Extend LSA 228 to\n \n \nUTC 242 and LTC\n \n \n \n \n \nstand 111 in THP 207\n \n \n244 in DCH.', '(tilted).', 'Close LSA 228\n \n \n \n \n \nfunnel.', '3.\n \nDriller\n \nExtend TD 116 and\n \nVisual/\n \nUTC 242 and LTC\n \n \nElevator 129 to\n \n \n \n \n \nlatch elevator 129:\n \nCCTV\n \n244 in DCH.', 'Closed state.', 'Extend TD 116 to WC\n \n \n \n \nTD 116 in WC\n \n \n \n \n \n203.\n \n \n \n \n203.', 'Latch elevator 129\n \n \n \n \nUTC 242 and\n \n \n \n \n \n(automatic close on\n \n \n \n \nLTC 244 in DCH.\n \n \n \n \n \nimpact).', '3.1.\n \nPipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTD 116 elevator 129\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nopen and retract.', 'CCTV\n \nmust be closed.', '244 open and retract.', 'LTC 244 to\n \n \n \n \n \n \n \nLSA 228 funnel must\n \n \nOpen states.\n \n \n \n \n \n \n \nbe closed.', '3.2.', 'Pipe\n \nMove RN 151 to WC\n \n \nOnly possible with\n \nRN 151 will move to\n \nTJ (stick-up)\n \n \n \n \nHandler\n \n203:\n \n \nTHT.', 'If THA is used,\n \nWC 203.', 'assist\n \n \n \n \n \nStart RN 151 MU\n \n \nwait for stand 111\n \nElevate RN 151 to\n \nindication.\n \n \n \n \n \nsequence to move RN\n \n \nlocated above stick-up.', 'stick-up.', '151 to WC 203.', 'RN 151 tongs open.', 'WC 203 selected.', '4.\n \nDriller\n \nTD 116 hoist stand 111\n \nVisual/\n \nUTC 242 or LTC 244\n \nSlips 161 Open will\n \nTD 116 at WC\n \n \n \n \n \nfrom THP 207:\n \nCCTV\n \nopen.\n \nbe blocked with\n \n203.', 'TD 116/DW 119 lift\n \n \n \nelevator 129 closed in\n \n \n \n \n \nstand 111 guided by\n \n \n \nWC 203 until stand\n \n \n \n \n \nLSA 228 (e.g., about\n \n \n \n111 is connected.', 'nine meters).', 'Stop\n \n \n \n \n \nwhen above stick-up.', 'Note: Drill collar stand\n \n \n \n \n \n111 to be lifted\n \n \n \n \n \ncarefully to avoid\n \n \n \n \n \ndamage to equipment.', 'Links tilt to WC 203\n \n \n \n \n \n(float).', '4.1.\n \nPipe\n \nLSA 228 guide stand\n \nVisual/\n \n \n \nLSA 228\n \n \n \n \nHandler\n \n111 to WC 203:\n \nCCTV\n \n \n \ncentralizer to\n \n \n \n \n \nLSA 228 guides stand\n \n \n \n \nClosed state.', '111 to WC 203 when\n \n \n \n \nLSA 228\n \n \n \n \n \npin is above stick-up\n \n \n \n \nadjustment\n \n \n \n \n \nheight.\n \n \n \n \navailable.', 'LSA 228 centralizer\n \n \n \n \n \ncloses when stand 111\n \n \n \n \n \nis close to vertical\n \n \n \n \n \nabove stick-up.', '4.2.\n \nPipe\n \nGuide stand 111 with\n \nCCTV\n \nStand 111 positioned\n \nClose RN 151 BUT.', 'Stabbing guide\n \n \n \n \nHandler\n \nRN 151 in WC 203:\n \n \nby TD 116/LSA 228\n \nClose stabbing guide.\n \nto Closed state.', 'Verify stand 111 is\n \n \nabove stick-up in WC\n \n \nRN 151 BUT to\n \n \n \n \n \nlocated in WC 203.\n \n \n203.\n \n \nClosed state.', 'Adjust RN 151\n \n \n \n \n \nelevation if required.', 'Continue RN 151\n \n \n \n \n \nsequence.', '5.\n \nDriller\n \nTD 116 lower to stab\n \nVisual/\n \nRN 151 in WC 203\n \n \n \n \n \nstand 111 in stick-up.', 'CCTV\n \nwith stabbing guide\n \n \n \n \n \n \n \nclosed.', '5.1.', 'Pipe\n \nLSA 228 open and\n \nVisual/\n \nRN 151 stabbing\n \n \nLSA 228 guide\n \n \n \n \nHandler\n \nretract:\n \nCCTV\n \nguide closed on stand\n \n \nto Open state.', 'LSA 228 opens and\n \n \n111.\n \n \n \n \n \nretracts when RN 151\n \n \n \n \n \nstabbing guide closed\n \n \n \n \n \non stand 111.\n \n \n \n5.2.', 'Pipe\n \nRN 151 spin-in and\n \nVisual/\n \nStand 111 stabbed in\n \nSpin-in and MU\n \nTorque log\n \n \n \n \nHandler\n \nMU:\n \nCCTV\n \nstick-up.\n \nconnection.', 'updated.', 'Continue RN 151\n \n \nTDA 202 unloaded.', 'Open RN 151 spinner\n \nMU torque\n \n \n \n \n \nsequence to spin-in\n \n \n \nand tongs.', 'presented to\n \n \n \n \n \nand MU.\n \n \n \nReturn RN 151 to\n \nDriller.', 'park position.', '5.3.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTHP 207 empty.', 'TBR 254 cannot open\n \nIndicate FIB\n \n \n \n \nHandler\n \nmove stand 111 to\n \nCCTV\n \nUTC 242 and LTC\n \nwith weight.', '166 open\n \n \n \n \n \nTHP 207:\n \n \n244 open.', 'TBR 254 grip open\n \nlatches.', 'Open FIB 166 latches\n \n \nCorrect pipe detected\n \nwhen unloaded.', 'TBR 254 load\n \n \n \n \n \nfor selected row.', 'in TBR 254 and SGA\n \nFIB 166 latches will\n \nindication.', 'Verify latches open.', '262.\n \nnot open with TBR 254\n \n \n \n \n \nTBR 254 lifts and\n \n \n \nhead in low position.', 'moves stand 111 out of\n \n \n \n \n \nFIB 166 to THP 207.', 'FIB 166 latches will\n \n \n \n \n \nclose as stand 111\n \n \n \n \n \nmoves out of FIB 166.', 'Set stand 111 on\n \n \n \n \n \nTHP 207.', 'Wash and dope pin if\n \n \n \n \n \npreselected.', '5.4.\n \nPipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nextend to THP 207 and\n \nCCTV\n \n262 with stand 111 in\n \n244 extend and close.', 'LTC 244 to\n \n \n \n \n \nclose.', 'THP 207.\n \n \nClosed states.', '5.5.\n \nPipe\n \nTBR 254 and SGA 262\n \n \nUTC242 and LTC 244\n \n \n \n \nHandler\n \nopen and move toward\n \n \nclosed on stand 111.', 'FIB 166:\n \n \n \n \n \nOpen TBR 254\n \n \n \n \n \nclamps and guide and\n \n \n \n \n \nSGA 262 guide.', 'Move toward FIB 166/\n \n \n \n \n \nnext stand 111.', 'Continue step 1.\n \n \n \n6.\n \nDriller\n \nOpening slips:\n \nVisual\n \nTD 116 elevator 129\n \n \nSlips 161 to\n \n \n \n \n \nOpen slips 161\n \n \nclosed.', 'Open state.', '(command).', 'RN 151 MU\n \n \nDW 119 load.', 'Hoist to open slips\n \n \nsequence finished.', '161.', 'Stand 111 connected\n \n \n \n \n \n \n \nstate.', '7.\n \nDriller\n \nLower drill string 120:\n \nVisual\n \nSlips 161 open.', 'Settings: DW\n \n \n \n \n \nVerify slips 161 are\n \n \n \n \n119 lowering\n \n \n \n \n \nopen before lowering\n \n \n \n \nspeed and\n \n \n \n \n \ndrill string 120.\n \n \n \n \nminimum slack-\n \n \n \n \n \n \n \n \n \noff weight.', '8.\n \nDriller\n \nSet slips 161:\n \nVisual\n \nStick-up at correct\n \n \nSlips 161 to\n \n \n \n \n \nSet slips 161 at\n \n \nheight.', 'Closed state.', 'correct stick-up height.', 'DW 119 load\n \n \n \n \n \nSet off weight.\n \n \n \n \nindicator.\n \n \n \n9.\n \nDriller\n \nCheck trip tank\n \nVisual\n \nSlips 161 closed.', 'Trip tank gain/loss is\n \nTrip sheet/\n \n \n \n \n \nvolume, gain/loss:\n \n \n \ndetermined and\n \nvolume control.', 'Trip tank gain/loss.\n \n \n \ndisplayed.', 'Repeat all steps for\n \n \n \n \n \nnext stand 111.', 'Different combinations of the aspects described above may also be utilized for running casing from the CW \n131\n with the TDA \n202\n and a casing running tool (CRT).', 'Preparations for such operation may include the examples set forth below in Table 12A.\n \n \n \n \n \n \n \n \nTABLE 12A\n \n \n \n \n \n \n \n \nPreparations for Running Casing from CW with TDA and CRT\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nCW 131\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Casings are laid out correct with aft end in line with skate 133\n \n \n \n \n \nfor correct loading.', 'Prepare to pick up casing.', 'CTO:', 'Operator 195 on\n \nCTO is rigged up in THA (or THT).', 'THA + CTO\n \nrig floor 114.', 'CTO adjusted for casing size.', 'as primary,\n \n \nDies are correct, clean, and not worn.', 'THT + CTO\n \n \nTravel path is unobstructed.', 'as backup\n \n \n \nLSA 228\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Slips 161\n \nOperator 195 on\n \nCorrect inserts in slips 161.', 'Rotary\n \nrig floor 114.', 'Dies are clean and not worn.', 'Table\n \n \nRotary table rotation lock activated.', 'TD 116,\n \nOperator 195 on\n \nCorrect inserts in elevator 129\n \n \n \nCRT\n \nrig floor 114.\n \n(or elevator 129 removed, if required).', 'Operator screen, system status.', 'Travel path is unobstructed.', 'CRT installed and tested.', 'DW 119\n \nOperator 195 on\n \nChecked.\n \n \n \n \nrig floor 114.\n \n \n \nTubulars\n \nOperator 195 on\n \nTubulars 111 to be laid out on CW 131.\n \n \n \n111\n \nrig floor 114.', 'Tubulars 111 to be cleaned and doped, protectors removed\n \n \n \n \n \n(other implementations may be used for casing with protectors).', 'Casings measured, marked, and tally updated.', 'The well construction system \n100\n, \n200\n can then be set-up for the operation.', 'Examples of such set-up may be as set forth below in Table 12B.\n \n \n \n \n \n \n \n \nTABLE 12B\n \n \n \n \n \n \n \n \nSet-Up for Running Casing from CW with TDA and CRT\n \n \n \n \n \n \n \n \n \n \n \nEquipment', 'Responsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'LSA 228,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nCTO,\n \n \nequipment.', 'Program setup\n \n \n \nCW 131\n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Running Casing from CW with TDA\n \nfor green light in\n \n \n \n \n \nand CRT mode.', 'Construction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nSelect casing type and verify casing\n \nscreen 532, 534,\n \n \n \n \n \ndata (size, weight, MU loss, torque\n \n536.\n \n \n \n \n \nsettings, weight, etc.).', 'Select CTO to use in the operations.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nDW 119,\n \n \ncompleted pre-checks and deactivated\n \nscreen.', 'MP 144\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \n \n \nequipment.', 'Program setup\n \n \n \n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Running Casing from CW with TDA\n \nfor green light in\n \n \n \n \n \nand CRT mode.', 'Construction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nStick-up target.', 'screen 532, 534,\n \n \n \n \n \nSet DW 119 upper/lower stops.', '536.', 'Set maximum lowering speed.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Verify active tanks are selected and\n \n \n \n \n \nlined up.', 'Select MP 144 (to fill casing, optional).', 'Verify MP 144 pressure limit setting.', 'Assign pumps to master slider.', 'Set number of strokes and SPM to fill\n \n \n \n \n \ncasing (optional).', 'Set ramp-up parameters.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator\n \n \n \n \n \ncompleted pre-checks.\n \nscreen, system\n \n \n \n \n \nActivate TD 116 from touchscreen 522,\n \nstatus/alarms.', '524.\n \n \n \n \n \nVerify correct elevator 129 setting\n \n \n \n \n \n(manual/remote).', 'Select Operation screen on touchscreen 522,\n \n \n \n \n \n524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator\n \n \n \n \n \n524.\n \nscreen, system\n \n \n \n \n \nSet maximum lowering speed.', 'status/alarms.', 'Set minimum slack off weight.', 'Slips 161,\n \nDriller\n \nVerify correct setting for slips 161\n \nVerify operator\n \n \n \nRotary\n \n \n(manual/remote).', 'screen, system\n \n \n \ntable\n \n \n \nstatus/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nAll types of tubulars 111 are registered.', '111\n \nHandler\n \n \n \n \n \n \n \n \n \n \nAfter such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example of this sequence may start with a casing stick-up at WC \n203\n, with the slips \n161\n closed and the CRT engaged.', "Casing may be laid out on the CW \n131\n casing side (e.g., Driller's side), having been cleaned, doped, and tallied, and with protectors removed.", 'The TDA \n202\n and LSA \n228\n may hold a casing in the rig floor \n114\n standby position.', 'Example steps of the sequence may be as set forth below in Table 12C.\n \n \n \n \n \n \n \n \nTABLE 12C\n \n \n \n \n \n \n \n \nSequence for Running Casing from CW with CTO\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nRelease CRT from\n \nVisual/\n \nSlips 161 must be\n \n \nCRT to\n \n \n \n \n \nstick-up:\n \nCCTV\n \nclosed before releasing\n \n \nDisconnect\n \n \n \n \n \nVerify slips 161 are\n \n \nCRT.\n \n \nstate.\n \n \n \n \n \nclosed, MP 144\n \n \n \n \n \nstopped, and IBOP\n \n \n \n \n \nclosed.', 'Release CRT from\n \n \n \n \n \nstick-up.', 'Hoist CRT above\n \n \n \n \n \nstick-up.\n \n \n \n \n \nRetract and hoist to\n \n \n \n \n \ncasing stabbing\n \n \n \n \n \nposition.\n \n \n \n1.1.', 'Pipe\n \nMove THT/CTO to WC\n \n \nCTO open.', 'CTO will move to WC\n \nTHT in WC 203.', 'Handler\n \n203 (optional):\n \n \nWC 203 selected.', '203.', 'Verify TD 116 hoisted\n \n \n \nElevate to stick-up.', 'above CTO working\n \n \n \nZMS will prevent\n \n \n \n \n \narea.', 'CTO start if TD 116 is\n \n \n \n \n \nStart CTO sequence\n \n \n \ntoo low.', 'to move THT/CTO to\n \n \n \n \n \nWC 203.\n \n \n \n1.2.', 'Pipe\n \nTDA 202 and LSA 228\n \n \nCTO open.', 'TDA 202 and\n \n \n \n \nHandler\n \nextend casing to WC\n \n \n \n \nLSA 228 in WC\n \n \n \n \n \n203:\n \n \n \n \n203.', 'Verify TD 116 is\n \n \n \n \n \nretracted.', 'TDA 202 and LSA\n \n \n \n \n \n228 will extend casing\n \n \n \n \n \nto WC 203 above stick-\n \n \n \n \n \nup.\n \n \n \n1.3.', 'Pipe\n \nGuide single casing\n \nVisual/\n \nCTO in WC 203.', 'Close CTO BUT.', 'Handler\n \nwith CTO in WC 203:\n \nCCTV\n \nLSA 228 in WC 203.', 'Close stabbing guide.', 'Verify casing at WC\n \n \n \n \n \n203.', 'Continue CTO\n \n \n \n \n \nsequence.', '1.4.\n \nPipe\n \nClose MUST for soft\n \nVisual/\n \nCTO in WC 203.', 'Close MUST.', 'MUST to\n \n \n \n \nHandler\n \nstabbing (optional):\n \nCCTV\n \n \nMust will take some\n \nClosed state.', 'Adjust CTO elevation\n \n \n \nload if closed prior to\n \n \n \n \n \nand TD 116 elevation if\n \n \n \nstabbing casing.\n \n \n \n \n \nrequired.', 'Continue CTO\n \n \n \n \n \nsequence.', '1.5.\n \nPipe\n \nStab casing:\n \nVisual/\n \nTDA 202 in WC 203.', 'TDA 202 will lower to\n \nTDA 202\n \n \n \n \nHandler\n \nLower TDA 202 to\n \nCCTV\n \nCTO in WC 203 with\n \nstab casing and\n \nunloaded.', 'stab casing in stick-up.', 'stabbing guide closed.', 'continue lowering\n \n \n \n \n \n \n \n \n(e.g., about one\n \n \n \n \n \n \n \n \nmeter).', '1.6.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \nCTO stabbing guide\n \n \nLSA 228 Open\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \nclosed.\n \n \nstatus.', 'Open and retract LSA\n \n \n \n \n \n228 when casing has\n \n \n \n \n \nentered stabbing\n \n \n \n \n \nguide.\n \n \n \n1.7.\n \nPipe\n \nCTO spin-in and MU:\n \nVisual/\n \nSingle casing stabbec\n \nCTO will spin-in and\n \nCasing\n \n \n \n \nHandler\n \nVerify casing is\n \nCCTV\n \nin stick-up.', 'MU automatically per\n \nConnected state.\n \n \n \n \n \nstabbed in box.', 'TD 116 unloaded,\n \ncasing data settings.', 'Continue CTO\n \n \nelevator 129 below TJ\n \nIf Accept: Open\n \n \n \n \n \nsequence.', 'to permit spinning.\n \nspinner, guide, and\n \n \n \n \n \nAccept or reject MU.\n \n \n \nclamps.\n \n \n \n \n \n \n \n \nReturn to park\n \n \n \n \n \n \n \n \nposition.\n \n \n \n1.8.\n \nPipe\n \nLoad casing into ramp\n \nVisual/\n \nCasing ready in\n \n \n \n \nHandler\n \n149:\n \nCCTV\n \nloading position.', 'Use CW 131 loading\n \n \nCW 131 in loading\n \n \n \n \n \nfingers to load casing\n \n \nposition.\n \n \n \n \n \nsingle into ramp 149.\n \n \n \n1.9.', 'Pipe\n \nRun ramp 149 to rig\n \nVisual/\n \nCasing loaded onto\n \nRamp 149 will tilt to\n \nCW 131\n \n \n \n \nHandler\n \nfloor 114:\n \nCCTV\n \nramp 149.\n \nrig floor 114 tubular\n \nanimated.', 'Verify casing is\n \n \n \nposition.', 'loaded in ramp 149.', 'Skate 133 will move\n \n \n \n \n \nMove ramp toward\n \n \n \ntoward rig floor 114.', 'pipe pick-up position.', 'Skate 133 will stop\n \n \n \n \n \n \n \n \nwith casing box inside\n \n \n \n \n \n \n \n \nramp 149.\n \n \n \n2.\n \nDriller\n \nStab and engage CRT:\n \nVisual/\n \nSingle casing\n \n \nCRT Connected\n \n \n \n \n \nVerify casing is\n \nCCTV\n \nstabbed in stick-up.\n \n \nstate.', 'stabbed and MU\n \n \nTDA 202 unloaded,\n \n \n \n \n \naccepted.', 'elevator (or gripper\n \n \n \n \n \nStab and engage\n \n \n169) below TJ to\n \n \n \n \n \nCRT.\n \n \npermit spinning.', 'CTO open.', '2.1.', 'Pipe\n \nOpen TDA 202 and\n \n \nCasing connected.', 'Open CTO', 'BUT and\n \nTDA 202', 'Open.', 'Handler\n \nmove to pick up next\n \n \nCRT connected.', 'move THT to parked\n \n \n \n \n \ncasing single:\n \n \n \nposition.', 'Open TDA 202 and\n \n \n \n \n \nmove to CW 131 pick-\n \n \n \n \n \nup position.', '3.\n \nDriller\n \nOpen slips 161:\n \nVisual\n \nCRT connected.', 'Slips 161 to\n \n \n \n \n \nOpen slips 161\n \n \nCasing connected.', 'Open state.', '(command).', 'DW 119 load.', 'Hoist to open slips\n \n \n \n \n \n161.\n \n \n \n4.\n \nDriller\n \nLower drill string 120:\n \nVisual\n \nSlips 161 open.', 'Optional: The selected\n \nMP 144 SPM\n \n \n \n \n \nVerify slips 161 are\n \n \nOptional: MP 144\n \nMP 144 will pump a\n \nand pressure.', 'open before lowering\n \n \nready.', 'set number of strokes\n \n \n \n \n \ndrill string 120.\n \n \n \nat set rate with\n \n \n \n \n \nOptional: Fill casing\n \n \n \nselected MP 144 and\n \n \n \n \n \nvolume, if selected.\n \n \n \nstop.', 'Open IBOP.', 'Start MP 144.', 'Close IBOP.', '4.1.\n \nPipe\n \nPush casing to pick-up\n \nVisual\n \nRamp 149 in rig floor\n \nSkate 133 will push\n \nCW 131 in pick-\n \n \n \n \nHandler\n \nposition:\n \n \n114 position.', 'casing a defined\n \nup position.', 'Verify TDA 116\n \n \nTDA 202 in CW 131\n \ndistance forward.', 'TDA 202 in CW\n \n \n \n \n \nelevator 129 is\n \n \npick-up position.', '131 pick-up\n \n \n \n \n \npositioned in CW 131\n \n \nTDA 202 open.\n \n \nposition.\n \n \n \n \n \npick-up position.', 'Run skate 133 until\n \n \n \n \n \ncasing is positioned\n \n \n \n \n \nabove elevator 129.', '4.2.', 'Pipe\n \nClose TDA 202:\n \nVisual\n \nCasing in CW 131\n \nTubular interlock will\n \nTD 202 to\n \n \n \n \nHandler\n \nHoist/tilt TDA 202 and\n \n \npick-up position, above\n \nprevent hoisting\n \nClosed state.', 'close.', 'TDA 202 elevator.', 'without closed\n \n \n \n \n \n \n \n \nelevator (above\n \n \n \n \n \n \n \n \ncertain height).', '5.\n \nPipe\n \nLift casing to rig floor\n \nVisual\n \nTDA 202 closed.', 'Hoisting will stop\n \nLSA 228 guide\n \n \n \n \nHandler\n \n114 DF standby\n \n \nVerify LSA 228 is\n \nprior to lifting casing\n \nto Closed state.', 'position:\n \n \npositioned to receive\n \nout of CW 131 without\n \nLSA 228\n \n \n \n \n \nVerify TDA 202 is\n \n \ncasing bottom before\n \nguiding.\n \ncentralizer to\n \n \n \n \n \nclosed.\n \n \nhoisting.', 'LSA 228 centralizer\n \nClosed state.', 'Hoist TDA 202 to pick\n \n \nTDA 202 above LSA\n \nclose when casing is\n \nIndicate TDA\n \n \n \n \n \nup single from CW\n \n \n228 operating area.', 'close to vertical.', '202/LSA 228 in\n \n \n \n \n \n131.', 'TDA 202 and LSA\n \nMOH 204\n \n \n \n \n \nMove LSA 228 to\n \n \n \n228 will position\n \nposition.', 'preset position to\n \n \n \ncasing above MOH\n \n \n \n \n \nprepare for guiding.', '204/ITC 236 with TDA\n \n \n \n \n \nBefore casing lower\n \n \n \n202 elevator facing\n \n \n \n \n \nend leaves CW 131,\n \n \n \nTD 116.', 'close LSA 228 funnel.', 'Continue hoisting and\n \n \n \n \n \nrotate TDA 202 until\n \n \n \n \n \ncasing is above MOH\n \n \n \n \n \n204 (rig floor 114\n \n \n \n \n \nstandby position).', 'Continue step.', '1.1.\n \n \n \n6.\n \nPipe\n \nCW 131 retract to\n \nVisual/\n \n \nSkate 133 will move\n \n \n \n \nHandler\n \nloading position:\n \nCCTV\n \n \nto loading position.', 'Verify casing pin end\n \n \n \nRamp 149 will tilt to\n \n \n \n \n \nis clear of ramp 149.\n \n \n \nloading position.', 'Move CW 131 toward\n \n \n \n \n \nFT loading position.', 'Continue step 1.6.', '7.\n \nDriller\n \nSet slips 161:\n \nVisual\n \nStick-up at correct\n \n \nSlips 161 to\n \n \n \n \n \nSet slips 161 at\n \n \nheight.', 'Closed state.', 'correct stick-up height.', 'DW 119 load\n \n \n \n \n \nSet off weight.\n \n \n \n \nindicator.', '8.\n \nDriller\n \nCheck gain/loss:\n \nVisual\n \n \nTrip tank or active\n \nVolume control.', 'Check trip tank gain/\n \n \n \ntank gain/loss is\n \n \n \n \n \nloss or active gain/loss\n \n \n \ndetermined and\n \n \n \n \n \ndepending on selected\n \n \n \ndisplayed.\n \n \n \n \n \noperation.', '9.\n \n \nRepeat sequence for\n \n \n \n \n \nnext casing.', 'Different combinations of the aspects described above may also be utilized for building stands of two or more casing singles.', 'Such casing stand building may be performed during drilling and other operations performed at WC \n203\n.', 'Such simultaneous operations, however, are coordinated to avoid conflicts and obstructions between the different machines and systems.', 'For example, the elevator of the TDA \n202\n may have two different sizes of inserts to permit building casing stands while drilling.', "The change of head size may be done remote from the Pipe Handler's workstation \n450\n (or \n452\n or \n454\n).", 'When a casing stand building operation is to be performed, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth below in Table 13A.\n \n \n \n \n \n \n \n \nTABLE 13A\n \n \n \n \n \n \n \n \nCasing Stand Building Preparations\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nCW 131\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Prepare for casing pick-up.', 'Casings are laid out correctly with aft\n \n \n \n \n \nend in line with skate 133\n \n \n \n \n \nfor correct loading.', 'FIB 166\n \nPipe Handler\n \nStands in FIB 166 slots per HMI.', 'Fingers closed.', 'Travel path is unobstructed.', 'TBR 254\n \nPipe Handler\n \nTravel path is unobstructed.', 'SGA 262\n \nPipe Handler\n \nTravel path is unobstructed.', 'LTC 244\n \nOperator 195 on\n \nTravel path is unobstructed.', 'ITC 236\n \nrig floor 114.', 'Dies are clean and not worn.', 'UTC 242\n \n \n \nTHP\n \nOperator 195 on\n \nTravel path is unobstructed.', 'Doper 209\n \nrig floor 114.', 'Water and correct dope available for doper 209.', 'LSA 228\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'TDA 202\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Correct dope is available for associated doper 209.', 'Correct inserts installed.', 'CTO:', 'Operator 195 on\n \nCTO is rigged up in THA.\n \n \n \nTHA-CTO\n \nrig floor 114.', 'Correct adaptors and stabbing guide funnel are installed.', 'Dies are correct, clean, and not worn.', 'Travel path is unobstructed.', 'Tubulars\n \nOperator 195 on\n \nTubular 111 to be loaded on FT.\n \n \n \n111\n \nrig floor 114.', 'Tubulars 111 to be cleaned and doped, protectors removed.', 'The well construction system \n100\n, \n200\n can then be set-up for the casing stand building operation.', 'Examples of such set-up may be as set forth below in Table 13B.\n \n \n \n \n \n \n \n \nTABLE 13B\n \n \n \n \n \n \n \n \nCasing Stand Building Set-Up\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'TBR 254,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nSGA 262,\n \n \nequipment.', 'Program setup\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \nwizard.', 'LTC 244,\n \n \ntouchscreen 522, 524.', 'After startup: Check\n \n \n \nITC 236,\n \n \nSelect Casing Stand Building mode.', 'for green light in\n \n \n \nTHP 207,\n \n \nSelect setup wizard to open pop-up on front\n \nConstruction\n \n \n \nTDA 202,\n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nProgram status\n \n \n \nLSA 228,\n \n \nSelect slot, direction for racking stands.', 'header on front\n \n \n \nRN 151,\n \n \nSelect casing size/type.', 'screen 532, 534,\n \n \n \nCW 131\n \n \nSelect CTO (with THA) to use.\n \n536.\n \n \n \n \n \nCTO MU torque.', 'Perform pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'All\n \nPipe\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \nHandler\n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nAll tubulars 111 to be registered in\n \n \n \n111\n \nHandler\n \nelectronic tally system.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example casing stand building sequence may start with the MOH \n204\n and THP \n207\n empty, the ITC \n236\n retracted, and the CW \n131\n feeding table pre-loaded with casing singles (perhaps already cleaned and doped).', 'Example steps of the casing stand building sequence may be as set forth below in Table 13C.', 'In such example, among others within the scope of the present disclosure, the pipe handling equipment may be operated automatically via the Construction Program, and the step execution of the pipe handling equipment may be controlled automatically by one or two operators \n195\n at the associated workstation(s) \n450\n, \n452\n, \n454\n.', 'The Construction Program may also feature configurable step confirmations.', 'The casing stand building sequence controlled by the Construction Program may be stopped or interrupted at any time, and some or all functions may be operated manually by the one or two operators \n195\n at the associated workstation(s) \n450\n, \n452\n, \n454\n.', 'TABLE 13C\n \n \n \n \n \n \n \n \nCasing Stand Building Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nPipe\n \nLoad casing single into\n \nVisual/\n \nCasing ready in\n \n \n \n \n \n \nHandler\n \nramp 149:\n \nCCTV\n \nloading position.', 'Verify ramp 149 is\n \n \nCW 131 in loading\n \n \n \n \n \nempty and in position.\n \n \nposition.', 'Use loading fingers to\n \n \n \n \n \nload casing single into\n \n \n \n \n \nramp 149.\n \n \n \n2.\n \nPipe\n \nRun ramp 149 to pick-\n \nVisual/\n \nCasing loaded on\n \nRamp 149 will tilt\n \n \n \n \nHandler\n \nup position:\n \nCCTV\n \nramp 149.\n \nto rig floor 114\n \n \n \n \n \nVerify casing is\n \n \n \ntubular position.\n \n \n \n \n \nloaded in ramp 149.\n \n \n \nSkate 133 will\n \n \n \n \n \nMove ramp 149\n \n \n \nmove toward rig\n \n \n \n \n \ntoward pipe pick-up\n \n \n \nfloor 114.\n \n \n \n \n \nposition.', 'Skate 133 will\n \n \n \n \n \n \n \n \nstop with casing\n \n \n \n \n \n \n \n \nbox on ramp 149.\n \n \n \n3.\n \nPipe\n \nMove TDA 202 to pick-\n \nVisual\n \n- TDA 202 open.', 'Handler\n \nup position:\n \n \n \n \n \nTilt TDA 202.\n \n \n \n \n \nLower and extend\n \n \n \n \n \nTDA 202 to CW 131\n \n \n \n \n \npick-up position (above\n \n \n \n \n \nTHP 207).', '4.\n \nPipe\n \nPresent casing above\n \nVisual\n \nRamp 149 in pick-up\n \nSkate 133 will move\n \nCW 131\n \n \n \n \nHandler\n \nTDA 202:\n \n \nposition.', 'forward a defined\n \nposition.', 'Run skate 133 until\n \n \n202 TDA in receive\n \ndistance depending\n \n \n \n \n \ncasing positioned\n \n \nposition.', 'on casing size.\n \n \n \n \n \nabove the TDA 202\n \n \n \n \n \nelevator (e.g., gripper\n \n \n \n \n \n169).', '5.\n \nPipe\n \nLatch TDA 202:\n \nVisual\n \nCasing is positioned\n \nTubular interlock\n \nTDA 202 to\n \n \n \n \nHandler\n \nHoist TDA 202 to\n \n \ncorrectly above TDA\n \nwill prevent hoisting\n \nClosed state.', 'latch onto casing.', '202 elevator.', 'without closed\n \n \n \n \n \nClose TDA 202.\n \n \n \nelevator (above\n \n \n \n \n \n \n \n \ncertain height).', '6.\n \nPipe\n \nLift casing to vertical\n \nVisual\n \nTDA 202 closed.', 'Hoisting will stop\n \nLSA 228 guide\n \n \n \n \nHandler\n \nposition above MOH\n \n \nVerify LSA 228 is\n \nprior to lifting casing\n \nto Closed state.', '204:\n \n \npositioned to receive\n \nout of CW 131 without\n \nLSA 228\n \n \n \n \n \nVerify TDA 202 is\n \n \ncasing bottom before\n \nguiding.', 'centralizer to\n \n \n \n \n \nclosed.', 'hoisting.', 'LSA 228 centralizer\n \nClosed state.', 'Hoist TDA 202 to\n \n \nTDA 202 above LSA\n \nclose when casing is\n \nShow TDA 202/\n \n \n \n \n \npick-up casing single\n \n \n228 operating area.', 'close to vertical.', 'LSA 228 in MOH\n \n \n \n \n \nfrom CW 131.', 'TDA 202 and LSA\n \n204 position.\n \n \n \n \n \nMove LSA 228 to\n \n \n \n228 will position\n \n \n \n \n \npreset position to\n \n \n \ncasing above MOH\n \n \n \n \n \nprepare for guiding.', '204/ITC 236.', 'Before casing lower\n \n \n \n \n \nend leaves CW 131,\n \n \n \n \n \nclose LSA 228 funnel.', 'Continue hoisting\n \n \n \n \n \nTDA 202 until the\n \n \n \n \n \ncasing is above MOH\n \n \n \n \n \n204.\n \n \n \n6.1.', 'Pipe\n \nCW 131 retract to\n \nVisual/\n \n \nSkate 133 will move\n \nAnimate\n \n \n \n \nHandler\n \nloading position:\n \nCCTV\n \n \nto loading position.\n \nposition.', 'Verify casing pin end\n \n \n \nRamp 149 will tilt to\n \n \n \n \n \nis clear of ramp149.\n \n \n \nloading position.', 'Move CW 131 toward\n \n \n \n \n \nFT loading position.', '6.2.\n \nPipe\n \nCW 131 load and\n \nVisual/\n \n \nSee steps 1 and 2.\n \n \n \n \nHandler\n \npresent next casing\n \nCCTV\n \n \n \n \n \nsingle:\n \n \n \n \n \nPick up next casing\n \n \n \n \n \nsingle per steps 1 and\n \n \n \n \n \n2.\n \n \n \n7.\n \nPipe\n \nStab/position first\n \nVisual\n \nCasing bottom clear\n \nTDA 202 is rotated\n \nIndicate LSA\n \n \n \n \nHandler\n \ncasing in MOH 204/\n \n \nof CW 131.', 'when casing single\n \n228, ITC 236,\n \n \n \n \n \nITC 236:\n \n \nLSA 228 close when\n \nis lowered into MOH\n \nand LTC 244\n \n \n \n \n \nVerify TDA 202/LSA\n \n \ncasing close to vertical.\n \n204 with elevator\n \nguide/ grip\n \n \n \n \n \n228 are above MOH\n \n \nLTC 244 open above\n \nopening facing Pipe\n \nstates.', '204.', 'MOH 204.', 'Handler Operator\n \nIndicate LSA\n \n \n \n \n \nLower casing single\n \n \n \n195 (permits open\n \n228, ITC 236,\n \n \n \n \n \ninto ITC 236/LSA 228.\n \n \n \nand retract outside\n \nand LTC 244\n \n \n \n \n \nExtend ITC 236 when\n \n \n \nWC 203 area).', 'positions.', 'pin end below guide.', 'Close ITC 236 guide.', 'Open and retract LSA\n \n \n \n \n \n228.', 'Close LTC 244 guide\n \n \n \n \n \nwhen pin end above\n \n \n \n \n \nMOH 204.', 'Continue lowering\n \n \n \n \n \ncasing inside MOH\n \n \n \n \n \n204.\n \n \n \n \n \nStop with stick-up of\n \n \n \n \n \nabout one meter.\n \n \n \n8.', 'Pipe\n \nClose ITC 236 clamp\n \nVisual/\n \n \n \nITC 236 and\n \n \n \n \nHandler\n \non casing:\n \nCCTV\n \n \n \nLTC 244 to\n \n \n \n \n \nVerify correct stick-\n \n \n \n \nClosed state.\n \n \n \n \n \nup.', 'Close ITC 236 guide\n \n \n \n \n \nand clamps.', 'Open and retract LTC\n \n \n \n \n \n244.\n \n \n \n9.\n \nPipe\n \nTransfer weight to ITC\n \nVisual/\n \nITC 236 closed.', 'Verify weight\n \nTDA 202 load\n \n \n \n \nHandler\n \n236 and open TDA\n \nCCTV\n \nWeight transferred.', 'transferred prior to\n \nindicator.', '202:\n \n \n \nopening TDA 202.\n \nTDA to Open\n \n \n \n \n \nLower TDA 202 to\n \n \n \n \nstate.\n \n \n \n \n \ntransfer casing weight\n \n \n \n \n \nto ITC 236.', 'Open TDA 202 and\n \n \n \n \n \nretract from stick-up.', 'Move TDA 202 to CW\n \n \n \n \n \n131 pick-up position.', '10.\n \nPipe\n \nPresent second casing\n \nVisual\n \nRamp 149 in tubular\n \nSkate 133 will move\n \n \n \n \nHandler\n \nsingle above TDA 202\n \n \npick-up position.', 'forward a defined\n \n \n \n \n \nelevator:', 'TDA 202 in tubular\n \ndistance depending\n \n \n \n \n \nVerify TDA 202\n \n \npickup position.', 'on casing size (see\n \n \n \n \n \nelevator open and\n \n \n \nstep 4).', 'below tubular pick-up\n \n \n \n \n \nposition.', 'Run skate 133 until\n \n \n \n \n \ncasing is positioned\n \n \n \n \n \nabove TDA 202\n \n \n \n \n \nelevator.', '11.\n \nPipe\n \nLatch TDA 202 on\n \nVisual\n \nSecond casing single\n \nTubular interlock\n \nTDA 202 to\n \n \n \n \nHandler\n \nsecond casing single:\n \n \nis positioned correctly\n \nwill prevent hoisting\n \nClosed state.', 'Hoist TDA 202 to\n \n \nabove TDA 202\n \nwithout TDA 202\n \n \n \n \n \nlatch onto second\n \n \nelevator.', 'elevator closed\n \n \n \n \n \ncasing single.', '(above certain\n \n \n \n \n \nClose TDA 202.\n \n \n \nheight).\n \n \n \n12.\n \nPipe\n \nLift casing to vertical\n \nVisual\n \nTDA 202 closed.', 'Hoisting will stop\n \nIndicate LSA\n \n \n \n \nHandler\n \nposition above MOH\n \n \nVerify LSA 228 is\n \nprior to lifting casing\n \n228 guide\n \n \n \n \n \n204:\n \n \npositioned to receive\n \nsingle out of CW 131\n \nposition.', 'Verify TDA 202 is\n \n \ncasing bottom before\n \nwithout guiding.', 'Indicate TDA\n \n \n \n \n \nclosed.\n \n \nhoisting.', 'LSA 228 centralizer\n \n202/LSA 228 in\n \n \n \n \n \nHoist TDA 202 to pick\n \n \nTDA 202 above LSA\n \nclose when casing\n \nMOH 204\n \n \n \n \n \nup casing single from\n \n \n228 operating area.', 'single is close to\n \nposition.', 'CW 131.\n \n \n \nvertical.\n \n \n \n \n \nMove LSA 228 to\n \n \n \nTDA 202 and LSA\n \n \n \n \n \npreset position to\n \n \n \n228 will position\n \n \n \n \n \nprepare for guiding.\n \n \n \ncasing single tubular\n \n \n \n \n \nBefore casing single\n \n \n \nabove MOH 204/ITC\n \n \n \n \n \nlower end leaves CW\n \n \n \n236.\n \n \n \n \n \n131, close LSA 228\n \n \n \n \n \nfunnel.', 'Continue hoisting\n \n \n \n \n \nTDA 202 until casing\n \n \n \n \n \nsingle is above MOH\n \n \n \n \n \n204.\n \n \n \n13.', 'Pipe\n \nCW 131 retract to\n \nVisual/\n \n \nCWM 131 pipe\n \nIndicate\n \n \n \n \nHandler\n \nloading position:\n \nCCTV\n \n \nfeeder will move to\n \npositions.', 'Verify casing pin end\n \n \n \nloading position.', 'is clear of ramp 149.', 'Ramp 149 will tilt to\n \n \n \n \n \nMove CW 131 toward\n \n \n \nloading position.', 'FT loading position.', '14.', 'Pipe\n \nCW 131 load and\n \nVisual/\n \n \nSee steps 1 and 2.\n \n \n \n \nHandler\n \npresent third casing\n \nCCTV\n \n \n \n \n \nsingle (if applicable):\n \n \n \n \n \nPick up next casing\n \n \n \n \n \nsingle per steps 1 and\n \n \n \n \n \n2.\n \n \n \n15.\n \nPipe\n \nMove THA/CTO to\n \n \nCTO open.', 'CTO will move to\n \nTHA/CTO in\n \n \n \n \nHandler\n \nMOH 204:\n \n \nWC 203 selected.', 'MOH 204.', 'MOH 204.', 'Verify that casing is\n \n \nLSA 228 in WC 203.', 'Elevate to stick-up.', 'located above MOH\n \n \n \nZMS will stop CTO if\n \n \n \n \n \n204 and LSA 228\n \n \n \nTD 116 or LSA 228 is\n \n \n \n \n \nabove CTO working\n \n \n \ntoo low.\n \n \n \n \n \narea.', 'Start CTO sequence\n \n \n \n \n \nto move THT to MOH\n \n \n \n \n \n204.\n \n \n \n16.', 'Pipe\n \nClose CTO BUT:\n \nVisual/\n \nCTO in MOH 204.', 'CTO BUT will close.', 'CTO BUT to\n \n \n \n \nHandler\n \nAdjust/verify correct\n \nCCTV\n \n \nCTO stabbing guide\n \nClosed state.', 'CTO elevation.\n \n \n \nwill close.', 'CTO SG to\n \n \n \n \n \nContinue CTO\n \n \n \n \nClosed state.\n \n \n \n \n \nsequence.', '17.\n \nPipe\n \nClose MUST for soft\n \nVisual/\n \nCTO in WC 203.\n \nMUST will close.', 'MUST to\n \n \n \n \nHandler\n \nstabbing (optional):\n \nCCTV\n \n \nMUST will take some\n \nClosed state.', 'Adjust CTO elevation\n \n \n \nload if closed prior to\n \n \n \n \n \nand TDA 202 elevation\n \n \n \nstabbing casing (soft\n \n \n \n \n \nif required.\n \n \n \nstab).', 'Continue CTO\n \n \n \n \n \nsequence.', '18.\n \nDriller\n \nStab casing:\n \nVisual/\n \nCTO in WC 203 with\n \nWeight transferred\n \nCTO SG to\n \n \n \n \n \nLower TDA 202 to\n \nCCTV\n \nstabbing guide\n \nto MUST per casing\n \nOpen state.', 'stab casing (soft stab).\n \n \nclosed.', 'data input.', 'TDA 202 weight\n \n \n \n \n \nOpen CTO stabbing\n \n \n \n \nindicator.\n \n \n \n \n \nguide (e.g., for better\n \n \n \n \n \nview).', '19.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \nCTO stabbing guide\n \n \nLSA 228 to\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \nclosed.', 'Open status.', 'Open and retract LSA\n \n \n \n \n \n228 when casing has\n \n \n \n \n \nentered stabbing\n \n \n \n \n \nguide.\n \n \n \n20.\n \nPipe\n \nCTO spin-in and MU:\n \nVisual/\n \nCasing stabbed in\n \nCTO will spin-in and\n \nCasing\n \n \n \n \nHandler\n \nVerify casing is\n \nCCTV\n \nstick-up.', 'MU automatically per\n \nconnected state.\n \n \n \n \n \nstabbed in box.', 'TDA 202 unloaded,\n \ncasing data settings.', 'Continue CTO\n \n \nelevator below TJ to\n \nIf Accept: Open\n \n \n \n \n \nsequence.', 'permit spinning.', 'spinner, guide, and\n \n \n \n \n \nAccept or reject MU.\n \n \n \nclamps.\n \n \n \n \n \n \n \n \nReturn to park\n \n \n \n \n \n \n \n \nposition.', 'If not accepted:\n \n \n \n \n \n \n \n \nEvaluate break-out,\n \n \n \n \n \n \n \n \nspin-out, and new\n \n \n \n \n \n \n \n \nattempt.\n \n \n \n21.\n \nPipe\n \nLower casing double\n \nVisual/\n \nCTO has completed\n \n \nTDA 202/LSA\n \n \n \n \nHandler\n \ninto MOH 204 (if\n \nCCTV\n \nMU sequence with\n \n \n228 close/open\n \n \n \n \n \napplicable):\n \n \naccepted MU.\n \n \nstatus.', 'Verify connection is\n \n \n \n \nTDA 202 load.\n \n \n \n \n \nmade-up.', 'LTC 244/ITC 236\n \n \n \n \n \nHoist TDA 202 to pick\n \n \n \n \nstatus.', 'up weight.', 'Open ITC 236 guide\n \n \n \n \n \nand clamps.', 'Lower casing double\n \n \n \n \n \nto correct stick-up.\n \n \n \n \n \nStop at selected stick-\n \n \n \n \n \nup (e.g., about one\n \n \n \n \n \nmeter).', 'Close ITC 236 guide\n \n \n \n \n \nand clamps.', 'Lower TDA 202 to\n \n \n \n \n \ntransfer weight to ITC\n \n \n \n \n \n236.\n \n \n \n \n \nOpen TDA 202 and\n \n \n \n \n \nretract from stick-up.', '22.\n \nPipe\n \nRepeat steps 10-20 for\n \n \n \n \nHandler\n \nthird single (if\n \n \n \n \n \napplicable).', '23.\n \nPipe\n \nMove casing stand to\n \nVisual/\n \nRN 151 has\n \n \nWeight transfer.', 'Handler\n \nTHP 207:\n \nCCTV\n \ncompleted MU\n \n \n \n \n \nLTC 244 extends to\n \n \nsequence with correct\n \n \n \n \n \ncasing stand in MOH\n \n \ntorque.', '204 position and close\n \n \nComplete casing\n \n \n \n \n \nguide.\n \n \nstand in MOH 204.', 'Hoist TDA 202 to pick\n \n \n \n \n \nup weight.', 'Open ITC 236 guide\n \n \n \n \n \nand clamps.', 'Retract ITC 236\n \n \n \n \n \nhead.', 'TDA 202 will lift\n \n \n \n \n \ncasing stand from\n \n \n \n \n \nMOH 204 and stop\n \n \n \n \n \nwith pin end above\n \n \n \n \n \nTHP doper 209.', 'TDA 202 and LTC\n \n \n \n \n \n244 move casing stand\n \n \n \n \n \nto above THP 207.', 'UTC 242 extends to\n \n \n \n \n \ncasing stand and\n \n \n \n \n \ncloses.', 'TDA 202 opens and\n \n \n \n \n \nretracts from casing\n \n \n \n \n \nstand.', '24.\n \nPipe\n \nSet back casing stand:\n \nVisual/\n \nUTC 242 and LTC\n \n \nTBR 254/SGA\n \n \n \n \nHandler\n \nTBR 254 and SGA\n \nCCTV\n \n244 closed on casing\n \n \n262 status.', '262 move to THP 207\n \n \nstand in THP 207.', 'TBR 254 load.', 'and close guide and\n \n \nTDA 202 retracted\n \n \n \n \n \nclamps on casing\n \n \nfrom casing stand in\n \n \n \n \n \nstand.', 'THP 207.\n \n \n \n \n \nUTC 242 and LTC\n \n \n \n \n \n244 open and retract.', 'TBR 254 and SGA\n \n \n \n \n \n262 set back casing\n \n \n \n \n \nstand to selected\n \n \n \n \n \nposition in FIB 166.\n \n \n \n25.', 'Pipe\n \nTBR 254 and SGA 262\n \n \nUTC 242/LTC 244\n \nTBR 254 clamp and\n \nTBR 254 clamp\n \n \n \n \nHandler\n \nmove to THP 207:\n \n \nclosed on casing\n \nguide and SGA 262\n \nand guide and\n \n \n \n \n \nOpen TBR 254 and\n \n \nstand.', 'guide will open.', 'SGA 262 guide\n \n \n \n \n \nSGA 262 in FIB 166.', 'TBR 254 will hoist\n \nto Open state.', 'Move toward THP\n \n \n \nbefore it retracts out of\n \n \n \n \n \n207/next casing stand.', 'FIB 166.', 'Continue step 1.', 'For tripping-in casing stands without the CRT, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth below in Table 14A.\n \n \n \n \n \n \n \n \nTABLE 14A\n \n \n \n \n \n \n \n \nPreparations for Tripping-In Casing Stands Without CRT\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nFIB 166\n \nOperator 195 on rig floor 114.', 'Casing stands (111) exist in FIB 166\n \n \n \nSetback 164\n \n \nslots per HMI/tally.', 'Fingers are closed.', 'Travel path is unobstructed.', 'TBR 254\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'SGA 262\n \n \nGripper inserts/dies are clean, not worn.', 'LTC 244\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'ITC 236\n \n \nGripper inserts/dies are clean, not worn.', 'UTC 242\n \n \n \nLSA 228\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'TDA 202\n \nOperator 195 on rig floor 114.', 'Travel path is unobstructed.', 'Correct inserts in TDA 202\n \n \n \n \n \nelevator/grippers.', 'CTO\n \nOperator 195 on rig floor 114.', 'CTO is rigged up in THA (or THT).', 'THA-CTO\n \n \nCorrect adaptors and stabbing guide\n \n \n \n(primary)\n \n \nfunnel is installed.\n \n \n \nTHT-CTO\n \n \nDies are correct, clean, and not worn.', '(backup)\n \n \nTravel path is unobstructed.', 'Slips 161\n \nOperator 195 on rig floor 114; and/or\n \nCorrect inserts/dies.', '“Driller” 195 at workstation 452.', 'Inserts/dies are clean, not worn.', 'TD 116\n \nOperator 195 on rig floor; and/or\n \nCorrect inserts/dies in elevator 129.\n \n \n \n \n“Driller” 195 at workstation 452.', 'Correct saver sub status.', 'Travel path is unobstructed.', 'DW 119\n \nOperator 195 on rig floor; and/or\n \nChecked.', '“Driller” 195 at workstation 452.', 'The well construction system \n100\n, \n200\n can then be set-up for the non-CRT casing stand trip-in sequence.', 'Examples of such set-up may be as set forth below in Table 14B.\n \n \n \n \n \n \n \n \nTABLE 14B\n \n \n \n \n \n \n \n \nSet-Up for Tripping-In Casing Stands Without CRT\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'handling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nTBR 254,\n \n \nemergency stop for all pipe handling\n \nsetup wizard.\n \n \n \nSGA 262,\n \n \nequipment.', 'After startup: Check for\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \nLTC 244,\n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \nTHP 207,\n \n \nSelect Trip In Casing mode.', 'status header on front\n \n \n \nTDA 202,\n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \nLSA 228,\n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \nTHA-\n \n \nsettings:\n \n \n \nCTO\n \n \nSelect casing type and verify casing\n \n \n \n \n \ndata (size, weight, MU loss,\n \n \n \n \n \ntorque settings, etc.).', 'Select CTO to use.\n \n \n \n \n \nStick-up target.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'DW 119,\n \n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nMP 144,\n \n \nemergency stop for all pipe handling\n \nsetup wizard.', 'Trip tank\n \n \nequipment.', 'After startup: Check for\n \n \n \n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \n \n \nSelect Trip In Casing mode.', 'status header on front\n \n \n \n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \n \n \nsettings:\n \n \n \n \n \nStick-up target.', 'Set DW 119 upper/lower stops.', 'Set maximum lowering speed.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Active tanks selected and lined up.', 'Set alarm limits for gain/loss.', 'Select MP 144 for filling casing.', 'MP 144 liner size setting and pump\n \n \n \n \n \nefficiency.', 'Set number of strokes for filling\n \n \n \n \n \ncasing stand (selected MP 144 will\n \n \n \n \n \nstop after set number of strokes).', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator screen,\n \n \n \n \n \ncompleted pre-checks.', 'system status/alarms.', 'Activate TD 116 from touchscreen 522,\n \n \n \n \n \n524.', 'Select Operation screen on touchscreen\n \n \n \n \n \n522, 524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator screen,\n \n \n \n \n \n524.\n \nsystem status/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled\n \nVerify operator screen,\n \n \n \nmachines\n \n \nin zone management system and\n \nsystem status/alarms.', 'tubular interlock system.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'The sequence for non-CRT tripping-in casing stands may start with the top drive \n116\n in lower position at WC \n203\n, with the slips \n161\n closed around a casing stick-up of about one meter.', 'Another casing stand \n111\n may be in the TDA \n202\n/LSA \n228\n, lifted from THP \n207\n to stick-up level above the MOH \n204\n, with the TDA \n202\n elevator facing the top drive \n116\n.', 'The THP \n207\n, UTC \n242\n, and LTC \n244\n may be open and retracted.', 'The TBR \n254\n and SGA \n262\n may be empty (e.g., on the way to pick up a new casing stand from the FIB \n166\n).', 'Example steps of the non-CRT tripping-in casing stand sequence may be as set forth below in Table 14C.\n \n \n \n \n \n \n \n \nTABLE 14C\n \n \n \n \n \n \n \n \nTripping-In Casing Stands Without CRT Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.\n \nDriller\n \nOpen TD 116 elevator\n \nVisual/\n \nSlips 161 must be\n \nElevator 129 Open is\n \nTD 116 elevator\n \n \n \n \n \n129:\n \nCCTV\n \nclosed before opening\n \nnot selectable if slips\n \n129 to Open\n \n \n \n \n \nVerify slips 161 are\n \n \nelevator 129.', '161 are not closed.', 'state.\n \n \n \n \n \nclosed.', 'Open elevator 129.\n \n \n \n1.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA\n \nTBR 254 will move\n \nTBR 254 and\n \n \n \n \nHandler\n \npick up new casing\n \nCCTV\n \n262 grip/guide open.\n \ninto FIB 166 elevated\n \nSGA 262 grip/\n \n \n \n \n \nstand:\n \n \nSelected FIB 166\n \nabove open latches.\n \nguide to Closed\n \n \n \n \n \nMove TBR 254 and\n \n \nposition “valid.”', 'Adjustments available.\n \nstate.', 'SGA 262 to selected\n \n \n \nTBR 254 and SGA\n \n \n \n \n \nfinger/slot in FIB 166.\n \n \n \n262 grip/guide will\n \n \n \n \n \nClose TBR 254 and\n \n \n \nClose.', 'SGA 262 guides and\n \n \n \n \n \nclamp on stand.', '2.\n \nDriller\n \nRetract and move TD\n \nVisual/\n \nTD 116 pipe handler\n \n \nDW 119 Upper\n \n \n \n \n \n116 to latching height:\n \nCCTV\n \nposition facing TDA\n \n \nStop setting.', 'Verify elevator 129 is\n \n \n202.\n \n \n \n \n \nopen.', 'Retract TD 116 to\n \n \n \n \n \nclear TJ.', 'Hoist TD 116 elevator\n \n \n \n \n \n129 to stand latch\n \n \n \n \n \nheight (upper stop or\n \n \n \n \n \ncalculated stop point).', '2.1.', 'Pipe\n \nTDA 202 move stand\n \nVisual/\n \nTD 116 retracted.', 'Tilt towards WC 203.', 'TDA 202 Load\n \n \n \n \nHandler\n \nto WC 203:\n \nCCTV\n \n \nTDA 202 dope top\n \nindication.', 'Continue lifting TDA\n \n \n \nbox if preselected\n \n \n \n \n \n202 and extend to WC\n \n \n \n(automatic).', '203 (above stick-up).', 'LSA 228 guide to WC\n \n \n \n \n \n203 when pin end\n \n \n \n \n \nabove rig floor.', '2.2.\n \nPipe\n \nMove THA/CTO to WC\n \n \nCTO open.', 'CTO will move to WC\n \nTHA/CTO in\n \n \n \n \nHandler\n \n203:\n \n \nWC 203 selected.\n \n203.\n \nWC 203.', 'Verify stand is located\n \n \nLSA 228 in WC 203.', 'Elevate to stick-up.', 'in WC 203 and LSA\n \n \n \nZMS will prevent\n \n \n \n \n \n228 is above CTO\n \n \n \nCTO start if TD 116 or\n \n \n \n \n \nworking area.', 'LSA 228 is too low.', 'Start CTO sequence\n \n \n \n \n \nto move THT to WC\n \n \n \n \n \n203.', 'Optional: Move THT/\n \n \n \n \n \nCTO to WC 203 when\n \n \n \n \n \nTD 116 is above THA,\n \n \n \n \n \nif selected.\n \n \n \n2.3.', 'Pipe\n \nClose CTO BUT:\n \nVisual/\n \nCTO in WC 203.', 'Close CTO BUT.', 'CTO BUT to\n \n \n \n \nHandler\n \nAdjust/verify correct\n \nCCTV\n \n \nClose stabbing guide.', 'Closed state.', 'CTO elevation.', 'CTO SG to\n \n \n \n \n \nContinue CTO\n \n \n \n \nClosed state.\n \n \n \n \n \nsequence.', '2.4.\n \nPipe\n \nClose MUST for soft\n \nVisual/\n \nCTO in WC 203.', 'Close MUST.', 'MUST to\n \n \n \n \nHandler\n \nstabbing (optional):\n \nCCTV\n \n \nMUST will take some\n \nClosed state.', 'Adjust CTO elevation\n \n \n \nload if closed prior to\n \n \n \n \n \nand TD 116 elevation if\n \n \n \nstabbing the casing.\n \n \n \n \n \nrequired.', 'Continue CTO\n \n \n \n \n \nsequence.', '2.5.', 'Driller\n \nStab casing:\n \nVisual/\n \nTD 116 link tilt float.', 'Weight transferred to\n \nCTO SG to\n \n \n \n \n \nLower TD 116 to stab\n \nCCTV\n \nCTO in WC 203 with\n \nMUST per casing\n \nOpen state.', 'casing (soft stab).', 'stabbing guide closed.', 'data input.', 'Open CTO stabbing\n \n \n \n \n \nguide.\n \n \n \n2.6.', 'Pipe\n \nOpen and retract LSA\n \nVisual/\n \nCTO stabbing guide\n \n \nLSA 228 Open\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \nclosed.\n \n \nstatus.', 'Open and retract LSA\n \n \n \n \n \n228 when casing has\n \n \n \n \n \nentered stabbing\n \n \n \n \n \nguide.\n \n \n \n2.7.\n \nPipe\n \nCTO spin-in and MU:\n \nVisual/\n \nStand stabbed in\n \nCTO will spin-in and\n \nCasing\n \n \n \n \nHandler\n \nVerify casing is\n \nCCTV\n \nstick-up (TD 116\n \nMU automatically per\n \nConnected state.', 'stabbed the box.\n \n \nunloaded, elevator\n \ncasing data settings.', 'Continue CTO\n \n \n129 below TJ to\n \nIf Accept: Open\n \n \n \n \n \nsequence.', 'permit spinning).', 'spinner, guide, and\n \n \n \n \n \nAccept or reject MU.\n \n \n \nclamps, then return to\n \n \n \n \n \n \n \n \npark position.', '2.8.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTHP 207 empty.', 'TBR 254 cannot\n \nIndicate open\n \n \n \n \nHandler\n \nmove stand to THP\n \nCCTV\n \nUTC 242/LTC 244\n \nopen with weight.\n \nlatches.', '207:\n \n \nopen.', 'TBR 254 grip open\n \nTBR 254 load\n \n \n \n \n \nOpen FIB 166 latches\n \n \nCorrect pipe detected\n \nwhen unloaded.\n \nindication,\n \n \n \n \n \nfor selected row.\n \n \nin TBR 254 and SGA\n \nFIB 166 latches will\n \nunload.', 'Verify latches open\n \n \n262.\n \nnot open with TBR\n \n \n \n \n \n(visual/CCTV).', '254 head in low\n \n \n \n \n \nTBR 254 lift stand\n \n \n \nposition.\n \n \n \n \n \nand move out of FIB\n \n \n \n \n \n166 to THP 207.', 'FIB 166 latches will\n \n \n \n \n \nclose as stand moves\n \n \n \n \n \nout of FIB 166.', 'Set down stand on\n \n \n \n \n \nTHP 207.', '2.9.\n \nPipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nextend to THP 207 and\n \nCCTV\n \n262 with stand in THP\n \n244 extend and close.', 'LTC 244 to\n \n \n \n \n \nclose:\n \n \n207.\n \n \nClosed state.', 'UTC 242 and LTC\n \n \n \n \n \n244 extend to THP\n \n \n \n \n \n207.\n \n \n \n \n \nUTC 242 and LTC', '244 close.', '2.10.', 'Pipe\n \nTBR 254 and SGA 262\n \n \nUTC 242/LTC 244\n \n \nTBR 254 and\n \n \n \n \nHandler\n \nopen and move toward\n \n \nclosed on stand.', 'SGA 262 to\n \n \n \n \n \nFIB 166:\n \n \n \n \nOpen state.', 'Open TBR 254\n \n \n \n \n \nclamps and guide and\n \n \n \n \n \nSGA 262 guide.', 'Move toward FIB 166/\n \n \n \n \n \nnext stand.', 'Continue step 1.1\n \n \n \n3.', 'Driller\n \nExtend TD 116 and\n \nVisual/\n \nTDA 202 below TJ.\n \n \nElevator 129\n \n \n \n \n \nlatch elevator 129:\n \nCCTV\n \n \n \nClosed state.', 'Extend TD 116 to WC\n \n \n \n \nIndicate TD 116\n \n \n \n \n \n203.', 'in WC 203.', 'Latch elevator 129\n \n \n \n \n \n(automatic close on\n \n \n \n \n \nimpact).', '3.1.', 'Pipe\n \nTDA 202 open and\n \nVisual/\n \nElevator 129 closed.', 'TDA 202 will retract\n \nTDA 202\n \n \n \n \nHandler\n \nmove to THP 207:', 'CCTV\n \n \nfrom WC 203, rotate,\n \nelevator Open\n \n \n \n \n \nVerify TD 116\n \n \n \nand lower until\n \nstate.', 'elevator 129 is closed.', 'elevator (e.g., gripper\n \nTDA 202\n \n \n \n \n \nOpen elevator 129.\n \n \n \n169) faces toward\n \nposition\n \n \n \n \n \nRetract to vertical\n \n \n \nTHP 207.\n \nanimation.\n \n \n \n \n \nlink.', 'Rotate and lower to\n \n \n \n \n \nstand in THP 207.', '4.\n \nDriller\n \nOpen slips 161:\n \nVisual\n \nTD 116 elevator 129\n \n \nSlips 161 to\n \n \n \n \n \nOpen slips 161\n \n \nmust be closed.', 'Open state.', '(command).', 'CTO has completed\n \n \nDW 119 load.', 'Hoist to take weight\n \n \nMU sequence\n \n \n \n \n \nand open slips 161.', 'with accepted\n \n \n \n \n \n \n \nconnection.', '5.\n \nDriller\n \nLower casing string in\n \nVisual\n \nSlips 161 open.', 'MP 144 will stop after\n \nSettings: DW\n \n \n \n \n \nwellbore 102:\n \n \n \nset number of\n \n119 lowering\n \n \n \n \n \nVerify slips 161 are\n \n \n \nstrokes, if selected.', 'speed and\n \n \n \n \n \nopen before lowering\n \n \n \n \nminimum slack-\n \n \n \n \n \ncasing string.', 'off weight.', 'Open IBOP and start\n \n \n \n \nIBOP open.', 'MP 144 to fill casing, if\n \n \n \n \nMP 144\n \n \n \n \n \nselected.', '(Extend\n \n \n \n \nrunning.', 'filling tool, if installed).\n \n \n \n5.1.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTDA 202 elevator\n \nTDA 202 tilt out/\n \n \n \n \nHandler\n \nextend to stand in THP\n \nCCTV\n \nmust be open.', 'extend elevator until\n \n \n \n \n \n207:\n \n \nLSA 228 guide funnel\n \ncontact with stand in\n \n \n \n \n \nTilt out/extend TDA\n \n \nmust be open.', 'THP 207.\n \n \n \n \n \n202 elevator until\n \n \n \n \n \ncontact with stand in\n \n \n \n \n \nTHP 207 below TJ.\n \n \n \n5.2.', 'Pipe\n \nTDA 202 and LSA 228\n \nVisual/\n \nTDA 202 elevator\n \n \nTDA 202\n \n \n \n \nHandler\n \nlatch onto stand in THP\n \nCCTV\n \nmust be in THP 207\n \n \nelevator to\n \n \n \n \n \n207:\n \n \nposition.', 'Closed state.', 'Close TDA 202\n \n \n \n \nLSA 228 guide\n \n \n \n \n \nelevator.', 'to Closed state.', 'Close LSA 228 guide\n \n \n \n \n \nfunnel.', '5.3.\n \nPipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTDA 202 elevator\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nopen and retract.', 'CCTV\n \nmust be closed.', '244 open and retract.', 'LTC 244 to Open\n \n \n \n \n \n \n \n \n \nstate.', 'UTC 242 and\n \n \n \n \n \n \n \n \n \nLTC 244 position\n \n \n \n \n \n \n \n \n \nanimation.', '5.4.\n \nPipe\n \nTDA 202 move stand\n \nVisual/\n \nUTC 242 or LTC 244\n \nTDA 202 hoist, tilt to\n \nTDA 202 Load\n \n \n \n \nHandler\n \nto rig floor:\n \nCCTV\n \nopen.', 'vertical, rotate 180\n \nindication.', 'TDA 202 lift stand\n \n \n \ndegrees to face TD\n \nTDA 202\n \n \n \n \n \nguided by the LSA 228\n \n \n \n116.', 'position\n \n \n \n \n \n(e.g., about nine\n \n \n \nTDA 202 dope top\n \nanimation.\n \n \n \n \n \nmeters) to rig floor 114\n \n \n \nbox if preselected\n \n \n \n \n \nstandby position.', '(automatic).', 'Continue step 2.2\n \n \n \n6.\n \nDriller\n \nSet slips 161:\n \nVisual\n \nStick-up at correct\n \n \nSlips 116 to\n \n \n \n \n \nSet slips 161 at\n \n \nheight.', 'Closed state.', 'correct stick-up height.', 'DW 119 load\n \n \n \n \n \nSet off weight.\n \n \n \n \nindicator.', 'Tally update.', '7.\n \nDriller\n \nCheck trip tank or\n \nVisual\n \nSlips 161 closed.', 'Trip tank gain/loss is\n \nTrip Sheet/\n \n \n \n \n \nactive volume,\n \n \n \ndetermined and\n \nVolume control.', 'gain/loss:\n \n \n \ndisplayed.', 'Trip tank or active\n \n \n \n \n \ngain/loss.\n \n \n \n \n \nRepeat all steps for\n \n \n \n \n \nnext stand.', 'Different combinations of the aspects described above may also be utilized for running large-diameter casing (LDC) from the CW \n131\n with the top drive \n116\n and CRT.', 'For example, LDC may have an outer diameter of about 13.375 inches (about 34 centimeters) or larger.', 'Preparations for such operation may include the examples set forth below in Table 15A.\n \n \n \n \n \n \n \n \nTABLE 15A\n \n \n \n \n \n \n \n \nPreparations for Running LDC from CW with TD and CRT\n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nVerifications\n \n \n \n \n \n \nCW 131\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Casings are laid out correct with aft end in line with skate 133\n \n \n \n \n \nfor correct loading.', 'Prepare to pick up casing.', 'CTO:', 'Operator 195 on\n \nCasing backup tong (CBU) is rigged up in THT.', 'THT + CBU\n \nrig floor 114.', 'CBU adjusted for casing size.', 'Dies are correct, clean, and not worn.', 'Travel path is unobstructed.', 'LSA 228\n \nOperator 195 on\n \nTravel path is unobstructed.\n \n \n \n \nrig floor 114.', 'Slips 161\n \nOperator 195 on\n \nCorrect inserts in slips 161.', 'Rotary\n \nrig floor 114.', 'Dies are clean and not worn.', 'Table\n \n \nRotary table rotation lock activated.', 'TD 116\n \nOperator 195 on\n \nCorrect pick-up elevator 129.\n \n \n \n \nrig floor 114.\n \nCheck elevator link extension chains.', 'Operator screen, system status.', 'Travel path is unobstructed.', 'CRT installed and tested.', 'DW 119\n \nOperator 195 on\n \nChecked.\n \n \n \n \nrig floor 114.\n \n \n \nTubulars\n \nOperator 195 on\n \nTubulars 111 to be laid out on CW 131.\n \n \n \n111\n \nrig floor 114.', 'Tubulars 111 to be cleaned and doped, protectors removed\n \n \n \n \n \n(other implementations may be used for casing with protectors).', 'Casings measured, marked, and tally updated.', 'The well construction system \n100\n, \n200\n can then be set-up for the operation.', 'Examples of such set-up may be as set forth below in Table 8B.\n \n \n \n \n \n \n \n \nTABLE 15B\n \n \n \n \n \n \n \n \nSet-Up for Running LDC from CW with TD and CRT\n \n \n \n \n \n \n \n \n \n \n \nEquipment', 'Responsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nPipe\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nhandling:\n \nHandler\n \ncompleted pre-checks and deactivated\n \nscreen.', 'LSA 228,\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \nCBU,\n \n \nequipment.', 'Program setup\n \n \n \nCW 131\n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Running 13⅜″ Casing from CW\n \nfor green light in\n \n \n \n \n \nwith TD and CRT mode.', 'Construction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nSelect casing size.', 'screen 532, 534,\n \n \n \n \n \nSelect CBU to use.\n \n536.\n \n \n \n \n \nStick-up target.', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback\n \n \n \nDW 119,\n \n \ncompleted pre-checks and deactivated\n \nscreen.', 'MP 144\n \n \nemergency stop for all pipe handling\n \nConstruction\n \n \n \n \n \nequipment.', 'Program setup\n \n \n \n \n \nOpen Construction Program screen on\n \nwizard.', 'touchscreen 522, 524.', 'After startup: Check\n \n \n \n \n \nSelect Running 13⅜″ Casing from CW\n \nfor green light in\n \n \n \n \n \nwith TD and CRT mode.', 'Construction\n \n \n \n \n \nSelect setup wizard to open pop-up on front\n \nProgram status\n \n \n \n \n \nscreen 532, 534, 536.', 'Verify settings:\n \nheader on front\n \n \n \n \n \nStick-up target.', 'screen 532, 534,\n \n \n \n \n \nSet TD elevator link length.', '536.', 'Set DW 119 upper/lower stops.', 'Set maximum lowering speed.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Verify active tanks are selected and\n \n \n \n \n \nlined up.', 'Select MP 144 (to fill casing, optional).', 'Verify MP 144 pressure limit setting.', 'Assign pumps to master slider.', 'Set number of strokes and SPM to fill\n \n \n \n \n \ncasing (optional).', 'Set ramp-up parameters.', 'Verify correct elevator setting\n \n \n \n \n \n(manual/remote).', 'Select “activate all machines” to startup and\n \n \n \n \n \nprepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator\n \n \n \n \n \ncompleted pre-checks.\n \nscreen, system\n \n \n \n \n \nActivate TD 116 from touchscreen 522,\n \nstatus/alarms.', '524.\n \n \n \n \n \nVerify correct elevator 129 setting\n \n \n \n \n \n(manual/remote).', 'Select Operation screen on touchscreen 522,\n \n \n \n \n \n524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator\n \n \n \n \n \n524.\n \nscreen, system\n \n \n \n \n \nSet maximum lowering speed.', 'status/alarms.', 'Set minimum slack off weight.', 'Slips 161,\n \nDriller\n \nVerify correct setting for slips 161\n \nVerify operator\n \n \n \nRotary\n \n \n(manual/remote).', 'screen, system\n \n \n \ntable\n \n \n \nstatus/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled in\n \n \n \nmachines\n \n \nzone management system and tubular\n \n \n \n \n \ninterlock system.', 'Tubulars\n \nPipe\n \nAll tubulars 111 are registered.', '111\n \nHandler\n \n \n \n \n \n \n \n \n \n \nAfter such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'An example of this sequence may start with a casing stick-up (e.g., about 1.5 meters) at WC \n203\n, with the slips \n161\n closed and the CRT engaged.', "Casing may be laid out on the CW \n131\n casing side (e.g., Driller's side), having been cleaned, doped, and tallied, and with protectors removed.", 'The catwalk ramp \n149\n may be loaded with casing.', 'The TDA \n202\n may be parked outside the collision area (e.g., top of the mast), and the LSA \n228\n may be ready.', 'Example steps of the sequence may be as set forth below in Table 15C.\n \n \n \n \n \n \n \n \nTABLE 15C\n \n \n \n \n \n \n \n \nSequence for Running LDC from CW with TD and CRT\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.', 'Driller\n \nRelease CRT from\n \nVisual/\n \nSlips 161 must be\n \n \nCRT to\n \n \n \n \n \nstick-up:\n \nCCTV\n \nclosed before\n \n \nDisconnect\n \n \n \n \n \nVerify slips 161 are\n \n \nreleasing CRT.\n \n \nstate.\n \n \n \n \n \nclosed and links/\n \n \n \n \n \nelevator tilted towards\n \n \n \n \n \nCW 131.', 'Release CRT from\n \n \n \n \n \nstick-up.', 'Hoist TD 116 to CW\n \n \n \n \n \n131 pick-up position\n \n \n \n \n \n(above casing).', '1.1.', 'Pipe\n \nPush casing to rig floor\n \nVisual/\n \n \nSkate 133 will move\n \nCW 131 to CW\n \n \n \n \nHandler\n \n114 pick-up position:\n \nCCTV\n \n \nforward a set\n \n131 pick-up\n \n \n \n \n \nVerify TD elevator\n \n \n \ndistance.\n \nposition.', '129 is above CW 131\n \n \n \n \n \npick-up position.', 'Activate CW 131\n \n \n \n \n \nsequence to move\n \n \n \n \n \ncasing to CW 131 pick-\n \n \n \n \n \nup position.', '2.\n \nDriller\n \nLatch pick-up elevator\n \nVisual\n \nCW 131 in pick-up\n \n \n \n \n \n129:\n \n \nposition.', 'Extend links above\n \n \n \n \n \ncasing.', 'Lower TD 116 to latch\n \n \n \n \n \nelevator 129.', 'Engage safety pin\n \n \n \n \n \n(manual).', '3.\n \nDriller\n \nTD 116 hoist casing\n \nVisual\n \nTD elevator 129\n \nHoisting will stop prior\n \n \n \n \n \nfrom CW 131:\n \n \nclosed.\n \nto lifting casing out of\n \n \n \n \n \nHoist TD 116 to pick\n \n \nLink tilt float: Elevator\n \nCW 131 without\n \n \n \n \n \nup casing from CW\n \n \n129 in WC 203 above\n \nguiding.', '131.\n \n \nRN 151 working area.', 'Activate link tilt float\n \n \n \n \n \nor move elevator 129\n \n \n \n \n \nto vertical position.', '3.1.\n \nPipe\n \nLSA 228 extend to\n \nVisual/\n \nTD 116 above LSA 228\n \n \nLSA 228 funnel\n \n \n \n \nHandler\n \nguide casing above\n \nCCTV\n \noperating area.', 'to Closed state.', 'CW 131:\n \n \n \n \n \nMove LSA 228 to\n \n \n \n \n \npreset position to\n \n \n \n \n \nreceive casing above\n \n \n \n \n \nCW 131.\n \n \n \n \n \nBefore casing lower\n \n \n \n \n \nend leaves CW 131,\n \n \n \n \n \nclose LSA 228 funnel.\n \n \n \n3.2.', 'Pipe\n \nMove THT/CBU to WC\n \n \nCBU open.', 'CBU will move to WC\n \nCBU in WC\n \n \n \n \nHandler\n \n203:\n \n \n \n203.\n \n203.', 'Verify TD 116 hoisted\n \n \n \nElevate to stick up.', 'above CBU working\n \n \n \nZMS will prevent\n \n \n \n \n \narea.', 'CBU start if TD 116 is\n \n \n \n \n \nStart CBU sequence\n \n \n \ntoo low.\n \n \n \n \n \nto move THT/CBU to\n \n \n \n \n \nWC 203.\n \n \n \n3.3.', 'Pipe\n \nLSA 228 tail in casing\n \nVisual\n \nCasing bottom clear\n \n \nLSA 228\n \n \n \n \nHandler\n \nto WC 203:\n \n \nof CW 131 and\n \n \ncentralizer to\n \n \n \n \n \nTD continues\n \n \nelevated above stick-\n \n \nClosed state.', 'hoisting.', 'up.', 'LSA 228 tail in casing\n \n \nLSA 228 funnel close.', 'towards WC 203 when\n \n \n \n \n \npin end is above stick-\n \n \n \n \n \nup.', 'LSA 228 centralizer\n \n \n \n \n \nwill close when casing\n \n \n \n \n \nis close to WC 203.\n \n \n \n3.4.\n \nPipe\n \nGuide casing single\n \nVisual/\n \nCBU in WC 203.', 'Close CBU BUT.\n \nCBU BUT to\n \n \n \n \nHandler\n \nwith CBU in WC 203:\n \nCCTV\n \nLSA 228 in WC 203.', 'Close stabbing guide.', 'Closed state.', 'Verify casing single\n \n \n \n \nCBU guide to\n \n \n \n \n \nlocated in WC 203.', 'Closed state.', 'Continue CBU\n \n \n \n \n \nsequence.', '3.5.\n \nPipe\n \nStab casing:\n \nVisual/\n \nTD 116 in WC 203.', 'Handler\n \nLower TD 116 to stab\n \nCCTV\n \nCBU in WC 203 with\n \n \n \n \n \ncasing in stick-up.', 'stabbing guide closed.', 'Continue lowering to\n \n \n \n \n \nstab CRT.\n \n \n \n3.6.\n \nPipe\n \nOpen and retract LSA\n \nVisual/\n \nCTO stabbing guide\n \n \nLSA 228 Open\n \n \n \n \nHandler\n \n228:\n \nCCTV\n \nclosed.\n \n \nstatus.', 'Open and retract LSA\n \n \n \n \n \n228 when casing has\n \n \n \n \n \nentered stabbing\n \n \n \n \n \nguide.\n \n \n \n3.7.', 'Pipe\n \nCW 131 retract to\n \nVisual/\n \n \nSkate 133 will move\n \nCW 131\n \n \n \n \nHandler\n \nloading position:\n \nCCTV\n \n \nto loading position.\n \nanimation.', 'Verify casing pin end\n \n \n \nRamp 149 will tilt to\n \n \n \n \n \nis clear of ramp 149.\n \n \n \nloading position.', 'Move CW 131 toward\n \n \n \n \n \nFT loading position.', '4.\n \nDriller\n \nStab CRT, spin-in, and\n \nVisual/\n \nCasing single\n \nTD 116/CRT will\n \nCBU closed for\n \n \n \n \n \nMU:\n \nCCTV\n \nstabbed in stick-up\n \nautomatically spin-in\n \nbackup.', 'Verify casing is\n \n \n(TD elevator 129\n \nand MU.', 'Casing\n \n \n \n \n \nstabbed and elevator is\n \n \nbelow TJ to permit\n \n \nConnected state.', 'unloaded (elevator\n \n \nspinning).', 'CRT Engaged\n \n \n \n \n \nsliding down).', 'CBU slips back up.\n \n \nstate.', 'Verify CBU closed for\n \n \n \n \n \nbackup.', '(Optional: or\n \n \n \n \n \nslips 161 closed for\n \n \n \n \n \nbackup).', 'Stab and engage\n \n \n \n \n \n(lock) CRT.\n \n \n \n \n \nSpin-in and MU\n \n \n \n \n \ncasing connection.\n \n \n \n4.1.\n \nPipe\n \nOpen CBU and move\n \n \nCasing connected.', 'Open CBU BUT and\n \nCBU open.', 'Handler\n \nto parked position:\n \n \nCRT connected.', 'move THT to parked\n \nCBU parked.', 'Verify casing has\n \n \n \nposition.\n \n \n \n \n \nbeen made-up.', 'Continue CBU\n \n \n \n \n \nbackup sequence.', '5.\n \nDriller\n \nOpen slips 161:\n \nVisual\n \nTD 116/CRT has\n \n \nSlips 161 to\n \n \n \n \n \nOpen slips 161\n \n \ncompleted MU\n \n \nOpen state.', '(command).', 'sequence with correct\n \n \nDW 119 load.', 'Hoist to take up\n \n \ntorque (CRT\n \n \n \n \n \nweight and open slips\n \n \nconnected).', '161.\n \n \n \n6.\n \nDriller\n \nRun-in-Hole:\n \nVisual\n \nSlips 161 open.', 'Optional: The selected\n \nMP 144 SPM,\n \n \n \n \n \nVerify slips 161 are\n \n \nOptional: MP 144\n \nMP 144 will pump a\n \ntotal strokes,\n \n \n \n \n \nopen before lowering\n \n \nready.', 'set number of strokes\n \nand pressure.', 'casing string into\n \n \n \nat set rate with\n \n \n \n \n \nwellbore 102.\n \n \n \nselected MP 144 and\n \n \n \n \n \nOptional: Fill casing, if\n \n \n \nstop.\n \n \n \n \n \nselected.', 'Open IBOP.', 'Start MP 144\n \n \n \n \n \n(casing fill mode).', 'Close IBOP.', '6.1.\n \nPipe\n \nLoad next casing onto\n \nVisual/\n \nCasing ready in\n \n \n \n \nHandler\n \nramp 149:\n \nCCTV\n \nloading position.', 'Use loading fingers to\n \n \nCW 131 in loading\n \n \n \n \n \nload another casing\n \n \nposition.', 'into ramp 149.\n \n \n \n7.\n \nDriller\n \nOpen pick-up elevator\n \nVisual\n \n \n \n \n \nand tilt out:\n \n \n \n \n \nWhen elevator is\n \n \n \n \n \nclose to rig floor 114,\n \n \n \n \n \nan operator 195\n \n \n \n \n \nremoves safety pin and\n \n \n \n \n \nopens elevator.', 'When the operator is\n \n \n \n \n \nout of the area, tilt links\n \n \n \n \n \nout and continue\n \n \n \n \n \nlowering.\n \n \n \n7.1.\n \nPipe\n \nRun ramp 149 to rig\n \nVisual/\n \nCasing loaded onto\n \nRamp 149 will tilt to\n \nCW 131\n \n \n \n \nHandler\n \nfloor:\n \nCCTV\n \nramp 149.\n \nrig floor 114 tubular\n \nanimated.', 'Verify casing is\n \n \n \nposition.', 'loaded in ramp 149.', 'Skate 133 will move\n \n \n \n \n \nMove ramp 149\n \n \n \ntoward rig floor 114.\n \n \n \n \n \ntoward pipe pick-up\n \n \n \nSkate 133 will stop\n \n \n \n \n \nposition.\n \n \n \nwith casing box inside\n \n \n \n \n \n \n \n \nramp 149.\n \n \n \n8.\n \nDriller\n \nSet slips161:\n \nVisual\n \nStick-up at correct\n \n \nSlips 161 to\n \n \n \n \n \nSet slips 161 at\n \n \nheight.', 'Closed state.', 'correct stick-up height.', 'DW 119 load\n \n \n \n \n \nSet off weight.\n \n \n \n \nindicator.\n \n \n \n9.\n \nDriller\n \nCheck gain/loss:\n \nVisual\n \n \nTrip tank or active\n \nVolume control.', 'Check trip tank gain/\n \n \n \ntank gain/loss is\n \n \n \n \n \nloss or active gain/loss\n \n \n \ndetermined and\n \n \n \n \n \ndepending on selected\n \n \n \ndisplayed.\n \n \n \n \n \noperation.', '10.\n \n \nRepeat sequence for\n \n \n \n \n \nnext casing.', 'For tripping-out drill collar stands, an operator \n195\n on the rig floor \n114\n may verify that various pieces of equipment are properly shut down and locked out, and then perhaps perform other preparations such as the examples set forth above in Table', '11A.', 'The well construction system \n100\n, \n200\n can then be set-up for the drill collar stand trip-out sequence.', 'Examples of such set-up may be as set forth below in Table 16A.\n \n \n \n \n \n \n \n \nTABLE 16A\n \n \n \n \n \n \n \n \nSet-Up for Tripping-Out Drill Collar Stands\n \n \n \n \n \n \n \n \n \n \n \nEquipment\n \nResponsible\n \nSet-Up\n \nHMI\n \n \n \n \n \n \nPipe\n \nDriller/\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'handling:\n \nPipe\n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nTBR 254,\n \nHandler\n \nemergency stop for all pipe handling\n \nsetup wizard.', 'SGA 262,\n \n \nequipment.', 'After startup: Check for\n \n \n \nUTC 242,\n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \nLTC 244,\n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \nTHP 207,\n \n \nSelect Tripping mode.', 'status header on front\n \n \n \nLSA 228,\n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \nRN 151\n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \n \n \nsettings:\n \n \n \n \n \nSelect slot, direction for setting back\n \n \n \n \n \ndrill collar stands.', 'Select pipe type.', 'Select RN 151 to use.', 'RN 151 MU torque.', 'Select pin/box doping.', 'Stick-up target.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116,\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify Setback screen.', 'DW 119,\n \n \ncompleted pre-checks and deactivated\n \nConstruction Program\n \n \n \nMP 144,\n \n \nemergency stop for all pipe handling\n \nsetup wizard.', 'Trip tank\n \n \nequipment.', 'After startup: Check for\n \n \n \n \n \nOpen Construction Program screen on\n \ngreen light in\n \n \n \n \n \ntouchscreen 522, 524.\n \nConstruction Program\n \n \n \n \n \nSelect Tripping DC mode.', 'status header on front\n \n \n \n \n \nSelect setup wizard to open pop-up on\n \nscreen 532, 534, 536.\n \n \n \n \n \nfront screen 532, 534, 536.', 'Verify\n \n \n \n \n \nsettings:\n \n \n \n \n \nStick-up target.', 'Set DW 119 upper/lower stops.', 'Set maximum lowering speed.', 'Set minimum slack off weight.', 'Trip tank 1/2/auto.', 'Trip tank low/high levels.', 'Select “activate all machines” to startup\n \n \n \n \n \nand prepare all machines.', 'TD 116\n \nDriller\n \nVerify operator 195 on rig floor 114\n \nVerify operator screen,\n \n \n \n \n \ncompleted pre-checks.', 'system status/alarms.', 'Activate TD 116 from touchscreen 522,\n \n \n \n \n \n524.', 'Select Operation screen on touchscreen\n \n \n \n \n \n522, 524.', 'DW 119\n \nDriller\n \nActivate DW 119 from touchscreen 522,\n \nVerify operator screen,\n \n \n \n \n \n524.\n \nsystem status/alarms.', 'All\n \nDriller\n \nVerify all relevant machines are enabled\n \nVerify operator screen,\n \n \n \nmachines\n \n \nin zone management system and\n \nsystem status/alarms.', 'tubular interlock system.', 'After such preparations and set-up, the operator \n195\n may vacate the rig floor \n114\n, and the equipment may be configured to be ready for remote control (e.g., by deactivating emergency stops).', 'The sequence for tripping-out drill collar stands may start with a drill collar stand \n111\n stick-up at WC \n203\n, with the top drive \n116\n elevator \n129\n closed on the stick-up and the slips \n161\n closed.', 'The UTC \n242\n and LTC \n244\n may be closed on another drill collar stand \n111\n in the THP \n207\n, with washing and doping of the pin already completed.', 'The TDA \n202\n may be parked outside the collision area, and the LSA \n228\n, TBR \n254\n, and SGA \n262\n may each be empty.', 'Example steps of the drill collar stand tripping-out sequence may be as set forth below in Table 16B.\n \n \n \n \n \n \n \n \nTABLE 16B\n \n \n \n \n \n \n \n \nTripping-Out Drill Collar Stands Operation\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOperator\n \n \nLine of\n \nEquipment\n \nEquipment\n \n \n \n \n \n195\n \nOperation\n \nSight\n \nprecondition\n \nFunctionality\n \nHMI\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1.', 'Driller\n \nOpen slips 161 and\n \nVisual/\n \nElevator 129 must be\n \nSlips 161 Open is\n \nSlips 161 to\n \n \n \n \n \nhoist drill string 120:\n \nCCTV\n \nclosed before opening\n \nnot selectable if\n \nOpen state.', 'Verify TD elevator\n \n \nslips 161.', 'elevator 129 is not\n \nSettings: DW\n \n \n \n \n \n129 is closed under TJ.\n \n \n \nclosed.', '119 hoisting\n \n \n \n \n \nOpen slips 161.\n \n \n \nSlips 161 Open\n \nspeed and\n \n \n \n \n \nHoist to take weight\n \n \n \ncommand is reset\n \nmaximum\n \n \n \n \n \nand verify slips 161\n \n \n \nafter a set time if slips\n \noverpull.\n \n \n \n \n \nopen.', '161 are not opened.', '1.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nTBR 254 and SGA\n \nTBR 254 and SGA\n \nTBR 254 and\n \n \n \n \nHandler\n \nwill pick up stand from\n \nCCTV\n \n262 grip/guide open.', '262 grip/guide will\n \nSGA 262 grip/\n \n \n \n \n \nTHP 207:\n \n \n \nclose automatically.', 'guide to Closed\n \n \n \n \n \nMove TBR 254 and\n \n \n \n \nstates.', 'SGA 262 to THP 207.', 'Close guides and\n \n \n \n \n \nclamp on stand.', '1.2.', 'Pipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTBR 254 and SGA\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \nopen and retract:\n \nCCTV\n \n262 closed on stand\n \n244 open and retract.', 'LTC 244 to\n \n \n \n \n \nUTC 242 and LTC\n \n \nin THP 207.', 'Open state -\n \n \n \n \n \n244 open guides.\n \n \n \n \nretracted.', 'UTC 242 and LTC\n \n \n \n \n \n244 retract from THP\n \n \n \n \n \n207.\n \n \n \n1.3.', 'Pipe\n \nTBR 254 and SGA 262', 'Visual/\n \nValid FIB 166 position\n \nTBR 254 and SGA\n \nTBR 254 load.', 'Handler\n \nmove toward FIB 166\n \nCCTV\n \nselected.', '262 will follow\n \nFIB 166 latches\n \n \n \n \n \nwith stand:\n \n \n \npredefined path.', 'to Open state.', 'Lift stand from THP\n \n \n \nFIB 166 latches will\n \nFIB 166 latches\n \n \n \n \n \n207.\n \n \n \nopen when stand is\n \nto Closed state.', 'Move to selected\n \n \n \noutside selected FIB\n \n \n \n \n \nposition in FIB 166.\n \n \n \n166 row.', 'FIB 166 latches will\n \n \n \n \n \n \n \n \nclose prior to setting\n \n \n \n \n \n \n \n \ndown the stand.', 'Set down stand on\n \n \n \n \n \n \n \n \nselected position.\n \n \n \n1.4.', 'Pipe\n \nMove RN 151 to WC\n \nVisual/\n \nRN tongs open.', 'RN 151 will move to\n \nTJ (stick-up)\n \n \n \n \nHandler\n \n203:\n \nCCTV\n \nWC 203 selected.', 'WC 203.', 'assist\n \n \n \n \n \nVerify TD 116 is\n \n \n \nElevate RN 151 to\n \nindication.\n \n \n \n \n \nhoisted above RN 151\n \n \n \nstick-up.\n \n \n \n \n \nworking area.', 'RN 151 will stop/wait\n \n \n \n \n \nStart RN 151 break-\n \n \n \noutside WC 203 area if\n \n \n \n \n \nout sequence to move\n \n \n \nTD 116 is moving.', 'RN 151 to WC 203.\n \n \n \n1.5.\n \nPipe\n \nLSA 228 move to WC\n \nVisual/\n \n \nLSA 228 will stop/\n \n \n \n \nHandler\n \n203:\n \nCCTV\n \n \nwait outside WC 203\n \n \n \n \n \nLSA 228 move to WC\n \n \n \narea if TD 116 is\n \n \n \n \n \n203.\n \n \n \nmoving.', '2.\n \nDriller\n \nSet slips 161:\n \nVisual/\n \n \n \nDW 119 Upper\n \n \n \n \n \nVerify required stick-\n \nCCTV\n \n \n \nstop setting.', 'up height.', 'Set slips 161\n \n \n \n \n \n(command).', 'Set off weight.\n \n \n \n2.1.', 'Pipe\n \nRN 151 break-out and\n \nCCTV\n \nSlips 161 closed.', 'Break-out and spin-\n \nRN 151\n \n \n \n \nHandler\n \nspin-out:\n \n \n \nout.', 'Double break-out\n \nindication.', 'Verify slips 161\n \n \n \navailable if required.', 'Stand not\n \n \n \n \n \nclosed and weight set\n \n \n \nOpen RN 151\n \nconnected.\n \n \n \n \n \noff.', 'spinner, guide, and\n \n \n \n \n \nAdjust RN 151\n \n \n \nclamps.\n \n \n \n \n \nelevation if required.', 'Return RN 151 to\n \n \n \n \n \nContinue RN 151\n \n \n \npark position.\n \n \n \n \n \nsequence.', 'Note: Spin-out\n \n \n \n \n \ncarefully.', 'Manual\n \n \n \n \n \nmode available.', '2.2.\n \nPipe\n \nLSA 228 guide close:\n \nVisual/\n \nSlips 161 closed.', 'LSA 228 will not close\n \nLSA 228 in WC\n \n \n \n \nHandler\n \nVerify LSA 228 in WC\n \nCCTV\n \n \nin WC 203 if slips 161\n \n203.\n \n \n \n \n \n203 and slips 161\n \n \n \nare not closed.', 'LSA 228 guide\n \n \n \n \n \nclosed.\n \n \n \n \nfunnel to Closed\n \n \n \n \n \nClose LSA 228 guide\n \n \n \n \nstate.\n \n \n \n \n \nfunnel.', '3.\n \nDriller\n \nHoist stand from stick-\n \nVisual/\n \nRN finished spin-out,\n \nThe stand is lifted\n \n \n \n \n \nup:\n \nCCTV\n \nBUT open.', 'carefully.', 'Lifting is\n \n \n \n \n \nVerify RN 151 is\n \n \nLSA 228 funnel\n \nstopped if stand\n \n \n \n \n \nfinished and open and\n \n \nclosed.', 'catches on threads in\n \n \n \n \n \nLSA 228 is closed.', 'TJ.\n \n \n \n \n \nOption: If second RN\n \n \n \n \n \n151 is used, first RN\n \n \n \n \n \n151 should be\n \n \n \n \n \nretracted.', 'Hoist stand above\n \n \n \n \n \nstick-up.', '3.1.\n \nPipe\n \nLSA 228 guides stand\n \nVisual/\n \nRN 151 open.', 'Animated\n \n \n \n \nHandler\n \nto THP 207:\n \nCCTV\n \nOptional: Second RN\n \n \npositions.', 'Verify pin above stick-\n \n \n151 open and\n \n \n \n \n \nup.', 'retracted.', 'LSA 228 guides stand\n \n \n \n \n \ntoward THP 207.', 'UTC 242 and LTC\n \n \n \n \n \n244 extend to DCH.', '4.\n \nDriller\n \nLower stand to THP\n \nVisual/\n \n \nTD 116 will stop with\n \n \n \n \n \n207:\n \nCCTV\n \n \nelevator 129 above\n \n \n \n \n \nVerify stand (pin end)\n \n \n \nUTC 242.\n \n \n \n \n \nis outside rig floor 114.', 'Lower stand to THP\n \n \n \n \n \n207 guided by LSA\n \n \n \n \n \n228.', 'Tilt links out toward\n \n \n \n \n \nUTC 242.\n \n \n \n4.1.\n \nPipe\n \nTD and LSA 228 move\n \nVisual/\n \nUTC 242 open.', 'DW 119 will slow\n \nUTC 242\n \n \n \n \nHandler\n \nstand to DCH:\n \nCCTV\n \nLSA 228 guide funnel\n \ndown above DCH.\n \nanimated in\n \n \n \n \n \nTD 116 and LSA 228\n \n \nclosed.', 'UTC 242 closes\n \nDCH.\n \n \n \n \n \nmove toward DCH.', 'UTC 242 open in\n \nwhen stand is inside\n \nLSA 228\n \n \n \n \n \nLTC 244 closes when\n \n \nDCH.', 'UTC 242.\n \nextend.', 'stand is close to DCH.', 'LTC 244 closes when\n \nLTC 244 is extended\n \nLTC 244 to\n \n \n \n \n \nSet down stand on\n \n \nstand is below LTC\n \nand closed.', 'Closed state.\n \n \n \n \n \nDCH.', '244.', 'UTC 242 to\n \n \n \n \n \nTD links tilted out\n \n \n \n \nClosed state.\n \n \n \n \n \ntoward UTC 242.', 'LSA 228 open.', 'UTC 242 closes when\n \n \n \n \n \nstand is inside guide.', 'LSA 228 opens and\n \n \n \n \n \nretracts.', '5.\n \nDriller\n \nOpen TD elevator 129,\n \nVisual/\n \nUTC 242 closed.', 'Elevator 129 to\n \n \n \n \n \nlower to stick-up:\n \nCCTV\n \n \n \nOpen state.', 'Verify UTC 242 and\n \n \n \n \n \nLTC 244 are closed.', 'Open elevator 129.', 'Tilt links vertical\n \n \n \n \n \n(float).', 'Lower TD 116 to\n \n \n \n \n \nstick-up.\n \n \n \n5.1.', 'Pipe\n \nUTC 242 and LTC 244\n \nVisual/\n \nTD elevator 129\n \nUTC 242 and LTC\n \nUTC 242 and\n \n \n \n \nHandler\n \ntilt stand to vertical\n \nCCTV\n \nopen.', '244 will stop in\n \nLTC 244 Closed.\n \n \n \n \n \nposition:\n \n \n \nvertical position.', 'UTC 242 and\n \n \n \n \n \nUTC 242 and LTC\n \n \n \n \nLCS to DCH.', '244 extend to tilt stand\n \n \n \n \nDoper\n \n \n \n \n \ntoward WC 203.\n \n \n \n \nanimated.', 'Wash and dope pin, if\n \n \n \n \n \npreselected.', '6.\n \nDriller\n \nExtend TD 116 and\n \nVisual\n \nRN 151 retracted.', 'Elevator 129\n \n \n \n \n \nlatch elevator 129:\n \n \n \n \nClosed state.', 'Extend TD 116 to WC\n \n \n \n \nIndicate TD 116\n \n \n \n \n \n203.', 'in WC 203.', 'Latch elevator 129\n \n \n \n \n \n(automatic close on\n \n \n \n \n \nimpact).', '7.\n \nDriller\n \nCheck trip tank\n \nVisual\n \n \nTrip tank gain/loss is\n \nTrip Sheet/\n \n \n \n \n \nvolume, gain/loss:\n \n \n \ndetermined and\n \nVolume control.', 'Trip tank gain/loss.\n \n \n \ndisplayed.', 'Repeat all steps for\n \n \n \n \n \nnext tubular.', 'Continue on step 1.\n \n \n \n7.1.', 'Pipe\n \nTBR 254 and SGA 262\n \nVisual/\n \nUTC 242 and LTC\n \nTBR 254 clamp and\n \nTBR 254 clamp\n \n \n \n \nHandler\n \nmove to THP 207:\n \nCCTV\n \n244 closed on stand.', 'guide and SGA 262\n \nand guide and\n \n \n \n \n \nOpen TBR 254 and\n \n \n \nguide will open.', 'SGA 262 guide\n \n \n \n \n \nSGA 262 in FIB 166.', 'TBR 254 will hoist\n \nto Open states.', 'Move toward THP\n \n \n \nbefore it retracts out of\n \n \n \n \n \n207/ next stand.', 'FIB 166.', 'Continue step 1.1.', 'The zone management system (ZMS) mentioned in the sequences above define a zone for each physical component of the IWCS for which collisions are to be avoided.', 'The zone is a three-dimensional space defined according to a coordinate system common of the IWCS.', 'Each zone pertains to one or more different pieces of equipment, including those structures or components that are stationary as part of the IWCS.', 'The zone is attached to the equipment and travels with the equipment.', 'The size of the zone may change (expand or shrink) depending on the transport speed of the related equipment, or the transport speed of surrounding equipment.', 'Some machinery and equipment is complex enough to warrant using multiple zones within the machinery, and the ZMS maintains information pertaining to the zones of the different subcomponents.', 'The ZMS monitors the zones to prevent collisions.\n \nFIG.', '24\n depicts a component \n1140\n that is a subject of the ZMS.', 'The component \n1140\n can be any component of the IWCS.', 'The component \n1140\n has a zone \n1141\n that at least partially envelops the component \n1140\n.', 'The zone \n1141\n may be larger than the component \n1140\n such that a buffer zone is created between the extremities of the component \n1140\n and the zone \n1141\n to further help avoid collisions between components.', 'A database \n1142\n stores characteristics of the components tracked by the ZMS.', 'The database \n1142\n may store information related to position, size, shape, weight, motion path, tolerance, impact sensitivity, reference point, center of mass \n1143\n, and attachment points.', 'A processing system \n1144\n of the ZMS may execute the logic and calculations.', 'The processing system \n1144\n may be an instance of the processing system \n1000\n shown in \nFIG.', '23\n.', 'The position of the component \n1140\n can be expressed in terms of coordinates relative to one or more coordinate systems.', 'Each coordinate system can be an x-y-z system, a polar coordinate system, or another type of coordinate system.', 'The coordinate system can be centered on any arbitrary point, such as a north-west extreme of the rig floor \n114\n (\nFIG.', '1\n) or the intersection of the well center and the rig floor \n114\n, among other examples.', 'The position of the component \n1140\n is monitored and continuously compared against the position of other relevant components of the IWCS.', 'The position information of a component, in conjunction with the size, and/or shape information of the component, may be used to describe the equipment and its associated zone in the three-dimensional space of the coordinate system in relation to other components of the IWCS.', 'The ZMS system can detect when a collision between two or more components is imminent and, consequently, issue a warning or take action to prevent the collision.', 'The component sizes are stored by the database \n1142\n to help calculate the zones \n1141\n.', 'The database \n1142\n may be at least a portion of an instance of the processing system \n1000\n shown in \nFIG.', '23\n.', 'The database \n1142\n can store the sizes of the components \n1140\n in terms of coordinates at various extremities of the component \n1140\n.', 'If the component \n1140\n has a generally cubic shape, the size can be described by the edges and the orientation of the cube or other coordinate system.', 'If the shape of the component \n1140\n is more complex, more coordinates can be used to define size and shape.', 'The size and/or shape information of each component \n1140\n is used to define the corresponding size and/or shape of the associated zones \n1141\n.', 'The zone \n1141\n may fully envelop the physical component \n1140\n, or may encompass just a part of the physical component \n1140\n that may collide with other components \n1140\n.', 'The size of the zone \n1141\n may also expand in a direction aligned with movement of that component \n1140\n, and/or in a direction of another approaching component \n1140\n.', 'The extent of this expansion may depend on the speed of the moving component(s) \n1140\n.', 'The database \n1142\n also tracks the weight of the components \n1140\n, which the ZMS may use to determine how much force is required to move or stop motion of a component \n1140\n.', 'The weight of a component \n1140\n may be known, such as when entered during sequence set-up, while in other cases the IWCS may comprise sensors configured to determine the weight of the component \n1140\n.', 'For example, if the component \n1140\n is the top drive \n116\n connected to the drill string \n120\n, the weight of the component \n1140\n varies depending on the length and other parameters of the drill string \n120\n.', 'The sensors may perform weight measurements to determine weight as needed.', 'The positions of the various components \n1140\n of the IWCS varies from time to time.', 'The motion path of each component \n1140\n can also be stored by the database \n1142\n.', 'The motion path of a component \n1140\n could be a complete path, such as when a component \n1140\n could travel from one position to another position.', 'Alternatively, the motion path of the component \n1140\n could be just the direction in which the component \n1140\n may travel, with no defined end point.', 'The database \n1142\n can store a routine path of motion for the components \n1140\n.', 'For example, an iron roughneck \n151\n has a movement path between retracted and expanded positions.', 'The trajectory of the path can be known ahead of time.', 'The ZMS processing system \n1144\n can be informed of a proposed motion path for a given component \n1140\n, and can calculate whether the component \n1140\n can make the proposed movement at the proposed time without intersecting with a zone of another component of the IWCS.', 'If so, the ZMS processing system \n1144\n approves the movement.', 'Alternatively, when the component \n1140\n is commanded to move in a particular direction, the zone \n1141\n associated with the component \n1140\n may be expanded in the direction of the intended movement.', 'The extent of the zone \n1141\n expansion may depend on the speed of the associated component \n1140\n.', 'With the expanded zone \n1141\n for a component \n1140\n, the ZMS processing system \n1144\n, may calculate whether the expanded zone \n1141\n could intersect with a zone \n1141\n of another component \n1140\n of the IWCS.', 'If not, the ZMS processing system \n1144\n approves the movement.', 'In addition, when a component \n1140\n is commanded to move in a particular direction, the zones \n1141\n associated with surrounding components \n1140\n that may come in contact with the moving component \n1140\n may be expanded in the direction of the incoming component \n1140\n.', 'The extent of the zone \n1141\n expansion may depend on the speed of the incoming component \n1140\n.', 'The ZMS processing system \n1144\n may perform similar calculations to evaluate whether a zone \n1141\n intersection may occur and react accordingly.', 'The movement of the components \n1140\n can be under the direction and control of the Construction Program, so actions controlled by the Construction Program may be subject to the approval of the ZMS processing system \n1144\n to prevent collisions between components \n1140\n.', 'The movement of one or more portable components may be unscheduled.', 'A portable component is an object that is not part of the IWCS equipment, but may be present during the operation.', 'For example, a human operator \n195\n on the rig floor \n114\n may be a portable object.', 'The ZMS processing system \n1144\n is equipped to detect and monitor unscheduled movement of the portable components.', 'For example, the various cameras, sensors, and other measuring equipment described above can be used to identify the portable component and detect its movement.', 'The ZMS processing system \n1144\n can establish a zone associated with the portable component, evaluate its risk for colliding with surrounding equipment, and issue a warning and/or take action to prevent a collision.', 'The ZMS processing system \n1144\n may move other components \n1140\n out of the way, or may stop the movement of other components \n1140\n, to avoid a collision.', 'The ZMS processing system \n1144\n may also calculate an expected damage for a given collision, and may include logic to permit the ZMS processing system \n1144\n to determine a course of action under a given set of circumstances.', 'For example, if the top drive \n116\n is moving down toward the rig floor \n114\n when the ZMS processing system \n1144\n detects an operator \n195\n walking toward well center, the ZMS processing system \n1144\n may immediately establish a zone \n1141\n around the operator \n195\n and evaluate whether this zone \n1141\n would intersect with the zone \n1141\n associated with the top drive \n116\n.', 'Depending on safety policy established for the operation, the ZMS processing system \n1144\n may take a number of measures to avoid collision between the top drive \n116\n and the operator \n195\n, such as triggering an alarm, slowing movement of the top drive \n116\n, and/or emergency stop of top drive \n116\n, among other examples.', 'The database \n1142\n can store information relating to a tolerance for a given component \n1140\n.', 'The tolerance can be defined as a distance from the edge of the physical structure of the component \n1140\n and the corresponding edge of the defined zone \n1141\n.', 'The nature of the component \n1140\n and the environment in which it is being used can factor into determining the tolerance.', 'Generally, the faster the speed of the component \n1140\n, the larger the tolerance in the direction of the movement.', 'Alternatively, the faster the speed of the incoming component \n1140\n, the larger the tolerance in the direction of the incoming component \n1140\n.', 'It is also possible that the more sensitive the component \n1140\n, the larger the tolerance can be.', 'The constraints of the environment may also determine what the tolerance is.', 'For example, if the component \n1140\n is to be installed into predefined space where it is next to another component, then the tolerance can be adjusted accordingly so as not to trigger an alarm or corrective action when installed in the desired location.', 'The tolerance may also be altered during movement, such that when a given component \n1140\n is stationary, the tolerance can be smaller, and when the component \n1140\n is moving, the tolerance (and, thus, the zone \n1141\n) can be temporarily enlarged.', 'Various components are made of different materials and some are more delicate than others.', "The nature of the component's resistance to collision can be factored into the calculation of the zone \n1141\n.", 'The notion of impact sensitivity may be more than physical impact, and can include chemical, thermal, vibrational, and electromagnetic contact.', 'Thus, the zone \n1141\n of a component \n1140\n can be enlarged or reduced according to the collision, chemical, thermal, vibrational, electromagnetic, and other sensitivity of the component \n1140\n.', 'The components \n1140\n each generally have a physical body, and to properly address the location of the component \n1140\n and its proximity to other components, the component \n1140\n can be given a reference point and the dimensions of the component \n1140\n can be defined with reference to the reference point.', 'The reference point can be arbitrarily chosen, or it can have some importance.', 'For example, the reference point can coincide with the center of mass \n1143\n, an important corner, an edge, or another significant point on the component \n1140\n.', 'If a component \n1140\n is routinely rotated, the reference point and geometry of the component \n1140\n can be updated as it is rotated during service.', 'The zone \n1141\n pertaining to the component can also be updated accordingly.', 'Some components \n1140\n have are attachment points, such as hooks, rails, skids, eyelets, bolt patterns, or other physical connection points.', 'This information can also be stored in the database \n1142\n to permit handling of the components.', 'In the event of an impending collision, information on where an attachment point is located may prove useful and can determine what course of action is taken to prevent or mitigate a collision.', 'Another type of attachment point are ports, such as valves, electrical outlets/ports, etc.', 'Knowing the location and existence of these attachment points and ports can also prove useful and can determine the actions taken by the systems and methods of the present disclosure.', 'Different priorities may be associated with different components \n1140\n.', 'Each component \n1140\n can be given a priority relative to other components, and if there are two competing movement proposals, the higher priority can be given the green light and the lesser priority components will have to wait or find another movement path.', 'The higher priority component can be referred to as the commanding component and the lesser component can be referred to as the lesser component or the subservient component.', 'A rig control system according to the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may comprise a communication network (e.g., ring network \n900\n from \nFIG. \n22\n), a control workstation connected directly to the communication network (e.g., control workstation(s) \n850\n and/or \n852\n from \nFIG. \n22\n), a plurality of control devices that are each connected directly to the communication network, at least some (maybe each) of which control devices may comprise or be a computer (PC or IPC) and/or a programmable logic controller (PLC) (e.g., PLCs \n901\n, \n911\n, \n921\n, \n931\n, \n941\n, \n951\n, \n961\n, \n971\n, \n981\n, \n991\n from \nFIG. \n22\n), a plurality of local control networks (e.g., subsystem network rings \n909\n, \n919\n, \n929\n, \n939\n, \n949\n, \n959\n, \n969\n, \n979\n, \n989\n, \n999\n from \nFIG.', '22\n) that are each connected to the communication network via a corresponding one of the plurality of control devices, and a plurality of local control devices, at least some (and maybe each) of which may comprise or be a computer (PC or IPC) and/or a programmable logic controller (PLC) (e.g., devices \n902\n-\n905\n, \n912\n-\n915\n, \n922\n-\n925\n, \n932\n-\n935\n, \n942\n-\n945\n, \n952\n-\n955\n, \n962\n-\n965\n, \n972\n-\n975\n, \n982\n-\n984\n, \n992\n-\n995\n from \nFIG.', '22\n) and each of which is connected (e.g., directly) to a corresponding one of the plurality of local control networks (in which case each is connected indirectly to the larger communication network).', 'The communication network may comprise or be a single ring, star, or daisy-chain network, and/or may be fiberoptic.', 'Each of the plurality of control devices may perform, be caused to perform, sense, measure, monitor, log, and/or the like an action (e.g., a mechanical, software, or other action) of a surface or downhole component (or group thereof), subsystem (or group thereof), and/or system (or group thereof).', 'By virtue of their connection through the communication network, each of the plurality of control devices may directly or indirectly communicate with each other of the plurality of control devices.', 'In an advantageous embodiment, the communication network is configured such that the plurality of control devices (and/or the plurality of local control devices) may (and, in some embodiments, do) perform substantially all control logic involved in direct operation of an array of individual tools/equipment and/or individual subsystems controlled by the rig control system, whereas the control workstations, e.g., via user-input data comprising, consisting essentially of, or being operating parameters and/or multi-tool/multi-subsystem tasks, substantially exchange data comprising, being, and/or derived from the user-input data with the plurality of control devices (and/or, through the plurality of local control networks, with the plurality of local control devices, and thus ultimately with various tools/equipment/subsystems controlled by the rig control system.', 'In this or another embodiment, or as a stand-alone embodiment, an analysis-while-drilling (AWD) control system according to the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may be operable to display and/or utilize a plurality of drilling-related parameters that can be and/or have been input by a user and/or that can be and/or have been calculated by one or more algorithms (e.g., based on parameters that can be or have been input by a user).', 'The AWD control system may utilize as input data drilling-related parameters involving well configuration, drill string (including BHA) configuration, drilling-related sensor data/parameters (e.g., mud pit level sensors, standpipe pressure sensors, mud flow sensors, and the like), and drilling equipment data/parameters (e.g., directly from the corresponding equipment, such as drill string revolutions per minute (RPM), make-up torque, mud pump SPM, and the like).', 'The AWD control system may provide output data that can be delivered to and/or used by workstation(s) display(s) (e.g., including the AWD display), a historical logging system (e.g., which may be comprised within and/or accessible via a remote computing resource environment such as environment \n306\n from \nFIGS. \n3\n and \n4\n), a mud logging system (e.g., which may be comprised within and/or accessible via a remote computing resource environment such as environment \n306\n from \nFIGS. \n3\n and \n4\n), etc.', 'The AWD control system output data may comprise: drilling operation warnings and alarms, a kick calculator and kill sheet; sensor data and sensor data calculations for storage in a historical trending/logging system, dynamic tracking of data/parameters related to/indicative of a predetermined set of operating parameters, parameters and/or other information indicative of well configuration, and/or parameters and/or other information indicative of drill string (e.g., including BHA) configuration.', 'The predetermined set of operating parameters may include, but may not necessarily be limited to: well depth/shape; bit depth; stands in hole; sectioned mud volumes; drill string volume, displacement, and weight; mud tank volumes, including active tank selection and loss/gain calculation information; trip tank difference volume; trip tank accumulated volume; mud pump total stroke counters (individual stroke count is tracked by/on behalf of each mud pump); mud pump SPM total; setting of mud pump liner capacities and efficiencies; mud flow into hole, individual and total; annular mud velocity per section; mud volume per section; total strokes per section; strokes to go per section; total minutes per section; minutes to go per section; mud return flow; bit runtime and revolutions; WOB; ROP; hook load; and standpipe pressure; inter alia.', 'The AWD system is operable for delivering high-quality calculations for real-time monitoring and alarming of complex drilling and tripping parameters.', 'Input from following sources may the basis for AWD calculations: well and drill string configuration; and drilling parameter sensors, as mud pit level sensors, standpipe pressure sensors, and mud flow sensors; directly from the drilling equipment, such as drill string RPM, make-up torque, and mud pump SPM.', 'The AWD system may output results to workstation displays (e.g., an AWD display screen viewable by the operator on a control workstation display), a historical logging system, and a mud logger system.', 'The AWD system may have direct access to all necessary sensor signals, and may permit further understanding and comprehension by the operator.', 'The AWD system may provide determination and/or confirmation of: well and drill string configuration; dynamic tracking of well and bit depth; stands in well; dynamic calculation of sectioned mud volumes, drill string volume, displacements, and weight; mud tank volumes, including active tank selection and loss/gain calculation; trip tank difference volume; trip tank accumulated volume; mud pump total stroke counters (individual count may be performed by the individual mud pumps); total mud pump strokes per minute; settings of mud pump liner capacities and efficiencies; mud flow into hole, individual and total; dynamic calculation of annular mud velocity per section; dynamic calculation of mud volume per section; dynamic calculation of total strokes per section; dynamic calculation of strokes to go per section; dynamic calculation of total minutes per section; dynamic calculation of minutes to go per section; mud return flow; bit runtime and revolutions; WOB; ROP; hookload; standpipe pressure; casing pressure; cement pressure; kick calculator and kill sheet (e.g., following the “Drillers Method”)′ sensors and calculations for storage in historical trending system; and operation warnings and alarms.', 'The AWD system may contain specific WITS (Well Site Information Transfer Standard) computations and triggers used to populate serial communication utilizing the WITS0 protocol.', 'The AWD system may calculate data for the WITS records “RECORD1—General Time-based” and “RECORD11—Mud Tank Volumes—Time-based.”', 'The WITS record “RECORD19—Hole and Drill String” may be used for configuration.', 'The AWD system may calculate mud active volume from the levels measured by the mud pit level instrumentation.', 'The level sensors may be wired to the AWD system, or the AWD system may receive the level sensor data from the drilling fluid control system.', 'Active tanks may be selected by the operator to be included as a part of the active volume.', 'Any tank combination is possible for active volume.', 'Once selected, the tank is automatically added to the active volume.', 'All calculations involving active volume will be updated with the new value.', 'The AWD screen may indicate the status of which tanks contribute into the mud active volume determination, which may always be visible to the operator.', 'The AWD system calculates data for the mud balance volume indicator showing loss/gain volume with an arrow for increasing/decreasing trend.', 'System loss/gain is calculated as variation in active volume from a reset value.', 'The AWD system calculates bit and well depth automatically by use of hoist position, hook load, and slips status.', 'Each time the bit moves in the well, or the well is being lengthened, the well and bit depths are automatically calculated by the AWD system.', 'The update is dependent on a certain weight of the drill string, i.e., the ability to measure hook load.', 'In cases when the weight of the drill string is too low to obtain a reliable signal, it is possible to manually decide when the bit depth should be updated.', 'The bit and well depth calculator also includes an automatic Stands', 'In Hole counter based on an input average stand length.', 'The AWD system may have two options for depth calculations: “slips” for depth calculation active when the slips are not set; and “hookload” for depth calculation when load is in the elevator.', 'The AWD system may include individual SPM and stroke counters for each mud pump.', 'In addition, there may be multiple (e.g., four) independent total strokes counters and total SPM for the active mud pumps.', 'The operator may select which pumps to count into the active mud pumps for total counters.', 'The AWD system may include monitoring of the mud flow pumped into the drill string, as well as mud return flow.', 'Calculation of flow in depends on configuration of liner capacity and efficiency factor set for the individual mud pumps.', 'By use of these data and SPM, the AWD system may calculate the mud flow in per pump, in addition to total flow pumped into the well.', 'The mud return flow may be read directly from a mud return sensor, which an operator may choose via a sensor-select pop-up menu.', 'The ROP may be calculated as a result of well or bit depth increase over time.', 'The operator may select whether the ROP calculation will be done from bit depth or well depth.', 'The WOB may be calculated as variation in hook load from a reset value.', 'The AWD system may include counters for bit revolutions and runtime.', 'These counters may depend on top drive RPM and calculated mud flow in.', 'Updating the counters may be done when the bit is on bottom.', 'The AWD system may display a well configuration used to configure well and drill string parameters, as well as to give a summarized view of the current configurations being used.', 'The well design entered in the AWD system includes number of well sections, as well as well diameter and planned length for each section.', 'The choke and kill line design entered in the AWD system may include choke line ID, choke line joint ID, choke line joint fraction, choke line length, kill line ID, kill line joint ID, kill line joint fraction, and kill line length.', 'The drill string design entered in the AWD system may include dimensions and length of each drill string section, including number of drill string sections, planned length, drill string capacity, drill string steel displacement, drill string closed displacement, average length of tubular tool joint, average length of stand, and number of tool joints per stand, among other examples.', 'The kick calculator may be used if the well kicks and the well must be shut in and circulated out to regain control over the well.', 'The kick calculator does not start any equipment, sequences, or processes, and may be used at any time or point of the well.', 'Inputs for the kick calculator may include measured depth, true vertical depth, measured shoe depth (e.g., second-lowest well section), vertical shoe depth, original mud weight, leak off test mud weight, leak off test pressure, shut in casing pressure, shut in drill pipe pressure, kick gain volume, kill pump selection, kill pump capacity (e.g., calculated from mud pumps configuration), kill pump speed, slow circulation rate pressure, safety margin, and selected choke/kill line to use, among other examples.', 'The kick calculator may also use previously entered and/or measured parameters as string and well properties, riser dimensions, and kill and choke line properties.', 'The volumes, shoe, and pump data may be gathered from the mud pumps and well configuration settings.', 'The kick calculator may output initial circulation pressure, interim circulation pressure, final circulation pressure, kill mud weight, maximum mud weight, pressure drop per 100 strokes, gradient of influx, height of influx, surface to bit strokes and minutes, bit to shoe strokes and minutes, shoe to bop strokes and minutes, bop to choke strokes and minutes, and total circulation strokes and minutes, among other examples.', 'The AWD system may determine the trip tank difference via a comparison between expected drill string displacement tripped into the well and actual volume measured in the trip tank.', 'Drill string displacement may depend on the drill string configuration and bit depth.', 'The AWD system may determine the trip tank accumulated volume as the total volume of mud during tripping in or out.', 'The accumulator may be frozen when filling or draining to make it possible to fill or empty the trip tank without reflecting the accumulated value.', 'The AWD display screen may dynamically show the configured and drilled well and drill string graphically.', 'The AWD display screen may also dynamically show mud volumes, strokes, and velocity for the different well sections.', 'The AWD system may also track the mud front depth, which may be displayed textually (e.g., numerically) and graphically on the well animation.', 'The AWD display screen may contain a graphical display of the well configuration and well section depths, a graphical display of the shoe, an animation of drilled well relative to well configuration, an animation of the drill string in the well, the mud front tracking (e.g., mud front depth value and graphical display), annular velocity per well section, open hole volume, and dynamic determination of total strokes and minutes, strokes and minutes to go, and volume for surface to bit, bit to shoe, bit to BOP, and bit to surface, well circulation, and full circulation, among other examples.', 'The AWS display screen may also display other AWD parameters already determined by the AWD System, such as drill string displacement—open end, drill string displacement—closed end, drill string weight, stands in the well, active volume, mud flow in, bit revolutions, and bit runtime, among other examples.', 'The AWD display screen may also summarize the configured well section lengths, and may display the depth of each section in addition to graphically indicating the shoe depth.', 'If the actual well depth exceeds the configured well depth, the length of the deepest well section may automatically be updated so that volume, time, and stroke calculations are correct.', 'Well and drill string animation may also be updated to reflect exceeded well depth.', 'When a well configuration is input to the AWD system, the well may be filled with a first color, and as drilling progresses, the well animation may correspondingly be filled with a second color according to the calculated well depth.', 'The drill string may be graphically displayed with the second color or a third color in the configured well.', 'Depth of the drill string will indicate the bit depth.', 'The mud front tracking position may be calculated in relation to the mud pump total strokes counter and the drill string and well configurations.', 'It may be possible to track the mud front from the surface or the bit.', 'When the operator selects to start tracking the mud front from the surface, and a selected total strokes counter is set to zero, a graphical symbol may indicate the mud front position moving from the surface towards the bit inside the drill string while mud is pumped into the well.', 'When the stroke counter exceeds the number of strokes for surface to bit, another graphical symbol may indicate the mud front position in the annular volume going from bottom to surface.', 'When the mud front indication reaches the surface, it may stay on the surface until the selected total stroke counter is reset.', 'When the operator selects to start tracking the mud front from the bit (or bottom), and the selected total strokes counter is set to zero, a graphical symbol may indicate the mud front position in the annular volume starting from the bit and moving towards the surface.', 'When the mud front indication reaches the surface, it may stay on the surface until the selected total stroke counter is reset.', 'In addition to the graphical display of the mud front depth, there may also be a numerical display showing the depth.', 'For example, the value may be a positive value if the mud front is moving towards the bit inside the drill string or towards surface in the annular volume.', 'The AWD system may calculate and display annular velocity with a numerical display for each of the well sections.', 'If the drill string has several outer diameters inside the same well sections, the velocity calculated may be the average in the specific well section.', 'The AWD system may calculate the open hole volume according to the well configuration at current well depth.', 'The AWD system may dynamically calculate volume, total strokes, total minutes and strokes, and minutes to go for one or more of: surface to bit (drill string volume); bit to shoe (annular volume from bit to shoe); bit to surface (total annular volume); well circulation (drill string+annular volume); and full circulation (drill string+annular volume+active volume).', 'The strokes and minutes to go may be calculated from the last reset of the selected total strokes counter.', 'If the operator selected to start tracking from surface, strokes and minutes to go may be calculated starting from counting strokes from surface.', 'If the operator selected to start tracking from bottom, strokes and minutes to go may be calculated starting from bit position.', 'The surface to bit strokes and time to go may be set to zero when the operator selects to start tracking from bottom.', 'Volume calculations may be related to the well and drill string configurations and the calculated bit depth.', 'Strokes calculations may depend on calculated volumes and active mud pump capacity settings.', 'Minutes to go calculations may depend on calculated volumes, active mud pump capacity settings, and mud pump total SPM.', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may be operable to monitor and at least partially (e.g., completely) control drilling operations of a drilling rig and one or more of the following modules: drill pipe tripping in (with and/or without drill collar stand); drill pipe tripping out (with and/or without drill collar stand); drill pipe connecting; drill pipe stand-building (offline); drill pipe laydown standing (offline); casing stand-building; casing tripping in; stand breakdown; running casing from catwalk; picking up singles from catwalk; laying down singles from well center to catwalk; back-reaming; wet tripping; normal drilling shut-down; and emergency drilling shut-down (based on alarm conditions).', 'One such example module involves running 13⅜″ casing from catwalk using top drive and casing running tool.', 'This module sequence may start with top drive in lower position, casing running tool engaged, closed slips (e.g., approximately 1.5 meters stick up), catwalk machine feeding table loaded with (cleaned) tubulars, catwalk machine ramp loaded with casing (e.g., on its way up), tubular delivery arm parked in/near top of mast, and lower stabilizing arm ready.', 'The module sequence may then include: (i) releasing casing running tool from stick up and hoisting top drive to pick up position; (ii) latching elevator; (iii) top drive/lower stabilizing arm hoisting the casing to well center and catwalk machine being moved to loading position; (iv) stabbing the casing; (v) loading another (e.g., the next) casing on catwalk machine ramp; (vi) running catwalk to drill floor; (vii) engaging casing running tool and making-up casing connection; (viii) opening backup tong and retracting tong handling trolley; (ix) lowering casing string and opening elevator; (x) tilting out elevator link(s) and setting slips; and (xi) optionally repeating some or all of these steps for additional (e.g., the next) casing(s), as desired.', 'A drilling system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may comprise at least partially (e.g., completely) automated control of equipment comprising, consisting essentially of, or consisting of each of: drawworks; top drive; iron roughneck; mud bucket; cathead(s); mousehole; mud system comprising mud pumps; catwalk; fingerboard; vertical pipe handler; CCTV system; riser tension system; top-mounted compensator; and optionally bottom hole assembly (BHA).', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may be operable for controlling drilling operations in which automated tripping in and/or automated tripping out modules may be advantageously more efficient than manual tripping in and/or tripping out modules for an average human working crew.', 'The control system may effectuate one, some, or all of the following: an automated average tripping in and/or tripping out speed [in stands/hour] that is at least 5% (e.g., at least 6%, at least 7%, at least 8%, at least 9%, or at least 10%) better/more than an average tripping in and/or tripping out speed of an average human working crew; an automated standard deviation from average tripping in and/or tripping out speed that is at least 50% (e.g., at least 55%, at least 60%, at least 65%, at least 70%, at least 75%, or at least 80%) better/lower than a standard deviation from an average tripping in and/or tripping out speed of an average human working crew; an automated average tripping in and/or tripping out slip-to-slip connection time', '[in seconds] that is at least 4% (e.g., at least 5%, at least 6%, or at least 7%) better/lower than an average tripping in and/or tripping out slip-to-slip connection time of an average human working crew; and an automated standard deviation from average tripping in and/or tripping out slip-to-slip connection time that is at least 50% (e.g., at least 55%, at least 60%, at least 65%, at least 70%, at least 75%, or at least 80%) better/lower than a standard deviation from an average tripping in and/or tripping out slip-to-slip connection time of an average human working crew.', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may be operable for controlling drilling operations in which collisions are prevented between: (a) drawworks and one or more of iron roughneck, tong-handling trolley, tong-handling arm, catwalk, tubular delivery arm, lower stabilizing arm, and upper tubular constraint; (b) top drive and one or more of iron roughneck, tong-handling trolley, tong-handling arm, catwalk, tubular delivery arm, lower stabilizing arm, and upper tubular constraint; (c) iron roughneck and one or more of drawworks, top drive, catwalk, tubular delivery arm, lower stabilizing arm, intermediate tubular constraint, rotary table, power slips, well center connection, and mousehole connection; (d) tong-handling trolley and one or more of drawworks, top drive, catwalk, tubular delivery arm, lower stabilizing arm, rotary table, power slips, and well center connection; (e) tong-handling arm and one or more of drawworks, top drive, catwalk, tubular delivery arm, lower stabilizing arm, intermediate tubular constraint, rotary table, power slips, well center connection, and mousehole connection; (f) catwalk and one or more of drawworks, top drive, iron roughneck, tong-handling trolley, tong-handling arm, tubular delivery arm, lower stabilizing arm, pipes around stand hand-off position, and pipes by mousehole; (g) tubular delivery arm and one or more of drawworks, top drive, iron roughneck, tong-handling trolley, tong-handling arm, catwalk, lower stabilizing arm, transfer bridge rackers, upper tubular constraint, intermediate tubular constraint, lower tubular constraint, setback guide arm(s), stand hand-off position, rotary table, and power slips; (h) lower stabilizing arm and one or more of drawworks, top drive, iron roughneck, tong-handling trolley, tong-handling arm, catwalk, tubular delivery arm, and intermediate tubular constraint; (i) transfer bridge rackers and one or more of tubular delivery arm, upper tubular constraint, lower tubular constraint, setback guide arm(s), stand hand-off position, and fingerboard; (j) upper tubular constraint and one or more of drawworks, top drive, tubular delivery arm, transfer bridge rackers, lower tubular constraint, and setback guide arm(s); (k) intermediate tubular constraint and one or more of iron roughneck, tong-handling arm, tubular delivery arm, lower stabilizing arm, and mousehole connection; (l) setback guide arm(s) and one or more of tubular delivery arm, lower stabilizing arm, transfer bridge rackers, upper tubular constraint, and lower tubular constraint; (m) setback guide arms; (n) fingerboard and transfer bridge rackers; (o) lower tubular constraint and one or more of tubular delivery arm, lower stabilizing arm, transfer bridge rackers, upper stabilizing arm, and setback guide arm(s); (p) stand hand-off position and one or both of tubular delivery arm and transfer bridge rackers; and/or (q) rotary table/power slips and one or more of drawworks, top drive, iron roughneck, tong-handling trolley, tong-handling arm, tubular delivery alarm, lower stabilizing arm, and well center connection.', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may be operable for controlling drilling operations in which a level of automation for various drilling operations can be selected by: generating a control screen facilitating selection of automation level; and facilitating selection of full (i.e., substantially complete) automation, semi-automation (e.g., confirmation by driller/operator to start a specific operational sequence, automating a first portion of a larger operational sequence such as waiting for a driller/operator to authorize completion and/or a second portion of the larger operational sequence, or the like), or manual control (e.g., via a joystick).', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may be operable for controlling drilling operations and may comprise a customizable display screen on which a control screen is generated and which control screen may be operable to facilitate selection of scale and/or limits for indicator graphs (e.g., pie chart(s), linear bar graph(s), spider graph(s), and/or the like, as well as combinations thereof) that may graphically represent one or more aspects of the drilling operations.', 'The selection of scale and/or limits may include, but are not necessarily limited to, minimum and maximum graph values; warning value limits; and graph scale.', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may be operable for controlling drilling operations and may comprise a display of software objects (e.g., symbols, icons, buttons, and/or the like) that: may be displayed on a monitor or touchscreen; may be indicative of equipment/tool/device status via changing color, localized background color, adjacent or localized background symbol (e.g., check or X), flashing color, filled/unfilled object, and/or the like; may show operational status (e.g., high value, open, closed, running, idle, error, and/or the like); may show communication status (e.g., feedback error, communication error, and/or the like); may show control status (e.g., auto, manual, local, and/or the like); and may be displayed in association with displayed numerical values; inter alia.', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may comprise an AWD display screen showing one, some, or all of the following information: (a) graphic display of well configuration and hole section depths; (b) graphic display of shoe; (c) animation of planned vs. actual well; (d) animation of drill string in well; (e) value and graphic display of mud front tracking/depth; (f) annular velocity per section; (g) open hole volume; (h) dynamic calculation of total strokes and minutes, strokes and minutes to go, and volume for at least the following: (i) Surface To Bit; (ii) Bit To Shoe; (iii) Bit To BOP; (iv) Bit To Surface; (v)', 'Well Circulation; (vi) Full Circulation; (j) drill string displacement, open end and closed end; (k) drill string weight; (l) stands in hole; (m) active volume; (n) mud flow in; (o) bit revolutions; and (p) bit runtime.', 'A control system according to one or more aspects of the present disclosure (which may be similar or identical to system \n800\n shown in \nFIG.', '22\n) may comprise an alarm system that can assist equipment operators/resource producers to operate equipment (e.g., drilling equipment) in an efficient and safe manner The alarm system may be operable to: draw operator attention to alarms by use of colors, symbols, flashing, sounds, and other notations with distinct meaning; present descriptive and easy to understand alarm texts; use alarm priority with distinct meaning; logically group alarms; and keep an alarm rate as low as possible.', 'The alarm system may additionally or alternatively utilize screen objects/symbols that are indicative of equipment or device and that may show status via changing color, localized background color, adjacent or localized background symbol, flashing color, filled or unfilled object, and/or the like.', 'The alarm system may additionally or alternatively be configured: such that the driller/operator responds to all alarms; for intuitive navigation and alarm acknowledgment; to automatically log each alarm and alarm state change; and for high system availability and robustness.', 'A method of at least partially automating drilling operations according to one or more aspects of the present disclosure, which may be employed using one, some, or all of the (control) systems described herein, can comprise utilizing data indicative of operation or capability of a first piece of drilling equipment as an input parameter for controlling operation of a second piece of drilling equipment, wherein impact of the data indicative of the operation/capability of the first piece of drilling equipment is either not intuitively linked to or is counterintuitive to operation/capability of the second piece of drilling equipment.', 'For example, an output parameter involving a piece of drilling equipment A may be used as an input parameter for operation of a piece of drilling equipment B, and an output parameter (e.g., similar to or different from the input parameter) involving the piece of drilling equipment B may be used as an input parameter for operation of a piece of drilling equipment C.', 'In this example, one or more effects of operation/capability of a parameter involving the piece of equipment A is either not intuitively linked to or is counterintuitive in its applicability to the operation/capability of the piece of equipment C.', 'In this example, the “piece of drilling equipment B” may represent a single piece of drilling equipment or a series of pieces of drilling equipment, an output parameter of each of which serves as an input parameter for the next piece of drilling equipment throughout the series (notably, it may be, although it need not be, the same output and/or input parameter throughout the series of drilling equipment).', 'In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces an apparatus comprising an integrated well construction system (IWCS) operable for constructing a well via integrated control of a plurality of integrated control devices that collectively control a plurality of integrated subsystems of the IWCS, wherein the IWCS comprises: an IWCS communication network; the integrated control devices, each directly connected with the IWCS communication network; the integrated subsystems; and a control workstation directly connected with the IWCS communication network and operable to control each of the integrated control devices to thereby control the integrated subsystems.', 'Each integrated control device may control a corresponding one of the integrated subsystems.', 'The IWCS communication network may be a single, fiberoptic, ring-topology network.', 'The integrated subsystems may include at least: a rig control subsystem comprising a drawworks, a top drive, an iron roughneck, automated slips, and automated pipe handling equipment; a fluid circulation subsystem comprising a drilling fluid pump and drilling fluid reconditioning equipment; a managed pressure drilling control subsystem; a choke pressure control subsystem; a well pressure control subsystem; and a closed-circuit television subsystem.', 'Each subsystem may comprise: a subsystem network directly connected with the integrated control device of that subsystem; and a plurality of subsystem components each directly connected with the subsystem network.', 'The subsystem components may each control, perform, sense, measure, and/or monitor an aspect of well construction performed in association with the subsystem comprising that subsystem component.', 'The control workstation may comprise a processor and a memory storing a construction program that, when executed by the processor, controls each integrated control device at least partially in response to data received from at least one other one of the integrated control devices.', 'The control workstation may comprise a processor and a memory storing a construction program that, when executed by the processor, controls each integrated control device during each of a plurality of predetermined operational sequences.', 'The plurality of predetermined operational sequences may comprise: picking up single tubulars; making drilling connections; building tubular stands; tripping-in drill collar stands; tripping-out drill collar stands; tripping-out wet; backreaming; moving single tubulars from a well center to a catwalk using a top drive; moving tubular stands from the well center to the catwalk; moving casing from the catwalk to the well center using a casing tong; moving casing from the catwalk to the well center using a tubular delivery arm and a casing running tool; moving large diameter casing from the catwalk to the well center using the top drive and the casing running tool; building casing stands; and tripping-in casing stands without using the casing running tool.', 'The construction program, when executed by the processor, may control the top drive, a drawworks, automated slips, a top drive elevator, an iron roughneck, a drilling fluid pumping system, the catwalk, an automated racker, an automated fingerboard, and the tubular delivery arm, via control of the integrated control devices, during performance of the predetermined operational sequences.', 'The construction program may be configurable by a human operator to permit the operator to select human interaction levels during performance of the predetermined operational sequences.', 'The construction program may be configurable by a human operator to permit the operator to select levels of automation of the IWCS during performance of the predetermined operational sequences.', 'The construction program may be configurable by a human operator to permit the operator to select which machines of the IWCS will be controlled by the construction program during performance of each predetermined operational sequence.', 'The construction program may be configurable by human operators to permit the operators to select which machines of the IWCS will be controlled by the construction program, and to select which machines of the IWCS will be supervised by which operator, during performance of each predetermined operational sequence.', 'The construction program may be configurable by human operators to permit the operators to select which steps of each predetermined operational sequence will be performed and/or confirmed manually, and by which operator.', 'The IWCS may be operable for constructing a well without operation of other components not controlled by, monitored by, or otherwise in communication with any of the integrated control devices.', 'The IWCS may be operable for constructing a well without operation of other components not controlled by any of the integrated control devices.', 'The present disclosure also introduces an apparatus comprising a control workstation directly connected with a communication network and operable to control each of a plurality of integrated control devices each directly connected with the communication network, wherein each integrated control device controls a corresponding component of an integrated well construction system, whereby control of the integrated control devices, via operations of the control workstation, controls the integrated well construction system.', 'The integrated well construction system may be operable, via operations of the control workstation, for constructing a well exclusive of any component not controlled by any of the integrated control devices.', 'The present disclosure also introduces a computer program product comprising a tangible, computer-readable, non-transitory medium having instructions stored thereon for: automatically controlling a plurality of integrated control devices that control integrated subsystems of an integrated well construction system (IWCS) to perform combinations of a plurality of predetermined operational sequences for constructing a well; receiving, via operation of a control workstation by a human operator, a selection of one of the operational sequences to be performed by the IWCS; receiving, via operation of the control workstation by the human operator, settings for first machines of the IWCS to be operated during the selected operational sequence; and in response to receiving a single commencement input via operation of the control workstation by the human operator, automatically starting and controlling the first machines and second machines of the IWCS to perform the selected operational sequence using the received settings.', 'The automatic start and control of the first and second machines may perform the selected operational sequence without further human action.', 'The present disclosure also introduces a method comprising operating an integrated well construction system (IWCS) comprising a fiberoptic ring network, wherein the fiberoptic ring network comprises a plurality of nodes comprising: programmable logic controllers (PLCs) of individual pieces of machinery forming the IWCS; video feed; drilling operator control; high-level supervisory control; and combinations thereof.', 'The IWCS machinery PLCs may comprise: a drilling fluid pumping system PLC; a top drive PLC; a drawworks PLC; an automated slips PLC; an iron roughneck PLC; a catwalk PLC; an automated racker PLC; an automated fingerboard PLC; and a tubular delivery arm PLC.', 'The fiberoptic ring network may exchange data between the PLCs for coordinated control of the machinery.', 'The fiberoptic ring network may exchange data between one or more of the PLCs and the drilling operator for manual or semi-automatic control of the IWCS.', 'The fiberoptic ring network may exchange data between one or more of the PLCs and a supervisory controller for automatic and optimized control of the IWCS.', 'The present disclosure also introduces an apparatus comprising: a communication network; a plurality of integrated control devices each directly connected with the communication network, wherein each integrated control device controls a corresponding component of an integrated well construction system, and wherein the integrated well construction system is operable for constructing a well without other components not controlled by any of the integrated control devices; and a control workstation directly connected with the communication network and operable to control each of the integrated control devices to thereby control the integrated well construction system.', 'The present disclosure also introduces an apparatus comprising: a communication network; a plurality of integrated control devices each directly connected with the communication network, wherein each integrated control device controls a corresponding one of a plurality of integrated well construction components, and wherein the integrated well construction components are collectively operable for constructing a well exclusive of any component not controlled by any of the integrated control devices; and a control workstation directly connected with the communication network and operable to control each of the integrated control devices to thereby control the integrated well construction system.', 'The present disclosure also introduces an apparatus comprising: a communication network; a plurality of integrated control devices each directly connected with the communication network, wherein each integrated control device controls a corresponding one of a plurality of integrated well construction components, and wherein the integrated well construction components form an integrated well construction system operable for constructing a well without any other components; and a control workstation directly connected with the communication network and operable to control each of the integrated control devices to thereby control the integrated well construction system.', 'The present disclosure also introduces a method comprising causing a well construction system to perform a well construction operation, whereby data associated with the well construction operation is automatically collected and analyzed in real-time to determine a plurality of parameters based on the data, and wherein at least some of the determined parameters are used for controlling the well construction operation.', 'The data may be selected from: human operator inputs; equipment control, feedback, and interlock signals; surface sensor signals; and downhole sensor signals.', 'The well construction system may comprise a processing system comprising a processor and a memory having instructions recorded thereon for, when executed by the processor: automatically determining the parameters; and automatically controlling at least a portion of the well construction operation based at least partially on the determined parameters.', 'The well construction system may comprise a processing system comprising a processor and a memory having instructions recorded thereon for, when executed by the processor: automatically determining the parameters; and automatically displaying at least some of the determined parameters to a human operator in substantially real-time.', 'The method may further comprise at least partially controlling, by the human operator, at least a portion of the well construction operation based at least partially on the displayed parameters.', 'The displaying may comprise numbers, pictures, animations, or combinations thereof.', 'The determined parameters may comprise one or more of drilling fluid active volume, drilling fluid loss and/or gain, bit depth, wellbore depth, hook load weight and friction, drilling fluid pump strokes, drilling fluid stroke rate, rate of penetration, weight on bit, bit revolutions, bit runtime, well configuration, drill string configuration, choke configuration, kill line configuration, kick calculator, trip tank volume, trip tank difference determinations, and trip tank accumulated volume.', 'One of the determined parameters may be a kick determination based on: measured depth; true vertical depth; measured shoe depth; vertical shoe depth; original drilling fluid weight; leak off test drilling fluid weight; leak off test pressure; shut in casing pressure; shut in drill pipe pressure; kick gain volume; kill pump selection; kill pump capacity; kill pump speed; slow circulation rate pressure; safety margin; and selected choke/kill line.', 'The present disclosure also introduces a method comprising causing a well construction system to perform a well construction operation, whereby data associated with the well construction operation is automatically collected and analyzed in real-time to determine a plurality of parameters based on the data, and wherein at least some of the determined parameters each provide a basis for triggering at least one real-time well construction operation alarm.', 'The data may be selected from: human operator inputs; equipment control, feedback, and interlock signals; surface sensor signals; and downhole sensor signals.', 'The at least one real-time alarm may be a plurality of alarms comprising: high trip tank volume; low trip tank volume; high active drilling fluid volume; low active drilling fluid volume; high drilling fluid loss; low drilling fluid loss; high drilling fluid gain; low drilling fluid gain; high drilling fluid flow return; low drilling fluid flow return; high standpipe pressure; low standpipe pressure; drilling fluid pumping system total stroke rate; and drilling fluid pumping system total strokes.', 'The well construction system may comprise a processing system comprising a processor and a memory having instructions recorded thereon for, when executed by the processor: automatically determining the parameters; and automatically triggering the at least one real-time alarm based on at least one of the determined parameters.', 'The determined parameters may comprise one or more of drilling fluid active volume, drilling fluid loss and/or gain, bit depth, wellbore depth, hook load weight and friction, drilling fluid pump strokes, drilling fluid stroke rate, rate of penetration, weight on bit, bit revolutions, bit runtime, well configuration, drill string configuration, choke configuration, kill line configuration, kick calculator, trip tank volume, trip tank difference determinations, and trip tank accumulated volume.', 'The present disclosure also introduces an apparatus comprising an analysis-while-drilling (AWD) control system utilized in conjunction with a well construction system during a well construction operation, wherein inputs for the AWD control system comprise: intended configuration of a well being constructed by the well construction system during the well construction operation; configuration of a drill string being used by the well construction system during the well construction operation; signals from drilling parameter sensors; and drilling equipment parameters.', 'Outputs from the AWD control system comprise real-time determination of: depth and trajectory of the well; bit depth; number of drill string tubulars and/or stands in the well; drill string volume, displacements, and weight; drilling fluid tank volumes and tank selections; drilling fluid loss and/or gain; trip tank difference volume; trip tank accumulated volume; total and/or per-section strokes and/or strokes-to-go of drilling fluid pumping system; total stroke rate of drilling fluid pumping system; drilling fluid pumping system liner capacities and efficiencies; individual and total drilling fluid flow into the well; annular drilling fluid velocity; total and/or per-section drilling fluid volumes; total minutes and/or minutes-to-go per section; drilling fluid return flow; bit runtime and revolutions; weight-on-bit; rate of penetration; hook load; and standpipe pressure.', 'The outputs from the AWD control system may further comprise a kick calculator and a kill sheet.', 'The outputs from the AWD control system may further comprise sensors and calculations for storage in a historian associated with the well construction system.', 'The outputs from the AWD control system may further comprise well construction operation warnings and alarms.', 'The drilling parameter sensors may comprise drilling fluid tank level sensors, standpipe pressure sensors, cement manifold pressure sensors, and drilling fluid flow sensors.', 'The drilling equipment parameters may comprise drill string revolutions per minute, make-up torque, hoist position, hook load, slips status, average stand length, average tubular length, liner capacities and efficiencies of individual drilling fluid system pumps, top drive revolutions per minute, choke like parameters, kill line parameters, number of drill string sections, drill string capacity, drill string steel displacement, and drill string closed displacement.', 'The present disclosure also introduces an apparatus comprising a control workstation directly connected with a communication network and operable to control each of a plurality of control devices each directly connected with the communication network, wherein each control device controls a corresponding component of an integrated well construction system, whereby control of the control devices, via operations of the control workstation, controls the integrated well construction system, wherein the control workstation comprises a display, a processor, and a memory storing: a construction program that, when executed by the processor, controls each control device; and an analysis-while-drilling (AWD) program.', 'Inputs for the AWD system comprise: intended configuration of a well being constructed by the well construction system during the well construction operation; configuration of a drill string being used by the well construction system during the well construction operation; signals from drilling parameter sensors; and drilling equipment parameters.', 'When executed by the processor, the AWD program generates in real-time, and displays in real-time in an AWD screen on the display, one or more of: a graphic display of the intended configuration and/or an actual configuration of the well, including depths; a graphic display of a shoe in the well; an animation of the intended and actual configurations of the well; an animation of the drill string in the well; value textual and/or graphic display of drilling fluid front tracking and/or depth; annular velocity per section; open hole volume; total strokes and minutes, strokes and minutes-to-go, and volume for one or more of: surface to bit; bit to shoe; bit to blow-out preventer; bit to surface; well circulation; full circulation; drill string displacement, open end and closed end; drill string weight; number of tubulars in the well; active volume; drilling fluid flow into the well; bit revolutions; and bit runtime.', 'The present disclosure also introduces an apparatus comprising a control workstation for use with an integrated well construction system (IWCS), wherein the IWCS is operable for constructing a well via integrated control of a plurality of integrated control devices that collectively control a plurality of integrated subsystems of the IWCS, and wherein the control workstation comprises a human-machine interface (HMI) comprising a display, a touchscreen, a joystick, and a processing system comprising a processor and a memory having a construction program thereon that, when executed by the processor: presents a human operator of the control workstation with a setup wizard guiding the operator through entering operating parameters for one or more well construction machines of the integrated subsystems to perform a well construction sequence; and controls the integrated control devices, and thus the integrated subsystems, to perform the well construction sequence based on the entered operating parameters.', 'The well construction sequence may be selected from: picking up single tubulars; making drilling connections; building tubular stands; tripping-in drill collar stands; tripping-out drill collar stands; tripping-out wet; backreaming; moving single tubulars from a well center to a catwalk using a top drive; moving tubular stands from the well center to the catwalk; moving casing from the catwalk to the well center using a casing tong; moving casing from the catwalk to the well center using a tubular delivery arm and a casing running tool; moving large diameter casing from the catwalk to the well center using the top drive and the casing running tool; building casing stands; and tripping-in casing stands without using the casing running tool.', 'The entered operating parameters may be for one or more of a top drive, a drawworks, automated slips, a top drive elevator, an iron roughneck, a drilling fluid pumping system, a catwalk, an automated racker, an automated fingerboard, and a tubular delivery arm.', 'The entered operating parameters may comprise speed limitations of at least one of the well construction machines.', 'The entered operating parameters may comprise travel stops of at least one of the well construction machines.', 'The entered operating parameters may comprise maximum limitations of at least one of the well construction machines.', 'The entered operating parameters may comprise target settings of at least one of the well construction machines.', 'The entered operating parameters may comprise target settings of the well construction sequence.', 'The entered operating parameters may comprise automation levels.', 'The automation levels may be selected from: automated control by the construction program; automated control by the construction program after confirmation by the human operator; and manual operation by the human operator.', 'The human operator may cause commencement of the well construction sequence by actuating a button on the touchscreen.', 'The human operator may cause commencement of the well construction sequence by actuating the joystick to ramp up the speed of the well construction machines.', 'The construction program may permit the human operator to take manual control of one or more of the well construction machines during the well construction sequence.', 'The construction program may permit the human operator to change an operating parameter of one or more of the well construction machines during the well construction sequence.', 'The well construction sequence may be a tripping-in or tripping-out sequence, which may be performed with an average stands-per-hour tripping-in or tripping-out speed that is at least five percent faster than attainable by an average human working crew not using the IWCS.', 'The well construction sequence may be a tripping-in or tripping-out sequence, which may be performed with a standard deviation from average tripping-in or tripping-out speed that is at least fifty percent lower than attainable by an average human working crew not using the IWCS.', 'The well construction sequence may be a tripping-in sequence, which may be performed with an average slips-to-slips connection time that is at least four percent faster than attainable by an average human working crew not using the IWCS.', 'The well construction sequence may be a tripping-in sequence, which may be performed with a standard deviation from average slips-to-slips connection time that is at least fifty percent lower than attainable by an average human working crew not using the IWCS.', 'The present disclosure also introduces an apparatus comprising an integrated well construction system (IWCS) operable for constructing a well via integrated control of a plurality of integrated control devices that collectively control a plurality of integrated subsystems of the IWCS, wherein the IWCS comprises a processing system comprising a processor and a memory having a construction program thereon that, when executed by the processor: controls each integrated control device, and thus each integrated subsystem, during each of a plurality of predetermined operational sequences; and prevents collisions between machines of the IWCS.', 'The IWCS machines prevented from colliding by the construction program may comprise: a drawworks; an iron roughneck; a tong-handling trolley; a tong-handling arm; a catwalk; a tubular delivery arm; a lower stabilizing arm; an upper tubular restraint; an intermediate tubular restraint; a lower tubular restraint; a top drive; a top drive elevator; a fingerboard; a transfer bridge racker; and a setback guide arm.', 'The construction program may further prevent collisions between: the IWCS machines; tubulars being transported by any of the IWCS machines; tubulars sticking up out of the well; tubulars in a mousehole of the IWCS; and tubulars in a hand-off position of the IWCS.', 'The construction program may prevent collisions between: a drawworks and one or more of a catwalk, an iron roughneck, a lower stabilizing arm, a tong-handling arm, a tong-handling trolley, a tubular delivery arm, and an upper tubular constraint; and/or a top drive and one or more of the iron roughneck, the tong-handling trolley, the tong-handling arm, the catwalk, the tubular delivery arm, the lower stabilizing arm, and the upper tubular constraint; and/or the iron roughneck and one or more of the drawworks, the top drive, the catwalk, the tubular delivery arm, the lower stabilizing arm, an intermediate tubular constraint, a rotary table, automated slips, a tubular sticking up out of the well, and a tubular sticking up out of a mousehole of the IWCS; and/or the tong-handling trolley and one or more of the drawworks, the top drive, the catwalk, the tubular delivery arm, the lower stabilizing arm, the rotary table, the automated slips, and a tubular sticking up out of the well; and/or the tong-handling arm and one or more of the drawworks, the top drive, the catwalk, the tubular delivery arm, the lower stabilizing arm, the intermediate tubular constraint, the rotary table, the automated slips, a tubular sticking up out of the well, and a tubular sticking up out of a mousehole; and/or the catwalk and one or more of the drawworks, the top drive, the iron roughneck, the tong-handling trolley, the tong-handling arm, the tubular delivery arm, the lower stabilizing arm, a tubular in a hand-off position of the IWCS, and a tubular sticking up out of a mousehole; and/or the tubular delivery arm and one or more of the drawworks, the top drive, the iron roughneck, the tong-handling trolley, the tong-handling arm, the catwalk, the lower stabilizing arm, a transfer bridge racker, the upper tubular constraint, the intermediate tubular constraint, a lower tubular constraint, a setback guide arm, a tubular in the hand-off position, the rotary table, and the automated slips; and/or the lower stabilizing arm and one or more of the drawworks, the top drive, the iron roughneck, the tong-handling trolley, the tong-handling arm, the catwalk, the tubular delivery arm, and the intermediate tubular constraint; and/or the transfer bridge racker and one or more of the tubular delivery arm, the upper tubular constraint, the lower tubular constraint, the setback guide arm, a tubular in the hand-off position, and a fingerboard; and/or the upper tubular constraint and one or more of the drawworks, the top drive, the tubular delivery arm, the transfer bridge racker, the lower tubular constraint, and the setback guide arm; and/or the intermediate tubular constraint and one or more of the iron roughneck, the tong-handling arm, the tubular delivery arm, the lower stabilizing arm, and a tubular in the mousehole; and/or the setback guide arm and one or more of the tubular delivery arm, the lower stabilizing arm, the transfer bridge racker, the upper tubular constraint, and the lower tubular constraint; and/or the fingerboard and the transfer bridge racker; and/or the lower tubular constraint and one or more of the tubular delivery arm, the lower stabilizing arm, the transfer bridge racker, the upper stabilizing arm, and the setback guide arm; and/or a tubular in the hand-off position and one or both of the tubular delivery arm and the transfer bridge racker; and/or the automated slips and one or more of the drawworks, the top drive, the iron roughneck, the tong-handling trolley, the tong-handling arm, the tubular delivery arm, and the lower stabilizing arm.', 'The present disclosure also introduces a method comprising constructing a well utilizing each of a plurality of automatically controlled well construction machines, including: a drawworks; an iron roughneck; a tong-handling trolley; a tong-handling arm; a catwalk; a tubular delivery arm; a lower stabilizing arm; an upper tubular restraint; an intermediate tubular restraint; a lower tubular restraint; a top drive; a top drive elevator; a fingerboard; a transfer bridge racker; a setback guide arm; a mousehole; a mousehole; a drilling fluid pumping system; and a drilling fluid recondition system.', 'The present disclosure also introduces a system operable to completely control each of a plurality of predetermined operational sequences of a well construction operation, wherein the sequences include: picking up single tubulars; making drilling connections; building tubular stands; tripping-in drill collar stands; tripping-out drill collar stands; tripping-out wet; backreaming; moving single tubulars from a well center to a catwalk using a top drive; moving tubular stands from the well center to the catwalk; moving casing from the catwalk to the well center using a casing tong; moving casing from the catwalk to the well center using a tubular delivery arm and a casing running tool; moving large diameter casing from the catwalk to the well center using the top drive and the casing running tool; building casing stands; and tripping-in casing stands without using the casing running tool.', 'The present disclosure also introduces a control system for controlling drilling operations in which a level of automation for various operations can be selected.', 'It may generate a control screen facilitating selection of level of automation.', 'It may facilitate selection of full automation, semi-automation (e.g., confirmation by driller to start a specific sequence), or manual control (e.g., via a joystick).', 'The present disclosure also introduces a control system for controlling drilling operations comprising: a customizable display; a control screen facilitating selection of scale and limits for indicator graphs (e.g., circular bar graph, linear bar graph); customizable selections including minimum and maximum graph values, warning value limits, and scale.', 'The present disclosure also introduces a control system for controlling drilling operations, including a display of software objects (symbols, icons, buttons, etc.)', 'that: are displayed on a monitor or touchscreen; are indicative of equipment or device status via changing color, localized background color, adjacent or localized background symbol (e.g., check or X), flashing color, filled or unfilled object, etc.; show operational status (e.g., high value, open, closed, running, idle, error, etc.); show communication status (e.g., feedback error, communication error, etc.); show control status (e.g., auto, manual, local, etc.); and/or can be displayed in association with displayed numerical values.', 'The present disclosure also introduces a rig control system comprising a communication network.', 'The communication network may be a single ring, star, or daisy-chain network.', 'The communication network may be fiberoptic.', 'The rig control system also comprises a control workstation connected directly to the network.', 'The rig control system also comprises multiple different control devices.', 'Each control device may perform, cause the performance of, sense, measure, monitor, and/or log a mechanical, software, or other action of a mechanical, software, or other surface or downhole component (or group thereof), subsystem (or group thereof), or system (or group thereof).', 'Each control device may be connected directly to the communication network.', 'Each control device may communicate (directly or indirectly) with each other control device.', 'Each control device may act at least partially in response to, or act at least partially based on, or otherwise use data from at least one other control device.', 'For example, each control device may have an input from (the control device(s) of) another rig component (or group thereof), rig subsystem (or group thereof), or rig system (or group thereof).', 'Each control device may be a computer (PC or IPC) or a PLC.', 'The rig control system may also comprise multiple local control networks.', 'Each local control network may be connected with the communication network, such as via a corresponding one of the control devices.', 'The rig control system may also comprise multiple local control devices.', 'Each local control device may be connected directly with a corresponding local control network.', 'Each local control device may be a computer (PC or IPC) or a PLC.', 'The control devices connected directly to the communication network may perform all control logic, and the control workstation may be (at least mostly) a data exchange.', 'The present disclosure also introduces an alarm system that helps operators to operate equipment and processes in an efficient and safe manner The alarm system may utilize screen objects/symbols that: are indicative of equipment or device; show status via changing color, localized background color, adjacent or localized background symbol, flashing color, filled or unfilled object, etc.; are designed to draw operator attention to alarms by use of colors, symbols, flashing, sounds, and other notations with distinct meaning, present descriptive and easy to understand alarm texts, use alarm priority with distinct meaning, logically group alarms, keep the alarm rate as low as possible, ensure operators responds to all alarms, permit intuitive navigation and alarm acknowledgement, permit logging all alarms and alarm state changes, and provide high system availability and robustness.', 'The present disclosure also introduces an analysis-while-drilling (AWD) control system that is operable to show a large number of drilling related parameters determined by sophisticated algorithms The AWD inputs may include: well configuration; drill string (including BHA) configuration; drilling parameter sensors (e.g., mud pit level sensors, standpipe pressure sensors, mud flow sensors); and drilling equipment parameters (e.g., directly from the equipment, such as drill string RPM, make-up torque, mud pump SPM).', 'The AWD outputs may be delivered to and/or used by: workstation(s) display(s), including an AWD display; a historical logging system; and/or a mud logger system.', 'The AWD outputs may include well configuration, drill string (including BHA) configuration, and dynamic tracking of: the well; bit depth; stands in hole; sectioned mud volumes; drill string volume, displacements, and weight; mud tank volumes, including active tank selection and loss/gain calculation; trip tank difference volume; trip tank accumulated volume; mud pump total stroke counters (individual count may be done in mud pumps); mud pump SPM total; mud pump liner capacities and efficiencies; mud flow into hole, individual and total; annular mud velocity per section; mud volume per section; total strokes per section; strokes to go per section; total minutes per section; minutes to go per section; mud return flow; bit runtime and revolutions; WOB; ROP; hook load; and standpipe pressure.', 'The AWD outputs may also include: kick calculator and kill sheet; sensors and calculations for storage in historical trending system; drilling operation warnings and alarms.', 'The present disclosure also introduces an AWD display screen showing: graphic display of well configuration and hole section depths; graphic display of shoe; animation of planned vs. actual well; animation of drill string in well; value and graphic display of mud front tracking/depth; annular velocity per section; open hole volume; dynamic calculation of total strokes and minutes, strokes and minutes to go, and volume for Surface To Bit, Bit To Shoe, Bit To BOP, Bit To Surface, Well Circulation, Full Circulation, drill string displacement (open end and closed end), drill string weight, stands in hole, active volume, mud flow in, bit revolutions, and bit runtime.', 'The present disclosure also introduces automated tripping-in (or tripping-out) resulting in: an automated average tripping-in speed (e.g., in stands/hour) that is at least 5% faster than an average human working crew; and/or an automated standard deviation from average tripping-in speed that is at least 50% lower than for an average human working crew; and/or an automated average tripping-in slip-to-slip connection time that is at least 4% faster than an average human working crew; and/or an automated standard deviation from average tripping-in slip-to-slip connection time that is at least 50% lower than for an average human working crew.', 'The present disclosure also introduces a method of automating drilling operations that requires entry of at least a given group of input parameters and requires ability to exercise automated control over at least a given group of equipment related to drilling operations.', 'The present disclosure also introduces a control system for controlling drilling operations in which a level of automation for various operations can be selected.', 'It may generate a control screen facilitating selection of level of automation.', 'It may facilitate selection of full automation, semi-automation (e.g., confirmation by driller to start a specific sequence), or manual control (e.g., via a joystick).', 'The present disclosure also introduces a control system for controlling drilling operations comprising: a customizable display; a control screen facilitating selection of scale and limits for indicator graphs (e.g., circular bar graph, linear bar graph); and customizable selections, including: minimum and maximum graph values, warning value limits, and scale.', 'The present disclosure also introduces a control system for controlling drilling operations, including a display of software objects (symbols, icons, buttons, etc.)', 'that: are displayed on a monitor or touchscreen; are indicative of equipment or device status via changing color, localized background color, adjacent or localized background symbol (e.g., check or X), flashing color, filled or unfilled object, etc.; show operational status (e.g., high value, open, closed, running, idle, error, etc.); show communication status (e.g., feedback error, communication error, etc.); show control status (e.g., auto, manual, local, etc.); and/or can be displayed in association with displayed numerical values.', 'The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure.', 'A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein.', 'A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.', 'The Abstract at the end of this disclosure is provided to permit the reader to quickly ascertain the nature of the technical disclosure.', 'It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.']

['1.', 'A method comprising:\ncausing a well construction system to perform a well construction operation;\nautomatically collecting data associated with the well construction operation;\nautomatically analyzing the data in real-time to determine a plurality of parameters based on the data, wherein one of the determined plurality of parameters is a kick determination, and wherein the kick determination is based on measured depth, true vertical depth, measured shoe depth, vertical shoe depth, original drilling fluid weight, leak off test drilling fluid weight, leak off test pressure, shut in casing pressure, shut in drill pipe pressure, kick gain volume, kill pump selection, kill pump capacity, kill pump speed, slow circulation rate pressure, safety margin, and selected choke/kill line; and\nusing at least one of the determined parameters for controlling the well construction operation.', '2.', 'The method of claim 1, wherein the data is selected from:\nhuman operator inputs;\nequipment control, feedback, and interlock signals;\nsurface sensor signals; and\ndownhole sensor signals.', '3.', 'The method of claim 1, further comprising:\nautomatically determining the plurality of parameters based on analyzing of the data; and\nautomatically controlling at least a portion of the well construction operation based at least partially on the determined plurality of parameters.', '4.', 'The method of claim 3, further comprising automatically displaying at least some of the determined parameters to a human operator in substantially real-time.', '5.', 'The method of claim 4, further comprising at least partially controlling, by the human operator, at least a portion of the well construction operation based at least partially on the displayed parameters.', '6.', 'The method of claim 4, wherein the displaying comprises displaying numbers, pictures, animations, or combinations thereof associated with the at least some of the determined parameters.', '7.', 'The method of claim 1, wherein the determined plurality of parameters comprise at least one of: drilling fluid active volume, drilling fluid loss and/or gain, bit depth, wellbore depth, hook load weight and friction, drilling fluid pump strokes, drilling fluid stroke rate, rate of penetration, weight on bit, bit revolutions, bit runtime, well configuration, drill string configuration, choke configuration, kill line configuration, kick calculator, trip tank volume, trip tank difference determinations, or trip tank accumulated volume.\n\n\n\n\n\n\n8.', 'A method comprising:\ncausing a well construction system to perform a well construction operation;\nautomatically collecting data associated with the well construction operation;\nautomatically analyzing the data in real-time to determine a plurality of parameters based on the data; and\ntriggering at least one real-time well construction operation alarm, of a plurality of alarms, based on at least one of the determined parameters, wherein the plurality of alarms comprise high trip tank volume, low trip tank volume, high active drilling fluid volume, low active drilling fluid volume, high drilling fluid loss, low drilling fluid loss, high drilling fluid gain, low drilling fluid gain, high drilling fluid flow return, low drilling fluid flow return, high standpipe pressure, low standpipe pressure, drilling fluid pumping system total stroke rate, and drilling fluid pumping system total strokes.', '9.', 'The method of claim 8, wherein the data is selected from:\nhuman operator inputs;\nequipment control, feedback, and interlock signals;\nsurface sensor signals; and\ndownhole sensor signals.', '10.', 'The method of claim 8, further comprising:\nautomatically determining the plurality of parameters; and\nautomatically triggering the at least one real-time alarm based on at least one of the determined plurality of parameters.', '11.', 'The method of claim 8, wherein the determined plurality of parameters comprises at least one of: drilling fluid active volume, drilling fluid loss and/or gain, bit depth, wellbore depth, hook load weight and friction, drilling fluid pump strokes, drilling fluid stroke rate, rate of penetration, weight on bit, bit revolutions, bit runtime, well configuration, drill string configuration, choke configuration, kill line configuration, kick calculator, trip tank volume, trip tank difference determinations, or trip tank accumulated volume.\n\n\n\n\n\n\n12.', 'An apparatus comprising:\nan analysis-while-drilling (AWD) control system utilized in conjunction with a well construction system during a well construction operation, wherein: inputs for the AWD control system comprise: intended configuration of a well being constructed by the well construction system during the well construction operation; configuration of a drill string being used by the well construction system during the well construction operation; signals from drilling parameter sensors; and drilling equipment parameters; and outputs from the AWD control system comprise real-time determination of: depth and trajectory of the well; bit depth; number of drill string tubulars and/or stands in the well; drill string volume, displacements, and weight; drilling fluid tank volumes and tank selections; drilling fluid loss and/or gain; trip tank difference volume; trip tank: accumulated volume; total and/or per-section strokes and/or strokes-to-go of drilling fluid pumping system; total stroke rate of drilling fluid pumping system; drilling fluid pumping system liner capacities and efficiencies; individual and total drilling fluid flow into the well; annular drilling fluid velocity; total and/or per-section drilling fluid volumes; total minutes and/or minutes-to-go per section; drilling fluid return flow; bit runtime and revolutions; weight-on-bit; rate of penetration; hook load; and standpipe pressure.', '13.', 'The apparatus of claim 12, wherein the outputs from the AWD control system further comprise a kick calculator and a kill sheet.', '14.', 'The apparatus of claim 12, wherein the outputs from the AWD control system further comprise sensors and calculations for storage in a historian associated with the well construction system.', '15.', 'The apparatus of claim 12, wherein the outputs from the AWD control system further comprise well construction operation warnings and alarms.', '16.', 'The apparatus of claim 12, wherein the drilling parameter sensors comprise drilling fluid tank: level sensors, standpipe pressure sensors, cement manifold pressure sensors, and drilling fluid flow sensors.', '17.', 'The apparatus of claim 12, wherein the drilling equipment parameters comprise drill string revolutions per minute, make-up torque, hoist position, hook load, slips status, average stand length, average tubular length, liner capacities and efficiencies of individual drilling fluid system pumps, top drive revolutions per minute, choke like parameters, kill line parameters, number of drill string sections, drill string capacity, drill string steel displacement, and drill string closed displacement.\n\n\n\n\n\n\n18.', 'An apparatus comprising:\na control workstation directly connected with a communication network and operable to control each of a plurality of control devices to control an integrated well construction system, wherein each of the plurality of control devices is directly connected with the communication network, wherein each control device controls a corresponding component of the integrated well construction system, wherein the control workstation comprises a display, a processor, and a memory, and wherein:\nthe memory stores: a construction program that, when executed by the processor, controls each of the plurality of control devices; and an analysis-while-drilling (AWD) program;\ninputs for the AWD program comprise: intended configuration of a well being constructed by the well construction system during the well construction; configuration of a drill string being used by the well construction system during the well construction operation; signals from drilling parameter sensors; and drilling equipment parameters; and\nwhen executed by the processor, the AWD program: automatically analyzes data in real-time to determine a plurality of parameters based on the data, wherein one of the determined plurality of parameters is a kick determination, and wherein the kick determination is based on measured depth, true vertical depth, measured shoe depth, vertical shoe depth, original drilling fluid weight, leak off test drilling fluid weight, leak off test pressure, shut in casing pressure, shut in drill pipe pressure, kick gain volume, kill pump selection, kill pump capacity, kill pump speed, slow circulation rate pressure, safety margin, and selected choke/kill line; and generates, in real-time, and displays in real-time in an AWD screen on the display, a graphic display of the intended configuration and/or an actual configuration including depths of the well and at least one of: a graphic display of a shoe in the well; an animation of the intended and actual configurations of the well; an animation of the drill string in the well; value textual and/or graphic display of drilling fluid front tracking and/or depth; annular velocity per section; open hole volume; total strokes and minutes, strokes and minutes-to-go, and volume for one or more of: surface to bit; bit to shoe; bit to blow-out preventer; bit to surface; well circulation; full circulation; drill string displacement, open end and closed end; drill string weight; number of tubulars in the well; active volume; drilling fluid flow into the well; bit revolutions; or bit runtime.']

['FIG.', '1 is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', '; FIG.', '2 is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', '; FIG.', '3 is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', '; FIG.', '4 is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', '; FIG.', '5 is a perspective view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.; FIG.', '6 is a perspective view of a portion of the apparatus shown in FIG.', '5 according to one or more aspects of the present disclosure.', '; FIG. 7 is a top view of a portion of an example implementation of the apparatus shown in FIG.', '6 according to one or more aspects of the present disclosure.', '; FIGS. 8-10 are example implementations of software controls displayed by the apparatus shown in FIG.', '7 according to one or more aspects of the present disclosure.', '; FIGS.', '11-21 are example implementations of screens displayed by the apparatus shown in FIG.', '7 according to one or more aspects of the present disclosure.', '; FIG.', '22 is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', '; FIG.', '23 is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.', '; FIG.', '24 is a schematic view of at least a portion of an example implementation of apparatus or a system according to one or more aspects of the present disclosure.; FIG.', '1 is a schematic view of at least a portion of an example implementation of an integrated well construction system 100 (i.e., a drill rig) according to one or more aspects of the present disclosure.', 'The well construction system 100 represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'Although the well construction system 100 is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', '; FIG.', '2 is a schematic view of an example implementation of a wellsite system 200 comprising a plurality of pipe handling equipment, each comprising or carrying one or more sensors operable to generate sensor measurements indicative of corresponding operational parameters (e.g., position, speed, acceleration, etc.) of such equipment.', 'According to one or more aspects of the present disclosure, the various pieces of equipment of the wellsite system 200 may be operable to move tubulars 111 between various positions of the wellsite system 200, to perform processes described herein, including assembly and disassembly of a drill string 120.', 'The wellsite system 200 may form a portion of and/or operate in conjunction with the well construction system 100 shown in FIG.', '1, including where indicated by the same numerals.', 'Accordingly, the following description refers to FIGS.', '1 and 2, collectively.;', 'FIG. 4 is a schematic view of an example implementation of the control system 300 shown in FIG.', '3 communicatively connected with the subsystems 311-316 of the well construction system 100, 200, including the RC system 311, the FC system 312, the MPDC system 313, the CPC system 314, the WC system 315, and the CCTV system 316.', 'The following description refers to FIGS.', '1-4, collectively.; FIGS. 5 and 6 are perspective and sectional views of at least a portion of an example implementation of a control center 400 according to one or more aspects of the present disclosure.', 'The control center 400 may be or form at least a portion of the control center 190 shown in FIG.', '1.', 'The following description refers to FIGS.', '1-6, collectively.;', 'FIG. 7 is a top view of a portion of an example implementation of a wellsite operator control workstation 500 communicatively connected with and operable to control the well construction system 100, 200 according to one or more aspects of the present disclosure.', 'The control workstation 500 depicted in FIG. 7 is an example implementation of the control workstations 450, 452, 454 described above.', 'The control workstation 500 may facilitate receiving and displaying various information, such as sensor signals or information (e.g., sensor data 351-356), control commands (e.g., control data 361-366), processes taking place, events being detected, and operational status of various equipment of the subsystems 311-316 of the well construction system 100, 200.', 'The following description refers to FIGS.', '1-7, collectively.; FIGS.', '11-15 are example implementations of control screens 601-605 (e.g., configuration screens or menus) that may be displayed on the touchscreens 522, 524 according to one or more aspects of the present disclosure.', 'Each control screen 601-605 may be operated via finger contact with the touchscreens 522, 524 (and/or other input means) by the wellsite operator 195 to operate, set, adjust, configure, or otherwise control the subsystems 311-316 or other wellsite equipment of the well construction system 100, 200 associated with or displayed on the control screen 601-605.', 'The following description refers to FIGS.', '11-15, collectively.;', 'FIG. 12 is an example implementation of a “DRILLING” control screen 602 that may be utilized to control automated, semi-automated, and/or manual operation of wellsite equipment associated with and/or collectively operable to perform drilling operations according to one or more aspects of the present disclosure.', 'The control screen 602 may display in the equipment control area 618 various software controls 630 for controlling various wellsite equipment and/or operational parameters of the drilling operations performed by well construction system 100, 200.', 'For example, when operated, the software controls 630 may activate, deactivate, start, stop, configure, or otherwise control automated, semi-automated, and/or manual operation of the wellsite equipment associated with the drilling operations.', 'Such wellsite equipment may include the top drive 116, the DW 119, the pump 144, and the BOP equipment 130, 132, among other examples.; FIG.', '13 is an example implementation of an “PIPE HANDLING” control screen 603 that may be utilized to control automated, semi-automated, and/or manual operation of wellsite equipment associated with and/or collectively operable to perform drill pipe handling (e.g., moving, storing) operations according to one or more aspects of the present disclosure.', 'The control screen 603 may display in the equipment control area 618 various software controls 630 for controlling various wellsite equipment and/or operational parameters of the drill pipe handling operations performed by well construction system 100, 200.', 'For example, when operated, the software controls 630 may activate, deactivate, start, stop, configure, or otherwise control automated, semi-automated, and/or manual operation of the wellsite equipment associated with the drill pipe handling operations.', 'Such wellsite equipment may include the catwalk 131, the TDA 202, the setback 164, the FIB 166, the TBR 254, the SGA 262, the LTC 244, the ITC 236, the UTC 242, the LSA 228, the RN 151, and the reciprocating slips 161, among other examples.; FIG.', '14 is an example implementation of a “TOP DRIVE” control screen 604 that may be utilized to control automated, semi-automated, and/or manual operation of the top drive 116 according to one or more aspects of the present disclosure.', 'The control screen 604 may display in the equipment control area 618 various software controls 630 for configuring and/or controlling automated, semi-automated, and/or manual operations performed by the top drive 116 and/or operational parameters associated with the top drive 116.', 'For example, when operated, the software controls 630 may activate, deactivate, start, stop, configure, or otherwise control operation of one or more portions of the top drive 116, such as the drive shaft 125, the grabber, the swivel, the tubular handling assembly 127, and other portions of the top drive 116.', 'The software controls 630 may also be utilized to control other wellsite equipment that may be directly or closely associated with or operate in close association with the top drive 116, such as the RN 151.; FIG.', '15 is an example implementation of a “ROUGHNECK 1” control screen 605 that may be utilized to control automated, semi-automated, and/or manual operation of one of the RNs 151 according to one or more aspects of the present disclosure.', 'The control screen 605 may display in the equipment control area 618 various software controls 630 for configuring or controlling automated, semi-automated, and/or manual operations performed by the RN 151 and/or operational parameters associated with the RN 151.', 'For example, when operated, the software controls 630 may activate, deactivate, start, stop, configure, or otherwise control operation of one or more portions of the RN 151, such as the spinner and the torque wrench, including the upper and lower tongs and the associated clamps.', 'The software controls 630 may also be utilized to control other wellsite equipment that may be directly or closely associated with or operate in close association with the RN 151.; FIG.', '16 is an example implementation of a manual control guide screen 606 displaying control functions for controlling drilling operations via the left joystick 510 and physical controls 514.', 'The guide screen 606 may display a title bar 640 identifying an operation or wellsite equipment to be controlled and the joystick 510 and/or physical controls 514 for controlling such operation or wellsite equipment.', 'The guide screen 606 may comprise a joystick control area 642 displaying a schematic view 644 of the joystick 510 and a schematic view 646 of the associated physical controls 518 (e.g., joystick buttons and thumb lever).', 'Each schematic button 646 is associated with text 638 describing control functions of each corresponding physical button 518 of the joystick 510.', 'The joystick control area 642 may further display arrows 648 and corresponding text 650 describing control functions associated with movements of the joystick 510, and arrows 652 and corresponding text 654 describing control functions associated with movement of the joystick thumb lever 518.', 'The guide screen 606 may also comprise a button control area 656 displaying schematic views 658 of the corresponding physical controls 514.', 'The button control area 656 may further display text 660 describing control functions associated with operation of each of the corresponding physical controls 514.', 'The guide screen 606 may further display an “EXIT” software control 662, which may be operated to abort manual control of the drilling operations and close the guide screen 606.', 'As described above with respect to FIG. 7, an operator workstation within the scope of the present disclosure may display on one or more of the video output devices 526 a plurality of status screens, each displaying selected sensor signals or information (e.g., sensor data 351-356) generated by various sensors (e.g., sensors 321-326) of the wellsite construction system 100, such as may permit the wellsite operator to monitor operations, wellsite equipment, and/or equipment subsystems (e.g., subsystems 311-316) described herein.', 'FIGS.', '17-21 are views of example implementations of status screens 701-706 displayed on one or more of the video output devices 526 according to one or more aspects of the present disclosure.', 'The following description refers to FIGS.', '1-4, 7, and 17-21, collectively.;', 'FIG.', '17 is an example implementation of a status screen 701 displaying sensor signals or information indicative of operational status of various wellsite equipment associated with and collectively operable to perform drill pipe tripping operations according to one or more aspects of the present disclosure.', 'When the wellsite operator 195 or the control system 300 causes the tripping operations status screen 701 to be displayed on one of the video output devices 526, the indicator 712 associated with the tripping operations, such as letters “TR,” may appear or become highlighted to visually indicate to the wellsite operator 195 that the tripping operations status screen is being displayed.', 'The primary operational status area 716 may display information, such as hook load, weight-on-bit, travelling block position, roughneck torque, trip tank accumulation or volume, and return flow, among other examples.', 'The secondary operational status area 718 may display information related to drilling operations, such as hook load, traveling block position, drill bit depth, wellbore depth, number of stands or tubulars in the wellbore, standpipe pressure, top drive dolly location, inside BOP position, top drive pipe connection status, elevator status, stick-up connection status, and slips status, among other examples.', 'The description area 720 may display a work plan (i.e., well construction plan) related to the tripping operations, including actions or steps that will be performed or overseen at the wellsite by the wellsite operator 195 during the tripping operations.', 'However, the description area 720 may also or instead display information indicative of operational events, as described above.', '; FIG.', '18 is an example implementation of a status screen 702 displaying sensor signals or information indicative of operational status of various wellsite equipment associated with and collectively operable to perform drilling operations according to one or more aspects of the present disclosure.', 'When the wellsite operator 195 or the control system 300 causes the drilling operations status screen 702 to be displayed on one of the video output devices 526, the indicator 712 associated with the drilling operations, such as letters “DR,” may appear or become highlighted to visually indicate to the wellsite operator 195 that the drilling operations status screen is being displayed.', 'The primary operational status area 716 may display information, such as hook load, travelling block speed, weight-on-bit, rate of penetration, standpipe pressure, top drive torque, torque wrench torque, top drive rotational speed, drilling fluid loss/gain, and drilling fluid return flow, among other examples.', 'The secondary operational status area 718 may display information related to drilling operations, such as information related to or indicative of drilling fluid (i.e., mud) operational status and/or active tank operational status.', 'The description area 720 may display a work plan (i.e., well construction plan) related to the drilling operations, including actions or steps that will be performed or overseen at the wellsite by the wellsite operator 195 during the drilling operations.', 'However, the description area 720 may also or instead display information indicative of operational events, as described above.', '; FIG.', '20 is an example implementation of a CPC system status screen 705 displaying sensor signals or information indicative of operational status of the CPC system 314 according to one or more aspects of the present disclosure.', 'When the wellsite operator 195 or the control system 300 causes the CPC system status screen 705 to be displayed on one of the video output devices 526, the indicator 712 associated with the CPC system 314, such as letters “CPC,” may appear or become highlighted to visually indicate to the wellsite operator 195 that the CPC system status screen 705 is being displayed.', 'The primary operational status area 716 may display sensor signals or information related to various pieces of wellsite equipment forming the CPC system 314, such as the choke manifold 162 and related wellsite equipment.', 'The primary operational status area 716 may also display schematic representations 730 of the wellsite equipment to visually display to the wellsite operator 195 operational status of such wellsite equipment.', 'The schematic representations 730 may include, for example, various fluid control valves (e.g., ball valves, adjustable chokes) of the choke manifold 162 and a plurality of fluid control valves fluidly connected with the choke manifold 162.', 'The primary operational status area 716 may visually indicate to the wellsite operator 195 in real-time operational status, fluid flow rates, fluid pressures, and valve positions of the wellsite equipment forming the CPC system 314.', 'Portions of the schematic representations 730 (e.g., fluid valves) may change position and/or color to indicate to the wellsite operator 195 operational status (e.g., positions) of such wellsite equipment.', 'The primary operational status area 716 may also display sensor signals or information indicative of operational status of the wellsite equipment within text boxes 732 located in association with the schematic representations 730 of the wellsite equipment.', 'The secondary operational status area 718 may display information related to drilling operations and/or additional information related to operational status of the CPC system 314, such as additional information that is not displayed in the primary operational status area 716.', 'The description area 720 may display information indicative of operational events, as described above.', 'However, the description area 720 may also or instead display a work plan related to tripping, drilling, or other wellsite construction operations.', 'A PIP video window 722 showing a real-time view of the choke manifold 162 or another portion of the CPC system 314 may be displayed in the primary operational status area 716 or another area of the CPC system status screen 705.; FIG.', '21 is an example implementation of a WC system status screen 706 displaying sensor signals or information indicative of operational status of the WC system 315 according to one or more aspects of the present disclosure.', 'When the wellsite operator 195 or the control system 300 causes the WC system status screen 706 to be displayed on one of the video output devices 526, the indicator 712 associated with the WC system 315, such as letters “WC,” may appear or become highlighted to visually indicate to the wellsite operator 195 that the WC system status screen 706 is being displayed.', 'The primary operational status area 716 may display sensor signals or information related to various pieces of wellsite equipment forming the WC system 315, such as the BOP equipment 130, 132.', 'Information displayed in the primary operational status area 716 may include, for example, information related to risers/diverters, POD controls, POD regulators, analog sensor values (e.g., pressure, position), BOP event alarm signals, and inclination sensors.', 'The primary operational status area 716 may visually indicate to the wellsite operator 195 in real-time operational status, fluid pressures, and operational positions of the wellsite equipment forming the CPC system 314.', 'The primary operational status area 716 may also display schematic representations 730 of the wellsite equipment to visually display to the wellsite operator 195 operational status of such wellsite equipment.', 'The schematic representations 730 may include, for example, the BOP stack 130 and the annular fluid control device 132, and visually indicate to the wellsite operator 195 operational status (e.g., position) of the various rams and valves of the BOP stack 130 and the annular fluid control device 132.', 'Portions of the schematic representations 730 (e.g., fluid valves, rams) may change position and/or color to indicate to the wellsite operator 195 operational status (e.g., positions) of such wellsite equipment.', 'The primary operational status area 716 may also display sensor signals or information indicative of operational status of the wellsite equipment within text boxes 732 located in association with the schematic representations 730 of the wellsite equipment.', 'The secondary operational status area 718 may display information related to drilling operations and/or additional information related to operational status of the WC system 315, such as additional information that is not displayed in the primary operational status area 716.', 'The description area 720 may display information indicative of operational events, as described above.', 'However, the description area 720 may also or instead display a work plan related to tripping, drilling, or other wellsite construction operations.', 'A PIP video window 722 showing a real-time view of the BOP equipment 130, 132 or another portion of the WC system 315 may be displayed in the primary operational status area 716 or another area of the WC system status screen 706.; FIG.', '22 is a schematic view of at least a portion of an example implementation of a system (or processing device) 800 according to one or more aspects of the present disclosure.', 'The system 800 may form at least a portion of one or more electronic devices utilized at the well construction system 100, 200.', 'For example, the system 800 may be or form at least a portion of the processing devices 188, 192, 456, and the control workstations 450, 452, 454, 500.', 'The system 800 may form at least a portion of the control system 300, including the wellsite computing resource environment 305, the coordinated control device 304, the supervisory control system 307, the local controllers 341-346, the onsite user devices 302, and the offsite user devices 303.', 'The following description refers to FIGS.', '1-7 and 22, collectively.;', 'FIG.', '23 is a schematic view of at least a portion of an example implementation of a processing device 1000 according to one or more aspects of the present disclosure.', 'One or more electronic devices utilized at the well construction system 100, 200 may each be, comprise, or be formed by at least a portion of the processing device 1000.', 'For example, the processing devices 188, 192, 456, the BOP control station 470, the control workstations 450, 452, 454, 500, 850, 852, 992, and the CPUs 901-981, may each be, comprise, or be formed by at least a portion of an instance the processing device 1000.', 'Instances of the processing device 1000, or portions thereof, may form at least a portion of the control system 300, including the wellsite computing resource environment 305, the coordinated control device 304, the supervisory control system 307, the local controllers 341-346, the onsite user devices 302, and the offsite user devices 303.; FIG.', '24 depicts a component 1140 that is a subject of the ZMS.', 'The component 1140 can be any component of the IWCS.', 'The component 1140 has a zone 1141 that at least partially envelops the component 1140.', 'The zone 1141 may be larger than the component 1140 such that a buffer zone is created between the extremities of the component 1140 and the zone 1141 to further help avoid collisions between components.', 'A database 1142 stores characteristics of the components tracked by the ZMS.', 'The database 1142 may store information related to position, size, shape, weight, motion path, tolerance, impact sensitivity, reference point, center of mass 1143, and attachment points.', 'A processing system 1144 of the ZMS may execute the logic and calculations.', 'The processing system 1144 may be an instance of the processing system 1000 shown in FIG.', '23.']

US11814942

Optimizing algorithm for controlling drill string driver

Nov 4, 2020

Benjamin Peter Jeffryes, Nathaniel Wicks, Jian Wu

SCHLUMBERGER TECHNOLOGY CORPORATION

Dwars, S., “Recent Advances in Soft Torque Rotary Systems”, SPE-173037 presented at the SPE/IADC Drilling Conference and Exhibition, London, England, UK, 2015, pp. 12 pages.; Kyllingstad, A. et al., “A New Stick-Slip Prevention System”, SPE-119660 presented at the SPE/IADC Drilling Conference and Exhibition, Amsterdam, The Netherlands, 2009, pp. 14 pages.; Kyllingstad, A. , “A comparison of Stick-Slip Mitigation Tools”, SPE-184658, presented at the SPE/IADC Drilling Conference and Exhibition, the Hague, The Netherlands, 2017, pp. 16 pages.; Halsey, G. W. et al., “Torque Feedback Used to Cure Slip-Stick Motion”, SPE-18049 presented at the SPE Annual Technical Conference and Exhibition, Houston, Texas, U.S.A., 1988, pp. 277-282.

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Foreign Citations not found.

['Apparatus and methods for optimizing a stick-slip algorithm for controlling a driver of a drill string.', 'A method may include commencing operation of a control system for controlling the driver.', 'The control system may have a processor and a memory storing a computer program code, which may include the stick-slip algorithm.', 'The operating control system may receive a plurality of different numerical parameters, and for each of the different numerical parameters, incorporate the numerical parameter into the stick-slip algorithm and execute the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority to and the benefit of U.S. Provisional Application No. 62/930,045, titled “Optimizing Algorithm for Controlling Drill String Driver,” filed Nov. 4, 2019, the entire disclosure of which is hereby incorporated herein by reference.', 'BACKGROUND OF THE DISCLOSURE\n \nWells are generally drilled into the ground or ocean bed to recover natural deposits of oil, gas, and other materials that are trapped in subterranean formations.', 'Drilling operations may be performed at a wellsite by a well construction system (i.e., a drilling rig) having various surface and subterranean well construction equipment being operated in a coordinated manner.', 'For example, a driver (i.e., a drive mechanism), such as a top drive or a rotary table located at a wellsite surface, can be utilized to rotate and advance a drill string into a subterranean formation to drill a wellbore.', 'The drill string may include a plurality of drill pipes coupled together and terminating with a drill bit.', 'Length of the drill string may be increased by adding additional drill pipes while depth of the wellbore increases.', 'During drilling operations, a drill string undergoes complicated dynamic behavior, including experiencing axial, lateral, and rotational vibrations, as well as frictional interactions with the bottom and sidewalls of the wellbore being drilled.', 'Rotational speed (i.e., angular velocity) measurements of the drill string taken at the wellsite surface (e.g., at the driver) and downhole (e.g., at the drill bit) have revealed that while the upper end of the drill string rotates with a substantially constant rotational speed, lower portions of the drill string often rotate with varying rotational speeds.', 'For example, a drill string may experience stick-slip motion, whereby a drill bit stops rotating (i.e., sticks) in a wellbore, such as due to friction, while the upper end of the drill string continues to be rotated by the driver, twisting the drill string.', 'When the drill bit becomes free and rotates again (i.e., slips), it accelerates to a rotational speed that may be higher than the rotational speed of the upper end of the drill string.', 'Such stick-slip motion may cause rotational (i.e., torsional) waves (i.e., oscillations, vibrations, etc.) that propagate or otherwise travel in an upward (i.e., uphole) and/or downward (i.e., downhole) directions along a drill string while the drill string is rotated within a wellbore.', 'Stick-slip motion and the resulting rotational waves in the drill string are a recognized problem in the drilling industry, causing one or more of reduced rate of penetration through the subterranean formation, bit wear, torsional damage to the drill string, failures or damage to the surface driver, and other damage to drilling equipment.', 'SUMMARY OF THE DISCLOSURE', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure introduces an apparatus that includes a control system that controls a driver for rotating a drill string.', 'The control system includes a processor and a memory storing a computer program code.', 'The computer program code includes a stick-slip algorithm.', 'The control system receives different numerical parameters and, for each of the different numerical parameters, incorporates the numerical parameter into the stick-slip algorithm and executes the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing rotational waves travelling along the drill string.', 'The present disclosure also introduces a method that includes commencing operation of a control system for controlling a driver of a drill string.', 'The control system includes a processor and a memory storing a computer program code.', 'The computer program code includes a stick-slip algorithm.', 'The operating control system receives different numerical parameters and, for each of the different numerical parameters, incorporates the numerical parameter into the stick-slip algorithm and executes the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing rotational waves travelling along the drill string.', 'The present disclosure also introduces a method that includes commencing operation of a processing device to run a computer simulation of a drill string being rotated by a driver to drill a wellbore.', 'Rotation of the driver is controlled by a stick-slip algorithm.', 'The operating processing device receives different numerical parameters and, for each of the different numerical parameters, incorporates the numerical parameter into the stick-slip algorithm and executes the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string.', 'These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the material herein and/or practicing the principles described herein.', 'At least some aspects of the present disclosure may be achieved via means recited in the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is understood from the following detailed description when read with the accompanying figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '2\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '3\n is a table related to one or more aspects of the present disclosure.\n \nFIG.', '4\n is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', 'DETAILED DESCRIPTION', 'It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments.', 'Specific examples of components and arrangements are described below to simplify the present disclosure.', 'These are, of course, merely examples and are not intended to be limiting.', 'In addition, the present disclosure may repeat reference numerals and/or letters in the various examples.', 'This repetition is for simplicity and clarity, and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.', 'Systems and methods (e.g., processes, operations, etc.)', 'according to one or more aspects of the present disclosure may be used or performed in association with a well construction system at a wellsite, such as for constructing a wellbore to obtain hydrocarbons (e.g., oil and/or gas) or other natural resources from a subterranean formation.', 'A person having ordinary skill in the art will readily understand that one or more aspects of systems and methods disclosed herein may be utilized in other industries and/or in association with other systems.\n \nFIG.', '1\n is a schematic view of at least a portion of an example implementation of a well construction system \n100\n according to one or more aspects of the present disclosure.', 'The well construction system \n100\n represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'The well construction system \n100\n may be or comprise a well construction rig (i.e., a drilling rig).', 'Although the well construction system \n100\n is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', 'The well construction system \n100\n is depicted in relation to a wellbore \n102\n formed by rotary and/or directional drilling from a wellsite surface \n104\n and extending into a subterranean rock formation \n106\n.', 'The well construction system \n100\n comprises well construction equipment, such as surface equipment \n110\n located at the wellsite surface \n104\n and a drill string \n120\n suspended within the wellbore \n102\n.', 'The surface equipment \n110\n may include a mast, a derrick, and/or another support structure \n112\n disposed over a rig floor \n114\n.', 'The drill string \n120\n may be suspended within the wellbore \n102\n from the support structure \n112\n.', 'The support structure \n112\n and the rig floor \n114\n are collectively supported over the wellbore \n102\n by legs and/or other support structures (not shown).', 'Certain pieces of surface equipment \n110\n may be manually operated (i.e., by hand or via a local control panel) by rig personnel \n195\n (e.g., a roughneck or another human rig operator) located at various portions (e.g., rig floor \n114\n) of the well construction system \n100\n.', 'The drill string \n120\n may comprise a bottom-hole assembly (BHA) \n124\n and means \n122\n for conveying the BHA \n124\n within the wellbore \n102\n.', 'The conveyance means \n122\n may comprise drill pipe, heavy-weight drill pipe (HWDP), wired drill pipe (WDP), tough logging condition (TLC) pipe, and/or other means for conveying the BHA \n124\n within the wellbore \n102\n.', 'A downhole end of the BHA \n124\n may include or be coupled to a drill bit \n126\n.', 'Rotation of the drill bit \n126\n and the weight of the drill string \n120\n collectively operate to form the wellbore \n102\n.', 'The drill bit \n126\n may be rotated by a driver at the wellsite surface \n104\n and/or via a downhole mud motor \n182\n connected with the drill bit \n126\n.', 'The BHA \n124\n may also include one or more downhole tools \n180\n above and/or below the mud motor \n182\n.', 'The downhole tools \n180\n may be or comprise a measurement-while-drilling (MWD) or logging-while-drilling (LWD) tool comprising downhole sensors \n184\n operable for the acquisition of measurement data pertaining to the BHA \n124\n, the wellbore \n102\n, and/or the rock formation \n106\n.', 'The downhole sensors \n184\n may comprise an inclination sensor, a rotational position sensor, and/or a rotational speed sensor, which may include one or more accelerometers, magnetometers, gyroscopic sensors (e.g., micro-electro-mechanical system (MEMS) gyros), and/or other sensors for determining the orientation, position, and/or speed of one or more portions of the BHA \n124\n (e.g., the drill bit \n126\n, the downhole tool \n180\n, and/or the mud motor \n182\n) and/or other portions of the tool string \n120\n relative to the wellbore \n102\n and/or the wellsite surface \n104\n.', 'The downhole sensors \n184\n may comprise a depth correlation tool utilized to determine and/or log position (i.e., depth) of one or more portions of the BHA \n124\n and/or other portions of the tool string \n120\n within the wellbore \n102\n and/or with respect to the wellsite surface \n104\n.', 'One or more of the downhole tools \n180\n and/or another portion of the BHA \n124\n may also comprise a telemetry device \n186\n operable to communicate with the surface equipment \n110\n via downhole telemetry, such as mud-pulse telemetry and/or electro-magnetic telemetry.', 'One or more of the downhole tools \n180\n and/or another portion of the BHA \n124\n may also comprise a downhole control device \n188\n (i.e., a processing device) operable to receive, process, and/or store data received from the surface equipment \n110\n, the downhole sensors \n184\n, and/or other portions of the BHA \n124\n.', 'The control device \n188\n may also store executable computer program code instructions, including for implementing one or more aspects of the operations described herein.', 'The support structure \n112\n may support the driver, such as a top drive \n116\n, operable to connect with an upper end of the drill string \n120\n, and to impart rotary motion \n117\n and vertical motion \n135\n to the drill string \n120\n, including the drill bit \n126\n.', 'However, another driver, such as a kelly and a rotary table (neither own), may be utilized in addition to or instead of the top drive \n116\n to impart the rotary motion \n117\n and vertical motion \n135\n to the drill string \n120\n.', 'The top drive \n116\n and the connected drill string \n120\n may be suspended from the support structure \n112\n via a hoisting system or equipment, which may include a traveling block \n113\n, a crown block \n115\n, and a drawworks \n118\n storing a support cable or line \n123\n.', 'The crown block \n115\n may be connected to or otherwise supported by the support structure \n112\n, and the traveling block \n113\n may be coupled with the top drive \n116\n.', 'The drawworks \n118\n may be mounted on or otherwise supported by the rig floor \n114\n.', 'The crown block \n115\n and traveling block \n113\n comprise pulleys or sheaves around which the support line \n123\n is reeved to operatively connect the crown block \n115\n, the traveling block \n113\n, and the drawworks \n118\n (and perhaps an anchor).', 'The drawworks \n118\n may thus selectively impart tension to the support line \n123\n to lift and lower the top drive \n116\n, resulting in the vertical motion \n135\n.', 'The drawworks \n118\n may comprise a drum, a base, and a motor (e.g., an electric motor) (not shown) operable to drive the drum to rotate and reel in the support line \n123\n, causing the traveling block \n113\n and the top drive \n116\n to move upward.', 'The drawworks \n118\n may be further operable to reel out the support line \n123\n via a controlled rotation of the drum, causing the traveling block \n113\n and the top drive \n116\n to move downward.', 'The top drive \n116\n may comprise a grabber, a swivel (neither shown), elevator links \n127\n terminating with an elevator \n129\n, and a drive shaft \n125\n operatively connected with a motor (e.g., an electric motor) (not shown) of the top drive \n116\n.', 'The drive shaft \n125\n may be selectively coupled with the upper end of the drill string \n120\n and the top drive \n116\n may be selectively operated to rotate the drive shaft \n125\n and the drill string \n120\n coupled with the drive shaft \n125\n.', 'Hence, during drilling operations, the top drive \n116\n, in conjunction with operation of the drawworks \n118\n, may advance the drill string \n120\n into the formation \n106\n to form the wellbore \n102\n.', 'The elevator links \n127\n and the elevator \n129\n of the top drive \n116\n may handle tubulars (e.g., drill pipes, drill collars, casing joints, etc.) that are not mechanically coupled to the drive shaft \n125\n.', 'For example, when the drill string \n120\n is being tripped into or out of the wellbore \n102\n, the elevator \n129\n may grasp the tubulars of the drill string \n120\n such that the tubulars may be raised and/or lowered via the hoisting equipment mechanically coupled to the top drive \n116\n.', 'The well construction system \n100\n may further include a drilling fluid circulation system or equipment operable to circulate fluids between the surface equipment \n110\n and the drill bit \n126\n during drilling and other operations.', 'For example, the drilling fluid circulation system may be operable to inject a drilling fluid from the wellsite surface \n104\n into the wellbore \n102\n via an internal fluid passage \n121\n extending longitudinally through the drill string \n120\n.', 'The drilling fluid circulation system may comprise a pit, a tank, and/or other fluid container \n142\n holding the drilling fluid \n140\n (i.e., drilling mud), and one or more pumps \n144\n operable to move the drilling fluid \n140\n from the container \n142\n into the fluid passage \n121\n of the drill string \n120\n via a fluid conduit \n145\n (e.g., a stand pipe) extending from the pump \n144\n to the top drive \n116\n and an internal passage extending through the top drive \n116\n.', 'During drilling operations, the drilling fluid may continue to flow downhole through the internal passage \n121\n of the drill string \n120\n, as indicated by directional arrow \n158\n.', 'The drilling fluid may exit the BHA \n124\n via ports in the drill bit \n126\n and then circulate uphole through an annular space \n108\n of the wellbore \n102\n defined between an exterior of the drill string \n120\n and the sidewall of the wellbore \n102\n, such flow being indicated by directional arrows \n159\n.', 'In this manner, the drilling fluid lubricates the drill bit \n126\n and carries formation cuttings uphole to the wellsite surface \n104\n.', 'The drilling fluid flowing downhole \n158\n through the internal passage \n121\n may selectively actuate the mud motor \n182\n to rotate the drill bit \n126\n instead of or in addition to the rotation of the drill string \n120\n via the top drive \n116\n.', 'Accordingly, rotation of the drill bit \n126\n caused by the top drive \n116\n and/or mud motor \n182\n may advance the drill string \n120\n through the formation \n106\n to form the wellbore \n102\n.', 'The well construction system \n100\n may further include fluid control equipment \n130\n for maintaining well pressure control and for controlling fluid being discharged from the wellbore \n102\n.', 'The fluid control equipment \n130\n may be mounted on top of a wellhead \n134\n.', 'The drilling fluid flowing uphole \n159\n toward the wellsite surface \n104\n may exit the annulus \n108\n via one or more instances of the fluid control equipment \n130\n, such as a bell nipple, an RCD, and/or a ported adapter (e.g., a spool, cross adapter, a wing valve, etc.).', 'The drilling fluid may then pass through one or more fluid conduits \n147\n to drilling fluid reconditioning equipment \n170\n to be cleaned and reconditioned before returning to the fluid container \n142\n.', 'The drilling fluid reconditioning equipment \n170\n may also separate drill cuttings \n146\n from the drilling fluid into a cuttings container \n148\n.', 'An iron roughneck \n165\n may be positioned on the rig floor \n114\n to make up and break out connections between the drill pipes of the drill string \n120\n.', 'A set of slips \n162\n may be located on the rig floor \n114\n, such as may accommodate therethrough the drill string \n120\n during tubular make up and break out operations, tubular running operations, and drilling operations.', 'The slips \n162\n may be in an open position during running and drilling operations to permit advancement of the drill string \n120\n, and in a closed position to clamp the upper end (e.g., uppermost tubular) of the drill string \n120\n to thereby suspend and prevent advancement of the drill string \n120\n within the wellbore \n102\n, such as during the make up and break out operations.', 'The surface equipment \n110\n of the well construction system \n100\n may also comprise a control center \n190\n from which various portions of the well construction system \n100\n, such as a drill string rotation system (e.g., the top drive \n116\n and/or the rotary table), a hoisting system (e.g., the drawworks \n118\n and the blocks \n113\n, \n115\n), a tubular handling system (e.g., a catwalk and/or a tubular handling device), a drilling fluid circulation system (e.g., the mud pump \n144\n and the fluid conduit \n145\n), a drilling fluid cleaning and reconditioning system (e.g., the drilling fluid reconditioning equipment \n170\n and the containers \n142\n, \n148\n), the well control system (e.g., a BOP stack and/or a choke manifold), and the BHA \n124\n, among other examples, may be monitored and controlled.', 'The control center \n190\n may be located on the rig floor \n114\n or another location of the well construction system \n100\n, such as the wellsite surface \n104\n.', 'The control center \n190\n may comprise a facility \n191\n (e.g., a room, a cabin, a trailer, etc.) containing a control workstation \n197\n, which may be operated by rig personnel \n195\n (e.g., a driller or another human rig operator) to monitor and control various wellsite equipment or portions of the well construction system \n100\n.', 'The control workstation \n197\n may be communicatively connected with a surface control device \n192\n (e.g., a processing device, an equipment controller, etc.), such as may be operable to receive, process, and output information to monitor operations of and provide control to one or more portions of the well construction system \n100\n.', 'For example, the control device \n192\n may be communicatively connected with the various surface equipment \n110\n and downhole equipment \n120\n equipment described herein, and may be operable to receive signals (e.g., sensor data, sensor measurements, etc.)', 'from and transmit signals (e.g., control data, control signals, control commands, etc.) to the equipment to perform various operations described herein.', 'The control device \n192\n may store executable program code, instructions, and/or operational parameters or set-points, including for implementing one or more aspects of methods and operations described herein.', 'The control device \n192\n may be located within and/or outside of the facility \n191\n.', 'The control workstation \n197\n may be operable for entering or otherwise communicating control commands to the control device \n192\n by the rig personnel \n195\n, and for displaying or otherwise communicating information from the control device \n192\n to the rig personnel \n195\n.', 'The control workstation \n197\n may comprise one or more input devices \n194\n (e.g., a keyboard, a mouse, a joystick, a touchscreen, etc.)', 'and one or more output devices \n196\n (e.g., a video monitor, a touchscreen, a printer, audio speakers, etc.).', 'Communication between the control device \n192\n, the input and output devices \n194\n, \n196\n, and the various wellsite equipment \n110\n, \n120\n may be via wired and/or wireless communication means.', 'However, for clarity and ease of understanding, such communication means are not depicted, and a person having ordinary skill in the art will appreciate that such communication means are within the scope of the present disclosure.', 'Communication (i.e., telemetry) between the BHA \n124\n and the controller \n192\n may be via mud-pulse telemetry (i.e., pressure pulses) sent through the drilling fluid flowing within a fluid passage \n121\n of the drill string \n120\n.', 'For example, the downhole telemetry device \n186\n may comprise a modulator selectively operable to modulate the pressure (i.e., cause pressure changes, pulsations, and/or fluctuations) of the drilling fluid flowing within the fluid passage \n121\n of the downhole tool \n180\n to transmit downhole data (i.e., downhole measurements) received from the downhole controller \n188\n, the downhole sensors \n184\n, and/or other portions of the BHA \n124\n in the form of pressure pulses.', 'The modulated pressure pulses travel uphole along the drilling fluid through the fluid passage \n121\n, the top drive \n116\n, and the fluid conduit \n145\n to be detected by an uphole telemetry device \n149\n.', 'The uphole telemetry device \n149\n may comprise a pressure transducer or sensor in contact with the drilling fluid being pumped downhole.', 'The uphole telemetry device \n149\n may thus be disposed along or in connection with the fluid conduit \n145\n, the top drive \n116\n, and/or another conduit or device transferring or in contact with the drilling fluid being pumped downhole.', 'The uphole telemetry device \n149\n may be operable to detect the modulated pressure pulses, convert the pressure pulses to electrical signals, and communicate the electrical signals to the controller \n192\n.', 'The controller \n192\n may be operable to interpret the electrical signals to reconstruct the downhole data transmitted by the downhole telemetry device \n186\n.', 'Well construction systems within the scope of the present disclosure may include more or fewer components than as described above and depicted in \nFIG.', '1\n.', 'Additionally, various equipment and/or subsystems of the well construction system \n100\n shown in \nFIG.', '1\n may include more or fewer components than as described above and depicted in \nFIG. \n1\n.', 'For example, various engines, motors, hydraulics, actuators, valves, and/or other components not explicitly described herein may be included in the well construction system \n100\n, and are within the scope of the present disclosure.', 'FIG.', '2\n is a schematic view of at least a portion of an example implementation of a control system \n200\n operable to monitor and control operation of a drill string driver (e.g., a top drive) according to one or more aspects of the present disclosure.', 'The control system \n200\n may form a portion of or operate in conjunction with the well construction system \n100\n shown in \nFIG.', '1\n, and thus may comprise one or more features of the well construction system \n100\n shown in \nFIG.', '1\n, including where indicated by the same reference numerals.', 'Accordingly, the following description refers to \nFIGS.', '1\n and \n2\n, collectively.', 'The top drive \n116\n may comprise an electric motor \n202\n operatively connected to the drive shaft \n125\n.', 'During drilling operations, the drive shaft \n125\n may be coupled with the upper end of the drill string \n120\n operable to drill the wellbore \n102\n.', 'The drill string \n120\n may comprise the BHA \n124\n at the lower end thereof.', 'The BHA \n124\n may comprise the drill bit \n126\n, the mud motor \n182\n operable to rotate the drill bit \n126\n, and one or more downhole tools \n180\n above and/or below the mud motor \n182\n.', 'One or more of the downhole tools \n180\n may be or comprise a MWD or LWD tool comprising downhole sensors \n184\n for the acquisition of measurements (i.e., sensor data) pertaining to the wellbore \n102\n, the formation \n106\n, and/or the BHA \n124\n.', 'For example, the downhole sensors \n184\n may be or comprise a downhole rotation sensor \n184\n operatively connected with and/or disposed in association with the drill bit \n126\n, the downhole motor \n182\n, and/or other portions of the BHA \n124\n.', 'The rotation sensor \n184\n may be operable to output or otherwise facilitate downhole rotational measurements (i.e., rotational data) indicative of rotational (i.e., angular) position of the drill bit \n126\n.', 'The rotational measurements may be further indicative of rotational distance (e.g., number of rotations), rotational speed, and rotational acceleration of the drill bit \n126\n.', 'The rotation sensor \n184\n may be or comprise, for example, at least one of an encoder, a rotary potentiometer, and a rotary variable-differential transformer (RVDT).', 'The control system \n200\n may comprise a surface rotation sensor \n208\n operatively connected with and/or disposed in association with the top drive \n116\n.', 'The rotation sensor \n208\n may be operable to output or otherwise facilitate surface rotational measurements (i.e., rotational data) indicative of rotational position of the drive shaft \n125\n of the top drive \n116\n.', 'The rotation sensor \n208\n may be disposed or installed in association with, for example, the electric motor \n202\n to monitor rotational position of the electric motor \n202\n, and thus the drive shaft \n125\n.', 'The rotation sensor \n208\n may be disposed or installed in association with, for example, the drive shaft \n125\n to monitor rotational position of the drive shaft \n125\n.', 'The rotational measurements may be further indicative of rotational distance, rotational speed, and rotational acceleration of the drive shaft \n125\n of the top drive \n116\n.', 'The rotation sensor \n208\n may be or comprise, for example, at least one of an encoder, a rotary potentiometer, and an RVDT.', 'The control system \n200\n may further comprise one or more electrical devices, each operable to output or otherwise facilitate torque measurements (i.e., torque data) indicative of torque generated, output, or facilitated by the top drive \n116\n.', 'For example, the control system \n200\n may comprise a torque sensor \n210\n (e.g., a torque sub, a load cell, etc.) operable to output or otherwise facilitate torque measurements indicative of torque that was output by the drive shaft \n125\n of the top drive \n116\n to the drill string \n120\n.', 'The torque sensor \n210\n may be mechanically connected or otherwise disposed between the drive shaft \n125\n and the upper end of the drill string \n120\n, such as may permit the torque sensor \n210\n to transfer and measure torque.', 'The torque sensor \n210\n may also be or comprise a rotation sensor operable to facilitate determination of rotational position, rotational distance, rotational speed, and rotational acceleration of the drive shaft \n125\n.', 'The control system \n200\n may comprise one or more control devices \n204\n (e.g., equipment controllers, information processing devices, etc.), such as, for example, variable frequency drives (VFDs), programmable logic controllers (PLCs), computers (PCs), industrial computers (IPC), or other equipment controllers furnished with control logic, communicatively connected with various sensors and actuators of the BHA \n124\n, the top drive \n116\n, and/or other portions of the control system \n200\n.', 'One or more of the control devices \n204\n may be in real-time communication with such sensors and actuators, and utilized to monitor and/or control various portions, components, and equipment of the top drive \n116\n and/or the BHA \n124\n.', 'For example, one or more of the control devices \n204\n may be communicatively connected with the rotation sensor \n208\n and operable to receive the rotational speed measurements \n232\n facilitated by the rotation sensor \n208\n.', 'One or more of the control devices \n204\n may be communicatively connected with the torque sensor \n210\n and operable to receive the torque measurements \n234\n facilitated by the torque sensor \n210\n.', 'One or more of the control devices \n204\n may be communicatively connected with a downhole rotation sensor \n184\n and operable to receive downhole rotational speed measurements \n236\n indicative of rotational speed of the drill bit \n126\n and/or another portion of the BHA \n124\n.', 'Communication between the downhole rotation sensor \n184\n and the control devices \n204\n may be via mud-pulse telemetry \n237\n sent by the downhole telemetry device \n186\n to the surface telemetry device \n149\n through the drilling fluid flowing within the fluid passage \n121\n of the drill string \n120\n.', 'Communication between one or more of the control devices \n204\n, the surface telemetry device \n149\n, and the sensors \n208\n, \n210\n, may be via wired and/or wireless communication means \n206\n.', 'A person having ordinary skill in the art will appreciate that such communication means are within the scope of the present disclosure.', 'The control devices \n204\n may be divided into or otherwise comprise hierarchical control levels or layers.', 'A first control level may comprise a first control device \n212\n (i.e., an actuator control device), such as a VFD operable to directly power and control (i.e., drive) the electric motor \n202\n of the top drive \n116\n.', 'The first control device \n212\n may store and be operable to execute corresponding computer program code instructions \n220\n, which when executed, may cause the first control device \n212\n to monitor and/or control the electric motor \n202\n.', 'The first control device \n212\n may be electrically connected with the electric motor \n202\n and/or supported by or disposed in association with the top drive \n116\n.', 'The first control device \n212\n may be operable to control rotational speed and torque of the electric motor \n202\n, and thus control rotational speed of and torque output by the drive shaft \n125\n of the top drive \n116\n.', 'The first control device \n212\n may control electrical power (e.g., current, voltage, and/or frequency) delivered to the electric motor \n202\n.', 'The first control device \n212\n may be further operable to calculate or determine torque and/or rotational speed generated or output by the electric motor \n202\n, such as based on the electrical power (e.g., current, voltage, and/or frequency) delivered to the electric motor \n202\n.', 'The first control device \n212\n may thus be operable to output or otherwise facilitate the torque measurements \n234\n indicative of torque output to the drill string \n120\n by the top drive \n116\n.', 'The first control device \n212\n may be communicatively connected with one or more of the other control devices \n204\n and operable to output the torque measurements \n234\n to one or more of the other control devices \n204\n.', 'The first control device \n212\n may be further operable to output or otherwise facilitate rotational speed measurements \n232\n and/or acceleration measurements indicative of rotational speed and/or acceleration of the top drive \n116\n.', 'A second control level may comprise a second control device \n214\n (i.e., a local or direct control device), such as a PLC operable to control the electric motor \n202\n of the top drive \n116\n via the first control device \n212\n.', 'The second control device \n214\n may store and be operable to execute corresponding computer program code instructions \n220\n, which when executed, may cause the second control device \n214\n to control the motor \n202\n and/or other actuators communicatively connected to the second control device \n214\n.', 'The second control device \n214\n may be a local control device disposed in association with the top drive \n116\n or another portion of the drill string drive system and operable to control the top drive \n116\n and/or other portions of the drill string drive system.', 'The second control device \n214\n may be communicatively connected with the first control device \n212\n and operable to receive the torque measurements \n234\n from the first control device \n212\n and output control commands (i.e., control data or signals) to the first control device \n212\n to control the rotational position, rotational distance, rotational speed, and/or torque of the motor \n202\n, and thus the drive shaft \n125\n of the top drive \n116\n.', 'The second control device \n214\n may be communicatively connected with the rotation sensor \n208\n and operable to receive rotational measurements, including the position measurements, the rotational distance measurements, the rotational speed measurements \n232\n, and/or the rotational acceleration measurements facilitated by the rotation sensor \n208\n.', 'The second control device \n214\n may be further communicatively connected with the torque sensor \n210\n and operable to receive the torque measurements \n234\n facilitated by the torque sensor \n210\n.', 'The second control device \n214\n may also be communicatively connected with the surface telemetry device \n149\n and operable to receive the rotational speed measurements \n236\n facilitated by the rotation sensor \n184\n.', 'A third control level may comprise a third control device \n216\n (i.e., a central or coordinated control device), such as a PC, an IPC, and/or another processing device.', 'The third control device \n216\n may store and be operable to execute corresponding computer program code instructions \n220\n, which when executed, may cause the third control device \n216\n to control the electric motor \n202\n and/or other actuators communicatively connected to the third control device \n216\n.', 'The program code instructions \n220\n may include high level programming languages, such as C, and C++, among other examples, and may be used with program code instructions running in a real time operating system (RTOS).', 'The third control device \n216\n may be a system-wide control device operable to control a plurality of devices and/or subsystems of the well construction system \n100\n.', 'The third control device \n216\n may be or form at least a portion of the control device \n192\n shown in \nFIG.', '1\n.', 'The third control device \n216\n may be operable to control the electric motor \n202\n of the top drive \n116\n via the first and/or second control devices \n212\n, \n214\n.', 'The third control device \n216\n may be communicatively connected with the second control device \n214\n and operable to receive the torque measurements \n234\n and the rotational speed measurements \n232\n from the first control device \n212\n via the second control device \n214\n.', 'The third control device \n216\n may also or instead be communicatively connected directly with the first control device \n212\n and operable to receive the torque measurements \n234\n and the rotational speed measurements \n232\n directly from the first control device \n212\n.', 'The third control device \n216\n may also or instead be communicatively connected with the rotation sensor \n208\n and operable to receive the rotational position measurements, the rotational distance measurements, the rotational speed measurements \n232\n, and/or the rotational acceleration measurements facilitated by the rotation sensor \n208\n.', 'The third control device \n216\n may also or instead be communicatively connected with the torque sensor \n210\n and operable to receive the torque measurements \n234\n facilitated by the torque sensor \n210\n.', 'The third control device \n214\n may also or instead be communicatively connected with the surface telemetry device \n149\n and operable to receive the rotational speed measurements \n236\n facilitated by the rotation sensor \n184\n.', 'The third control device \n216\n may be operable to output control commands (i.e., control data or signals) directly to the first control device \n212\n or indirectly via the second control device \n214\n to control the rotational position, the rotational distance, the rotational speed, and/or the torque of the motor \n202\n.', 'The present disclosure is further directed to various implementations of systems and methods (e.g., processes, operations, etc.) for monitoring and controlling drilling operations to increase performance (e.g., increase rate of penetration) of the drilling operations, such as by reducing stick-slip of the drill string \n120\n.', 'For example, the control system \n200\n according to one or more aspects of the present disclosure may be used in association with the well construction system \n100\n.', 'The control system \n200\n may be used to control the drill string \n120\n during drilling operations for drilling the wellbore \n102\n.', 'The control system \n200\n may include, utilize, or otherwise be implemented by hardware and/or the computer program code instructions \n220\n for controlling rotation of the drill string \n120\n to prevent, mitigate, inhibit, or otherwise reduce rotational waves (e.g., torsional vibrations, oscillations, and/or resonances) at the fundamental frequency and higher order resonant frequencies that are traveling along the drill string \n120\n caused by stick-slip at the lower end and/or other locations along the drill string \n120\n.', 'The control system \n200\n may control the top drive \n116\n (or another driver, such as a rotary table) operable to rotate the drill string \n120\n to drill the wellbore \n102\n.', 'The control system \n200\n may comprise one or more control devices \n204\n each comprising a processor and a memory storing the executable computer program code instructions \n220\n, wherein the instructions \n220\n comprise a stick-slip algorithm \n222\n for causing the top drive \n116\n to rotate the drill string \n120\n to perform drilling operations while reducing the rotational waves travelling along the drill string \n120\n.', 'One or more of the control devices \n204\n may receive input data \n226\n, \n228\n, \n230\n and incorporate (i.e., insert) the input data \n226\n, \n228\n, \n230\n into the stick-slip algorithm \n222\n to complete and/or configure the stick-slip algorithm \n222\n.', 'The control devices \n204\n may also receive the sensor measurements \n232\n, \n234\n, \n236\n indicative of operational status of the drill string \n120\n to update the stick-slip algorithm \n222\n and measure the reduction of rotational waves traveling along the drill string \n120\n.', 'During the drilling operations, the control devices \n204\n may output an intended rotational speed control command \n224\n (i.e., intended rotational speed set-point) and/or an intended torque control command \n244\n (i.e., intended torque set-point) based on the input data \n226\n, \n228\n, \n230\n and sensor measurements \n232\n, \n234\n, \n236\n, thereby causing the top drive \n116\n to vary rotational speed of and/or torque input to the drill string \n120\n based on the rotational speed command \n224\n and/or the torque command \n244\n, respectively, to reduce amplitude of the rotational waves traveling along the drill string \n120\n.\n \nSystems and methods according to one or more aspects of the present disclosure may be caused or otherwise facilitated by the computer program code instructions \n220\n comprising the stick-slip algorithm \n222\n stored on (i.e., entered, installed, programmed, etc.)', 'one or more of the control devices \n204\n of the control system \n200\n.', 'The computer program code instructions \n220\n according to one or more aspects of the present disclosure may be, comprise, or be implemented in software, firmware, middleware, microcode, hardware description languages, or a combination thereof, which may be stored in a machine readable medium, such as a memory medium, of one or more of the control devices \n204\n.', 'The computer program code instructions \n220\n may represent or otherwise implement a procedure, a function, a subprogram, a program, an algorithm, an equation, a routine, a subroutine, a module, a software package, a class, or a combination of instructions, data structures, or program statements.', 'Portions of the computer program code instructions \n220\n may be coupled together or with a hardware circuit by passing and/or receiving information, data, arguments, parameters, or memory contents.', 'Information, arguments, parameters, and/or data may be passed, forwarded, or transmitted via a suitable means including memory sharing, message passing, token passing, and/or network transmission.', 'As described herein, the rotational waves may travel in upward (i.e., uphole) and downward (i.e., downhole) directions along the drill string \n120\n while the drill string \n120\n is rotated within the wellbore \n102\n.', 'The upward traveling rotational waves may be reflected at the surface \n104\n (e.g., by the top drive \n116\n) forming downward traveling rotational waves, which may cause or exacerbate rotational resonances and repetitive stick-slip motion along and/or at the lower end of the drill string \n120\n.', 'In a drill string \n120\n having larger diameter drill pipe near the surface \n104\n, some of the upward traveling rotational waves may be reflected before they reach the surface \n104\n.', 'The downward traveling rotational waves in the drill string \n120\n may also include those initiated by the top drive \n116\n (or another driver) while the top drive \n116\n rotates the drill string \n120\n.', 'The downward traveling rotational waves produced by the top drive \n116\n may drive the drill bit \n126\n through the formation \n106\n.', 'Thus, the downward traveling energy comprises intended downward traveling energy that is utilized to drive the drill bit \n126\n and unintended (i.e., undesirable) downward traveling energy that causes or exacerbates the rotational waves and/or stick-slip motion of the drill string \n120\n.', 'The stick-slip algorithm \n222\n according to one or more aspects of the present disclosure may cause or otherwise facilitate methods, processes, and/or operations described herein.', 'For example, the stick-slip algorithm \n222\n may facilitate control of the top drive \n116\n (or another driver) to control rotation of the drill string \n120\n to perform the drilling operations while reducing rotational waves traveling along the drill string \n120\n.', 'The stick-slip algorithm \n222\n, when executed by one or more of the control devices \n204\n, may thus facilitate control of the rotational waves traveling along the drill string \n120\n and other tubular strings, such as liner and casing strings, during well completion operations.', 'For example, the stick-slip algorithm \n222\n may cause the top drive \n116\n to vary rotational speed of the drill string \n120\n to absorb, dampen, or otherwise reduce the upward traveling rotational waves, thereby preventing, mitigating, inhibiting, or otherwise reducing corresponding reflected downward traveling rotational waves, resonances, and other vibrations along and/or at the lower end of the drill string \n120\n and the resulting stick-slip motion of the drill string \n120\n.', 'The stick-slip algorithm \n222\n may be utilized to achieve and maintain an intended average (i.e., nominal) rotational speed of the upper end of the drill string \n120\n (i.e., at the top drive \n116\n) while reducing or minimizing vibrations and/or stick-slip motion of the drill string \n120\n.', 'Accordingly, one or more control devices \n204\n of the control system \n200\n may be operable to execute or otherwise utilize the stick-slip algorithm \n222\n to determine an intended rotational speed and/or torque of the top drive \n116\n that reduces unintended rotational waves travelling along the drill string \n120\n.', 'The stick-slip algorithm \n222\n according to one or more aspects of the present disclosure may be derived and implemented via mathematical equations modeling or otherwise characterizing portions of the drilling equipment, such as the drill string \n120\n and/or the top drive \n116\n, and utilized to control the top drive \n116\n.', 'For example, relationship between rotational speed and torque with respect to the drill string \n120\n and the top drive \n116\n may be characterized or otherwise expressed as set forth below in Equation (1), which may be used to control rotational speed of the top drive \n116\n.', 'v\n \n\u2061\n \n \n(\n \nt\n \n)\n \n \n \n=\n \n \n \n \nv\n \n0\n \n \n\u2061\n \n \n(\n \nt\n \n)\n \n \n \n+\n \n \nr\n \n\u2061\n \n \n(\n \nt\n \n)', '+\n \n \n \n(\n \n \n \n \nk\n \n1\n \n \n\u2062\n \nv\n \n \n-\n \n \n \nk\n \n2\n \n \n\u2062\n \n \n \nT\n \nic\n \n \nz\n \n \n \n \n)', 'f\n \n \n \n \n \n \n \n(\n \n1\n \n)\n \n \n \n \n \n \n \n where v(t) is the intended rotational speed control command \n224\n (i.e., control signal) of the top drive \n116\n, v\n0\n(t) is an intended average (nominal) rotational speed set-point \n226\n (i.e., average rotational speed input) of the drill string \n120\n at the surface \n104\n that is to be imparted by the top drive \n116\n rotating the drill string \n120\n to drill the wellbore \n102\n, r(t) is a residual correction integral term used to account for the long term average of the intended rotational speed control command v(t), v is a present measured rotational speed (i.e., present rotational speed input) of the top drive \n116\n, T\nic \nis a present measured or calculated estimate value of inertia-corrected torque (i.e., present inertia-corrected torque input) applied by the top drive \n116\n to the drill string \n120\n, and z is a measured or calculated estimate of compliance (i.e., present compliance input) of the drill string \n120\n.', 'f signifies a filter being applied to the quantity inside the parentheses.', 'k\n1 \nand k\n2 \nare dimensionless speed and torque proportionality constants, used to vary sensitivity of the intended rotational speed control command v(t) to present rotational speed and torque measurements or estimates, respectively.', 'The residual correction integral r(t) may be calculated via Equation (2) set forth below.', 'r\n(\nt\n)=∫\nk\n(\nv\n0\n(\nt\n)−\nv\n(\nt\n))', 'dt\n\u2003\u2003(2) \n where k is a speed integral constant comprising dimensions of 1/time.', 'The present inertia-corrected torque T\nic \napplied by the top drive \n116\n to the drill string \n120\n can be measured by a torque sensor (e.g., the torque sub \n210\n).', 'The present inertia-corrected torque T\nic \ncan be calculated via Equation (3) set forth below.', 'T\n \nic\n \n \n=\n \n \n \nT\n \ntd\n \n \n-\n \n \n \nk\n \ntdj\n \n \n\u2062\n \n \nJ\n \ntd\n \n \n\u2062\n \n \ndv\n \ndt\n \n \n \n \n \n \n \n \n(\n \n3\n \n)\n \n \n \n \n \n \n \n where T\ntd \nis a top drive torque, which is torque exerted by the top drive \n116\n, which can be measured by measuring electrical current drawn by the electric motor \n202\n driving the top drive \n116\n.', 'J\ntd \nis a rotational inertia of the top drive \n116\n, and \n \n \n \n \n \ndv\n \ndt\n \n \n \n \n is a time rate of change of the measured rotational speed (i.e., rotational acceleration) of the top drive \n116\n, which may be low-pass filtered too remove high frequency noise.', 'k\ntdj \nis a dimensionless inertial compensation constant, which may be used to vary sensitivity of the present inertia-corrected torque T\nic \nto the rotational inertia J\ntd \nof the top drive \n116\n and the time rate of change of the measured rotational speed \n \n \n \n \n \n \nd\n \n\u2062\n \n \n \n \n\u2062\n \nv\n \n \ndt\n \n \n \n \n of the top drive \n116\n.', 'The control loop characterized by Equations (1)-(3) used to output the intended rotational speed control command \n224\n to the top drive \n116\n may be or comprise a portion of the stick-slip algorithm \n222\n stored on and executed by the third control device \n216\n.', 'The intended rotational speed control command v(t) output by Equation (1) set forth above may be sent to a speed control loop portion of a stick-slip algorithm \n222\n of the control system \n200\n for controlling the top drive \n116\n.', 'The speed control loop may be characterized or otherwise expressed as set forth below in Equation (4), which may be used to control torque output by the top drive \n116\n.', 'T\nsp\n=k\np\n(\nv\n0\n(\nt\n)−\nv\n(\nt\n))', '+∫\nk\ni\n(\nv\n0\n(\nt\n)−\nv\n(\nt\n))', 'dt\n\u2003\u2003(4) \n where T\nsp \nis the intended torque control command \n244\n (i.e., control signal) of the electric motor \n202\n that is to be applied to the top drive \n116\n.', 'k\np \nand k\ni \nare proportional and integral constants, respectively.', 'The control loop characterized by Equation (4) used to output the intended torque control command \n244\n to the top drive \n116\n may be or comprise a portion of the stick-slip algorithm \n222\n stored on and executed by the first control device \n212\n.', 'Thus, the manner in which the stick-slip algorithm \n222\n characterized or otherwise expressed by Equations (1)-(4) controls rotation of the top drive \n116\n can be controlled via a plurality of numerical parameters \n230\n, such as the constants of the Equations (1)-(4).', 'The numerical parameters \n230\n my include the speed proportionality constant k\n1\n, the torque proportionality constant k\n2\n, the speed integral constant k, the inertial compensation constant k\ntdj\n, the speed control loop proportional constant k\np\n, the speed control loop integral constant k\ni\n, and one or more filtering parameters f, such as a bandpass filter that can be applied to control and/or feedback signals to control or vary an upper and a lower frequency of control and/or feedback signals.', 'Because the numerical parameters \n230\n control the manner in which the stick-slip algorithm \n222\n controls rotation of the top drive \n116\n, such numerical parameters \n230\n may also be referred to as control parameters.', 'The stick-slip algorithm \n222\n within the scope of the present disclosure, such as implemented by one or more of the Equations (1)-(4), may be contained within or captured by the computer program code instructions \n220\n, which may be executed or otherwise implemented by one or more of the control devices \n204\n of the control system \n200\n, such as by determining and outputting control commands \n224\n, \n244\n (i.e., control data or signals) indicative of intended rotational speed v(t) and intended torque T\nsp \nof the top drive \n116\n.', 'However, it is to be understood that the stick-slip algorithm \n222\n implemented by one or more of the Equations (1)-(4) is merely an example stick-slip algorithm.', 'Therefore, it is to be further understood that the control system \n200\n within the scope of the present disclosure may utilize or otherwise implement computer program code instructions \n220\n comprising other stick-slip algorithms (i.e., implemented by other equations) for controlling rotational speed and/or torque of the top drive \n116\n to reduce rotational waves (e.g., torsional vibrations, oscillations, and/or resonances) traveling along the drill string \n120\n.', 'It is to be also understood that a stick-slip algorithm \n222\n within the scope of the present disclosure may be combined with or work in association with one or more other algorithms to control rotational speed and/or torque of the top drive \n116\n or another driver of the drill string \n120\n.', 'The computer program code instructions \n220\n comprising the stick-slip algorithm \n222\n may be stored on (i.e., entered, installed, programmed, etc.) and executed by one or more of the control devices \n204\n.', 'For example, a portion of the stick-slip algorithm \n222\n stored on the third control device \n216\n may be implemented by one or more of the Equations (1)-(3) to determine (i.e., calculate) and output the intended rotational speed control command \n224\n (i.e., control signal) for controlling the rotational speed (e.g., revolutions per minute (RPM)) of the top drive \n116\n, and thus rotational speed of the upper end of the drill string \n120\n.', 'Prior to and/or during drilling operations, the third control device \n216\n may receive various input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n, incorporate (i.e., insert) the input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n into the stick-slip algorithm \n222\n to complete and/or configure the stick-slip algorithm \n222\n, and then execute the stick-slip algorithm \n222\n based on the received input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n to determine the intended rotational speed control command \n224\n.', 'The intended rotational speed control command \n224\n may be or comprise the intended rotational speed control command v(t) determined via Equations (1)-(3).', 'The input data may comprise an intended average (i.e., nominal) rotational speed set-point \n226\n of the top drive \n116\n to control the average rotational speed of the upper end of the drill string \n120\n.', 'The intended average rotational speed set-point \n226\n may be or comprise the intended average rotational speed set-point v\n0\n(t) described above in association with one or more of the Equations (1)-(3).', 'The input data may further comprise equipment physical specifications \n228\n (e.g., mechanical properties or characteristics) of the drilling equipment, including physical specifications of the top drive \n116\n and/or the drill string \n120\n.', 'For example, the equipment physical specifications \n228\n may comprise the compliance z of the drill string \n120\n and the rotational inertia J\ntd \nof the top drive \n116\n, as described above in association with one or more of the Equations (1)-(3).', 'The drill string compliance z may be determined prior to being transmitted to the third control device \n216\n based on certain drill string specifications, and then transmitted to the third control device \n216\n.', 'The input data may further comprise the numerical parameters \n230\n (e.g., terms, coefficients, constants, variables, etc.) of the stick-slip algorithm \n222\n.', 'For example, the numerical parameters \n230\n may comprise the stick-slip algorithm constants k, k\n1\n, k\n2\n, k\np\n, k\ni\n, and k\ntdj \ndescribed above in association with one or more of the Equations (1)-(4).', 'The input data \n226\n, \n228\n, \n230\n may be entered into the third control device \n216\n by personnel (e.g., rig personnel, research and development personnel, engineers, etc.)', 'using the control workstation \n197\n or another HMI, such as a keyboard, communicatively connected with the third control device \n216\n.', 'The input data \n226\n, \n228\n, \n230\n may also or instead be entered into the third control device \n216\n automatically by another control device.', 'The input data may also comprise present (i.e., real-time) operational measurements of the top drive \n116\n, such as present rotational speed measurements \n232\n of the top drive \n116\n facilitated by the rotation sensor \n208\n and present torque measurements \n234\n (e.g., present inertia-corrected torque measurements) of the top drive \n116\n facilitated by the torque sensor \n210\n.', 'The rotational speed measurements \n232\n and the torque measurements \n234\n may be or comprise the present rotational speed v of the top drive \n116\n and the present value of inertia-corrected torque T\nic \nof the top drive \n116\n, respectively, as described above in association with one or more of the Equations (1)-(4).', 'The torque measurements \n234\n may also or instead be derived based on Equation (3) by solving for the present value of inertia-corrected torque T\nic\n.', 'For example, top drive torque T\ntd \ncan be derived based on electrical current drawn by the electric motor \n202\n driving the top drive \n116\n.', 'Information indicative of the top drive torque T\ntd \nand/or electrical current drawn by the electric motor \n202\n may be output by the first control device \n212\n and transmitted to the third control device \n216\n.', 'The third control device \n216\n may then calculate the present value of inertia-corrected torque T\nic \nc based on the top drive torque T\ntd\n, the rotational inertia J\ntd \nof the top drive \n116\n, and the time rate of change\n \n \n \n \n \ndv\n \ndt\n \n \n \n \n of the rotational speed measurements \n232\n of the top drive \n116\n.', 'When the stick-slip algorithm \n222\n is completed and/or configured with the input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n, the third control device \n216\n may execute the stick-slip algorithm \n222\n based on the input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n to determine the intended rotational speed control command \n224\n.', 'The determined intended rotational speed control command \n224\n may then be output (i.e., communicated) directly to the first control device \n212\n associated with the motor \n202\n of the top drive \n116\n or indirectly via the second control device \n214\n.', 'The intended rotational speed control command \n224\n may be or comprise a proportional and integral (PI) gain value to be used by the first control device \n212\n utilizing PI rotational speed control.', 'Although the control system \n200\n shows the algorithm \n222\n stored and executed by the third control device \n216\n, it is to be understood that at least a portion of the algorithm \n222\n may also or instead be stored and executed by the first control device \n212\n and/or the second control device \n214\n.', 'Accordingly, the first control device \n212\n and/or the second control device \n214\n may also or instead receive the input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n, incorporate the input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n into the stick-slip algorithm \n222\n to complete and/or configure the stick-slip algorithm \n222\n, and then execute the stick-slip algorithm \n222\n to determine and output the intended rotational speed control command \n224\n.', 'At least a portion of the computer program code instructions \n220\n comprising the stick-slip algorithm \n222\n may be stored on (i.e., entered, installed, programmed, etc.) and executed by the first control device \n212\n.', 'For example, a portion of the stick-slip algorithm \n222\n comprising Equation (4) may be stored on and executed by the first control device \n212\n.', 'The portion of the stick-slip algorithm \n222\n comprising Equation (4) may determine (i.e., calculate or compute) and output an intended torque control command \n244\n (i.e., a control signal or set-point) indicative of torque that is to be applied by the top drive \n116\n to the upper end of the drill string \n120\n.', 'The first control device \n212\n may receive various input data, incorporate the input data into the stick-slip algorithm \n222\n to complete and/or configure the stick-slip algorithm \n222\n, and then execute the stick-slip algorithm \n222\n based on the received input data to determine the intended torque control command \n244\n.', 'The intended torque control command \n244\n may be or comprise the intended torque control command T\nsp \ndetermined via Equation (4).', 'The first control device \n212\n may receive from the third control device \n216\n both the intended rotational speed control command \n224\n determined by the third control device \n216\n and the intended average rotational speed set-point \n226\n of the top drive \n116\n.', 'The first control device \n212\n may also receive additional numerical parameters \n230\n to configure the stick-slip algorithm \n222\n.', 'For example, the numerical parameters \n230\n received by the first control device \n212\n may include one or more numerical parameters of the stick-slip algorithm \n222\n, such as the stick-slip algorithm constants k\np \nand k\ni \ndescribed above in association with the Equation (4).', 'As described above, the numerical parameters \n230\n may be entered into the third control device \n216\n by personnel using the control workstation \n197\n or another HMI, such as a keyboard, communicatively connected with the third control device \n216\n and then transmitted to the first control device \n212\n from the third control device \n216\n.', 'When the stick-slip algorithm \n222\n is completed and/or configured with the input data \n224\n, \n226\n, \n230\n, the first control device \n212\n may execute the stick-slip algorithm \n222\n based on the input data \n224\n, \n226\n, \n230\n to determine and output the intended torque control command \n244\n.', 'The first control device \n212\n may then operate or otherwise control the motor \n202\n of the top drive \n116\n to cause the motor \n202\n to output a level of torque indicated by the intended torque control command \n244\n, and thereby control the rotational speed of the drill string \n120\n to reduce the rotational waves traveling along the drill string \n120\n while performing the drilling operations.', 'The third control device \n216\n may continually receive the rotational speed measurements \n232\n and the torque measurements \n234\n, and use such measurements \n232\n, \n234\n as feedback input data (i.e., feedback signals or information).', 'The third control device \n216\n may then continually update (e.g., recalculate) the intended rotational speed control command \n224\n via the stick-slip algorithm \n222\n based on the measurements \n232\n, \n234\n.', 'The updated intended rotational speed control command \n224\n may then be communicated to the first control device \n212\n directly or via the second control device \n214\n.', 'The first control device \n212\n may then continually update the intended torque control command \n244\n via the stick-slip algorithm \n222\n based on the updated intended rotational speed control command \n224\n.', 'The first control device \n212\n may then operate or otherwise control the motor \n202\n of the top drive \n116\n to cause the motor \n202\n to output level of torque as indicated by the updated intended torque control command \n244\n to reduce the rotational waves traveling along the drill string \n120\n while performing the drilling operations.', 'Thus, the third control device \n216\n may continually receive the updated rotational speed measurements \n232\n and the updated torque measurements \n234\n, such as may permit the first control device \n212\n to continually update the intended torque control command \n244\n to continually change the torque output by the motor \n202\n to continually change the rotational speed of the drill string \n120\n to reduce the rotational waves traveling along the drill string \n120\n while performing the drilling operations.', 'As described above, the manner in which the stick-slip algorithm \n222\n characterized or otherwise expressed by Equations (1)-(4) controls rotation of the top drive \n116\n and the drill string \n120\n can be controlled by controlling (e.g., changing, adjusting, etc.)', 'the numerical parameters \n230\n of the stick-slip algorithm \n222\n.', 'The numerical parameters \n230\n may be or comprise the constants of the stick-slip algorithm Equations (1)-(4), including the speed proportionality constant k\n1\n, the torque proportionality constant k\n2\n, the speed integral constant k, the inertial compensation constant k\ntdj\n, the speed control loop proportional constant k\np\n, the speed control loop integral constant k\ni\n, and one or more filtering parameters f, such as a bandpass filter that can be applied to control and/or feedback signals to control or vary an upper and a lower frequency of control and/or feedback signals.', 'An optimal set of numerical parameters \n230\n may be selected to optimize performance of the stick slip algorithm \n222\n to reduce the rotational waves traveling along the drill string \n120\n in an optimal manner while performing the drilling operations.', 'Accordingly, the present disclosure is further directed to various implementations of systems and methods (e.g., processes, operations, etc.) for selecting or otherwise determining an optimal set of the numerical parameters \n230\n to optimize performance of the stick-slip algorithm \n222\n.', 'An optimal set of numerical parameters of a stick-slip algorithm may be selected based on actual (i.e., measured) drilling performance.', 'For example, performance of a stick-slip algorithm may be monitored during a drilling test run of the control system \n200\n utilizing the stick-slip algorithm \n222\n on an actual drilling rig while performing drilling operations.', 'During the drilling test run, drilling operations may be performed while the numerical parameters \n230\n of the stick-slip algorithm \n222\n are changed (i.e., varied) and behavior (i.e., operational parameters) of the drill string \n120\n is monitored.', 'The personnel and/or a control device may analyze the behavior of the drill string \n120\n while the numerical parameters \n230\n change to determine the performance of the stick-slip algorithm \n222\n in terms of ability to reduce the amplitude of rotational waves traveling along the drill string \n120\n caused by stick-slip while utilizing each different set of numerical parameters \n230\n to complete and/or configure the stick-slip algorithm \n222\n.', 'The behavior of the drill string \n120\n can be defined or characterized by monitoring (i.e., measuring) for fluctuations operational parameters, such as downhole rotational speed and/or surface torque.', 'The downhole rotational speed may be measured via the downhole rotational speed sensor \n184\n operable to facilitate rotational speed measurements \n236\n indicative of rotational speed of the drill bit \n126\n and/or another portion of the BHA \n124\n.', 'Rotational speed data output by the downhole rotational speed sensor \n184\n may be transmitted to the wellsite surface via downhole to surface telemetry \n237\n facilitated by the telemetry devices \n186\n, \n149\n.', 'The surface torque may be measured by the torque sensor \n210\n and/or calculated based on electrical current drawn by the motor, as described above.', 'One or more of the control devices \n204\n may then determine amplitude of downhole rotational speed fluctuations and the surface torque fluctuations based on the downhole rotational speed measurements \n236\n and the surface torque measurements \n234\n, respectively.\n \nFIG.', '3\n is table \n300\n showing behavior of the drill string \n120\n controlled by the control system \n200\n shown in \nFIG.', '2\n utilizing the stick-slip algorithm \n222\n that is completed and/or configured, one at a time, by six different sets \n302\n of numerical parameters \n230\n during test drilling operations performed by the well construction system \n100\n shown in \nFIG.', '1\n.', 'Accordingly, the following description refers to \nFIGS.', '1\n-\n3\n, collectively.', 'For each set \n302\n of the numerical parameters \n230\n, the table \n300\n shows average percentage (%) surface torque fluctuation \n304\n when the stick-slip algorithm \n222\n is not utilized (i.e., turned off), and average percentage (%) surface torque fluctuation \n306\n when the stick-slip algorithm \n222\n is utilized (i.e., turned on).', 'For each set \n302\n of the numerical parameters \n230\n, the table \n300\n further shows percentage (%) surface torque fluctuation reduction \n308\n, an average percentage (%) downhole rotational speed fluctuation \n310\n when the stick-slip algorithm \n222\n is not utilized, an average percentage (%) downhole rotational speed fluctuation \n312\n when the stick-slip algorithm \n222\n is utilized, and percentage (%) downhole rotational speed fluctuation reduction \n314\n.', 'The table \n300\n shows that the numerical parameter “Set 1” and “Set 6” cause the highest percentage (%) reduction in downhole rotational speed fluctuations \n308\n at 68.93% and 78.61%, respectively, and the highest percentage (%) reduction in surface torque fluctuations \n314\n at 82.50% and 86.14%, respectively.', 'Because numerical parameter “Set 6” resulted in the highest percentage (%) reduction in downhole rotational speed and surface torque fluctuations, the numerical parameters \n230\n of the numerical parameter “Set 6” may be utilized in the stick-slip algorithm \n222\n to optimize performance of the stick-slip algorithm \n222\n, and thus reduce the rotational waves traveling along the drill string \n120\n in an optimal manner while performing the drilling operations.', 'Thus, a plurality of different sets of numerical parameters \n230\n may be selected and then, during a drilling test and one at a time, incorporated (i.e., inserted) into the stick-slip algorithm \n222\n to complete and/or configure the stick-slip algorithm \n222\n stored on and operable to be executed by the control system \n200\n while monitoring (i.e., measuring) operational parameters of the drill string \n120\n.', 'In other words, an optimal set of the numerical parameters \n230\n may be determined by varying the numerical parameters \n230\n and analyzing surface and/or downhole operational measurements \n234\n, \n236\n in real-time while performing the drilling test.', 'The operational measurements \n234\n, \n236\n may also or instead be recorded and analyzed at a later time.', 'After the drilling test is performed, the optimal set of numerical parameters \n230\n may be selected based on the analysis of the operational measurements \n234\n, \n236\n, such as the ability to reduce the amplitude of rotational waves traveling along the drill string \n120\n.', 'Thus, the optimal set of numerical parameters \n230\n may cause or otherwise be associated with the rotational waves having the lowest (or smallest) determined amplitudes (or largest decrease in the amplitude of the rotational waves).', 'The optimal set of numerical parameters \n230\n may then be incorporated into the stick-slip algorithm \n222\n to perform the drilling operations.', 'The test drilling operations, the selection of different sets of numerical parameters \n230\n, the selection of the optimal set of numerical parameters \n230\n, and incorporation of the optimal set of numerical parameters \n230\n into the stick-slip algorithm \n222\n may be initiated or otherwise performed manually by personnel or automatically by the control system \n200\n.', 'Instead of performing test drilling operations using actual (i.e., real world)', 'well construction equipment, an optimal set of the numerical parameters of a stick-slip algorithm may instead be selected based on computer (i.e., virtual) simulations of such drilling operations, including computer simulations of a drill string being rotated by a driver (e.g., the top drive \n116\n or a rotary table) to drill a wellbore through a subterranean formation.', 'The computer simulations may also simulate control of the driver via the stick-slip algorithm to reduce the rotational waves traveling along the drill string.', 'Thus, the computer simulations according to one or more aspects of the present disclosure may comprise performing the operations of the test drilling operations described above, except that one or more aspects of such test drilling operations is performed virtually on a processing device (e.g., processing device \n400\n shown in \nFIG.', '4\n), such as a PLC, a PC, or an IPC.', 'A computer simulation may comprise or utilize a numerical simulation (i.e., a mathematical model) of the drilling equipment, including a top drive and a drill string.', 'The numerical simulation may include the use of a stick-slip algorithm for controlling the drilling equipment, such that stick-slip control of the drill string can be applied to the numerical simulation of the drilling equipment and the resulting behavior (i.e., operational parameters) of the drill string predicted.', 'To model the stick-slip behavior, the numerical simulation of the drilling equipment may include, for example, axial and/or rotational degrees of freedom, axial and/or rotational wave propagation, wellbore friction, and interaction between a drill bit and a rock formation.', 'During simulated drilling operations, the numerical parameters may be changed (i.e., varied) and simulated behavior of the drill string monitored.', 'Personnel (e.g., research and development personnel, computer programmers, engineers, etc.)', 'and/or a processing device may analyze the behavior of the drill string while the numerical parameters change to determine the performance of the stick-slip algorithm in terms of its ability to reduce the rotational waves traveling along the drill string \n120\n caused by stick-slip while utilizing each different set of numerical parameters.', 'The behavior of the drill string may be defined or characterized by monitoring simulated operational parameters, such as downhole rotational speed fluctuations and/or surface torque fluctuations along the drill string.', 'After the simulated drilling operations are performed, an optimal set of numerical parameters may be selected based on ability to inhibit or reduce the rotational waves traveling along the drill string.', 'The optimal set of numerical parameters may be incorporated into the stick-slip algorithm of the control system \n200\n.', 'Numerical optimization methods may be utilized to analyze the simulated operational parameters to identify or otherwise determine an optimal numerical parameter set.', 'The simulation of the drilling operations, the selection of different sets of numerical parameters, the selection of the optimal set of numerical parameters, and incorporation of the optimal set of numerical parameters may be initiated or otherwise performed manually by the personnel or automatically by the processing device.', 'Thus, an optimal set of the numerical parameters may also or instead be determined based on virtual experiments simulating a drill string during drilling operations and effects of a control system utilizing a stick-slip algorithm on the simulated drill string.', 'Numerical parameters of the stick-slip algorithm may be varied and surface and/or downhole operational parameters analyzed to determine the optimal set of numerical parameters.', 'A computer simulation may also or instead comprise or utilize a physics-based analytic model of the drilling equipment, including a top drive and a drill string.', 'The analytic model may include the use of a stick-slip algorithm for controlling the drilling equipment, such that stick-slip control of the drill string can be applied to the analytic model of the drilling equipment and the resulting behavior (i.e., operational parameters) of the drill string predicted.', 'The analytic model may include a constrained optimization, whereby optimization techniques (e.g., simulated annealing, genetic algorithms, etc.) are used to find a set of numerical parameters that minimize, for example, the reflection coefficient over a predetermined frequency range (e.g., between about 0.05 Hertz (Hz) and about 1.00 Hz) while placing a constraint on a value of a reflection coefficient over another predetermined frequency range (e.g., between about one Hertz (Hz) and about four Hz).', 'Additional constraints may include a maximum value and/or a minimum value of the reflection coefficient, wherein, for example, an overall minimum value of the reflection coefficient is 0.75 or less.', 'While optimizing the numerical parameters, an objective may be to minimize the absolute value of the reflection coefficient of upgoing rotational waves at the surface.', 'However, additional constraints and/or different criteria for minimizing the absolute value of the reflection coefficient may exist.', 'Because the reflection coefficient is generally a complex number, the term “reflection coefficient” as used hereinafter, refers to an absolute value of the reflection coefficient.', 'A criteria for minimizing the reflection coefficient may include minimizing an average reflection coefficient, or a simple function of the reflection coefficient, over a frequency range for which high rotational oscillations are detected during drilling operations.', 'Because rotational oscillations will not be problematic when the reflection coefficient is sufficiently low (e.g., less than 0.80), an example simple function may include taking the mean of an interval of the reflection coefficient, or the sufficiently low reflection coefficient, whichever is greater.', 'However, reducing the reflection coefficient over one frequency range may come at the expense of increasing the reflection coefficient over another frequency range.', 'For example, if the reflection coefficient is increased above 1.00, then such reflection coefficient increase may induce large rotational oscillations within a frequency range where no rotational oscillations existed without use of rotational control.', 'Thus, an additional constraint may be to include a limit on the value of the reflection coefficient over a frequency range where the reflection coefficient is not subject to minimization.', 'Such limit may itself be frequency varying because higher frequency oscillations may be subject to more natural dampening, and thus a higher reflection coefficient can be tolerated.', 'In addition to constraining the reflection coefficient, a top drive or another driver should not be used to deliver excessive torque.', 'For a given set of numerical parameters, torque requirement for reflecting a unit amplitude upgoing wave as a function of frequency can be derived, and similarly to the limit placed on the reflection coefficient, a limit on the derived torque function may be imposed.', 'The limit on the torque function may vary based on frequency.', 'Another constraint may be that the control system incorporating a stick-slip algorithm utilizing numerical parameters is stable.', 'Thus, an optimal set of the numerical parameters may also or instead be determined based on a physics-based analytic model of surface equipment (e.g., a top drive) and a drill string.', 'The model may then be used to simulate or predict behavior of the surface equipment and drill string based on different numerical parameters of the stick-slip algorithm to determine an optimal set of numerical parameters.', 'Constrained optimizations of the behavior caused by the numerical parameters may be performed to determine an optimal set of numerical parameters.', 'FIG.', '4\n is a schematic view of at least a portion of an example implementation of a processing device \n400\n (or system) according to one or more aspects of the present disclosure.', 'The processing device \n400\n may be or form at least a portion of one or more electronic devices shown in one or more of the \nFIGS.', '1\n and \n2\n.', 'Accordingly, the following description refers to \nFIGS.', '1\n, \n2\n, and \n4\n, collectively.', 'The processing device \n400\n may be or comprise, for example, one or more processors, controllers, special-purpose computing devices, PCs (e.g., desktop, laptop, and/or tablet computers), personal digital assistants, smartphones, IPCs, PLCs, servers, internet appliances, and/or other types of computing devices.', 'The processing device \n400\n may be or form at least a portion of the control devices \n188\n, \n192\n shown in \nFIG.', '1\n.', 'The processing device \n400\n may be or form at least a portion of the control devices \n212\n, \n214\n, \n216\n shown in \nFIG.', '2\n.', 'Although it is possible that the entirety of the processing device \n400\n is implemented within one device, it is also contemplated that one or more components or functions of the processing device \n400\n may be implemented across multiple devices, some or an entirety of which may be at the wellsite and/or remote from the wellsite.', 'The processing device \n400\n may comprise a processor \n412\n, such as a general-purpose programmable processor.', 'The processor \n412\n may comprise a local memory \n414\n, and may execute machine-readable and executable program code instructions \n432\n (i.e., computer program code) present in the local memory \n414\n and/or another memory device.', 'The processor \n412\n may execute, among other things, the program code instructions \n432\n and/or other instructions and/or programs to implement the example methods, processes, and/or operations described herein.', 'For example, the program code instructions \n432\n, when executed by the processor \n412\n of the processing device \n400\n, may cause a top drive \n116\n to perform example methods and/or operations described herein.', 'The program code instructions \n432\n, when executed by the processor \n412\n of the processing device \n400\n, may also or instead cause the processor \n412\n to receive and process the algorithm \n222\n and input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n, and output control commands \n224\n, \n244\n to the motor \n202\n of the top drive \n116\n based on the algorithm \n222\n and input data \n226\n, \n228\n, \n230\n, \n232\n, \n234\n.', 'The processor \n412\n may be, comprise, or be implemented by one or more processors of various types suitable to the local application environment, and may include one or more of general-purpose computers, special-purpose computers, microprocessors, digital signal processors (DSPs), field-programmable gate arrays (FPGAs), application-specific integrated circuits (ASICs), and processors based on a multi-core processor architecture, as non-limiting examples.', 'Examples of the processor \n412\n include one or more INTEL microprocessors, microcontrollers from the ARM and/or PICO families of microcontrollers, embedded soft/hard processors in one or more FPGAs.', 'The processor \n412\n may be in communication with a main memory \n416\n, such as may include a volatile memory \n418\n and a non-volatile memory \n420\n, perhaps via a bus \n422\n and/or other communication means.', 'The volatile memory \n418\n may be, comprise, or be implemented by random access memory (RAM), static random access memory (SRAM), synchronous dynamic random access memory (SDRAM), dynamic random access memory (DRAM), RAMBUS dynamic random access memory (RDRAM), and/or other types of random access memory devices.', 'The non-volatile memory \n420\n may be, comprise, or be implemented by read-only memory, flash memory, and/or other types of memory devices.', 'One or more memory controllers (not shown) may control access to the volatile memory \n418\n and/or non-volatile memory \n420\n.', 'The processing device \n400\n may also comprise an interface circuit \n424\n, which is in communication with the processor \n412\n, such as via the bus \n422\n.', 'The interface circuit \n424\n may be, comprise, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third generation input/output (3GIO) interface, a wireless interface, a cellular interface, and/or a satellite interface, among others.', 'The interface circuit \n424\n may comprise a graphics driver card.', 'The interface circuit \n424\n may comprise a communication device, such as a modem or network interface card to facilitate exchange of data with external computing devices via a network (e.g., Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, satellite, etc.).', 'The processing device \n400\n may be in communication with various sensors, video cameras, actuators, processing devices, control devices, and other devices of the well construction system via the interface circuit \n424\n.', 'The interface circuit \n424\n can facilitate communications between the processing device \n400\n and one or more devices by utilizing one or more communication protocols, such as an Ethernet-based network protocol (such as ProfiNET, OPC, OPC/UA, Modbus TCP/IP, EtherCAT, UDP multicast, Siemens S7 communication, or the like), a proprietary communication protocol, and/or another communication protocol.', 'One or more input devices \n426\n may also be connected to the interface circuit \n424\n.', 'The input devices \n426\n may permit human wellsite operators \n195\n to enter the program code instructions \n432\n, which may be or comprise control commands, drilling equipment specifications, top drive specifications, drill string specifications, numerical parameters, operational parameters, operational thresholds, and/or other operational set-points.', 'The program code instructions \n432\n may further comprise modeling or predictive routines, equations, algorithms, processes, applications, and/or other programs operable to perform example methods and/or operations described herein.', 'The input devices \n426\n may be, comprise, or be implemented by a keyboard, a mouse, a joystick, a touchscreen, a track-pad, a trackball, an isopoint, and/or a voice recognition system, among other examples.', 'One or more output devices \n428\n may also be connected to the interface circuit \n424\n.', 'The output devices \n428\n may permit for visualization or other sensory perception of various data, such as sensor data, status data, and/or other example data.', 'The output devices \n428\n may be, comprise, or be implemented by video output devices (e.g., an LCD, an LED display, a CRT display, a touchscreen, etc.), printers, and/or speakers, among other examples.', 'The one or more input devices \n426\n and the one or more output devices \n428\n connected to the interface circuit \n424\n may, at least in part, facilitate the HMIs described herein.', 'The processing device \n400\n may comprise a mass storage device \n430\n for storing data and program code instructions \n432\n.', 'The mass storage device \n430\n may be connected to the processor \n412\n, such as via the bus \n422\n.', 'The mass storage device \n430\n may be or comprise a tangible, non-transitory storage medium, such as a floppy disk drive, a hard disk drive, a compact disk (CD) drive, and/or digital versatile disk (DVD) drive, among other examples.', 'The processing device \n400\n may be communicatively connected with an external storage medium \n434\n via the interface circuit \n424\n.', 'The external storage medium \n434\n may be or comprise a removable storage medium (e.g., a CD or DVD), such as may be operable to store data and program code instructions \n432\n.', 'As described above, the program code instructions \n432\n and other data (e.g., sensor data or measurements database) may be stored on (i.e., entered, installed, programmed, etc.)', 'the mass storage device \n430\n, the main memory \n416\n, the local memory \n414\n, and/or the removable storage medium \n434\n.', 'Thus, the processing device \n400\n may be implemented in accordance with hardware (perhaps implemented in one or more chips including an integrated circuit, such as an ASIC), or may be implemented as software or firmware for execution by the processor \n412\n.', 'In the case of firmware or software, the implementation may be provided as a computer program product including a non-transitory, computer-readable medium or storage structure embodying computer program code instructions \n432\n (i.e., software or firmware) thereon for execution by the processor \n412\n.', 'The program code instructions \n432\n may include program instructions or computer program code that, when executed by the processor \n412\n, may perform and/or cause performance of example methods, processes, and/or operations described herein.', 'The present disclosure is further directed to example methods (e.g., operations, processes, actions, etc.) for monitoring and controlling well construction equipment \n110\n, \n120\n of a well construction system \n100\n.', 'In the following description, one or more descriptors and/or other references to such example methods may not be applicable to the entirety of one or more of the methods.', 'That is, such references may instead be applicable to just one or more aspects of one or more of the methods.', 'Thus, references to “the example methods” are to be understood as being applicable to the entirety of one or more of the methods and/or one or more aspects of one or more of the methods.', 'The example methods may be performed utilizing or otherwise in conjunction with one or more implementations of one or more instances of one or more components of the apparatus shown in one or more of \nFIGS.', '1\n-\n4\n and/or otherwise within the scope of the present disclosure.', 'For example, the example methods may be at least partially performed (and/or caused to be performed) by a processing device (e.g., the processing device \n500\n, the control devices \n204\n, etc.)', 'executing program code instructions according to one or more aspects of the present disclosure.', 'Thus, the present disclosure is also directed to a non-transitory, computer-readable medium comprising computer program code that, when executed by the processing device, may cause such processing device to perform the example methods described herein.', 'The methods may also or instead be at least partially performed (or be caused to be performed) by a human operator (e.g., rig personnel, engineers, etc.) utilizing one or more implementations of one or more instances of one or more components of the apparatus shown in one or more of \nFIGS.', '1\n-\n4\n and/or otherwise within the scope of the present disclosure.', 'Accordingly, the following description refers to apparatus shown in one or more of \nFIGS.', '1\n-\n4\n and example methods that may be performed by such apparatus.', 'However, the example methods may also be performed in conjunction with implementations of apparatus other than those depicted in \nFIGS.', '1\n-\n4\n that are also within the scope of the present disclosure.', 'An example implementation of a method according to one or more aspects of the present disclosure may comprise commencing operation of a control system \n200\n for controlling a driver \n116\n of a drill string \n120\n.', 'The control system \n200\n may comprise a processor \n412\n and a memory \n416\n storing a computer program code \n220\n, which may include a stick-slip algorithm \n222\n.', 'The operating control system \n200\n may receive a plurality of different numerical parameters \n230\n, and for each of the different numerical parameters \n230\n, incorporate the numerical parameter \n230\n into the stick-slip algorithm \n222\n and execute the stick-slip algorithm \n222\n to determine a control command \n224\n, \n244\n that causes the driver \n116\n to rotate the drill string \n120\n to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string \n120\n.', 'Before executing the stick-slip algorithm, the operating control system \n200\n may also receive an intended average rotational speed set-point \n226\n of the drill string \n120\n, incorporate the intended average rotational speed set-point \n226\n of the drill string \n120\n into the stick-slip algorithm \n222\n, receive specifications \n228\n of the drill string \n120\n and/or the driver \n116\n, and incorporate the specifications \n228\n into the stick-slip algorithm \n222\n.', 'For each of the different numerical parameters \n230\n, the operating control system \n200\n may output a different torque command \n244\n to the driver \n116\n thereby causing the driver \n116\n to output a different amount of torque to rotate the drill string \n120\n.', 'The operating control system \n200\n may also receive torque measurements \n234\n indicative of torque at a corresponding portion (e.g., the upper end) of the drill string \n120\n, determine (i.e., measure) the amplitude of the rotational waves travelling along the drill string \n120\n based on the torque measurements \n234\n for each of the different numerical parameters \n230\n, and determine optimal ones of the different numerical parameters \n230\n based on the determined amplitudes of the rotational waves.', 'The operating control system \n200\n may also receive rotational speed measurements indicative of rotational speed of a corresponding portion of the drill string, determine the amplitude of the rotational waves travelling along the drill string based on the rotational speed measurements for each of the different numerical parameters, and determine optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves.', 'The optimal ones of the different numerical parameters \n230\n may cause or otherwise be associated with the rotational waves having the lowest (or smallest) determined amplitudes (or largest decrease in the amplitude of the rotational waves).', 'As described above, the numerical parameters \n230\n may be or comprise the constants of the stick-slip algorithm Equations (1)-(4), including the speed proportionality constant k\n1\n, the torque proportionality constant k\n2\n, the speed integral constant k, the inertial compensation constant k\ntdj\n, the speed control loop proportional constant k\np\n, the speed control loop integral constant k\ni\n, and one or more filtering parameters f, such as a bandpass filter that can be applied to control and/or feedback signals to control or vary an upper and a lower frequency of control and/or feedback signals.', 'Another example implementation of a method according to one or more aspects of the present disclosure may comprise commencing operation of a processing device \n400\n to run a computer simulation of a drill string \n120\n being rotated by a driver \n116\n to drill a wellbore \n120\n, wherein rotation of the driver \n116\n is controlled by a stick-slip algorithm \n222\n.', 'The computer simulation run by the processing device \n400\n may be or comprise a numerical simulation.', 'However, the computer simulation run by the processing device \n400\n may instead be or comprise a physics-based analytic model that utilizes constrained optimizations.', 'The operating processing device \n400\n may receive a plurality of different numerical parameters \n230\n, and for each of the different numerical parameters \n230\n, incorporate the numerical parameter \n230\n into the stick-slip algorithm \n222\n and execute the stick-slip algorithm \n222\n to determine a control command \n224\n, \n244\n that causes the driver \n116\n to rotate the drill string \n120\n to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string \n120\n.', 'Before executing the stick-slip algorithm, the operating processing device \n400\n may also receive an intended average rotational speed set-point \n226\n of the drill string \n120\n, incorporate the intended average rotational speed set-point \n226\n of the drill string \n120\n into the stick-slip algorithm \n222\n, receive specifications \n228\n of the drill string \n120\n and/or the driver \n116\n, and incorporate the specifications \n228\n into the stick-slip algorithm \n222\n.', 'For each of the different numerical parameters \n230\n, the operating processing device \n400\n may simulate output of a different torque command \n244\n to the driver \n116\n thereby causing the driver \n116\n to output a different amount of torque to rotate the drill string \n120\n.', 'The operating processing device \n400\n may also determine the amplitude of the rotational waves travelling along the drill string \n120\n for each of the different numerical parameters \n230\n, and determine optimal ones of the different numerical parameters \n230\n based on the determined amplitudes of the rotational waves.', 'The optimal ones of the different numerical parameters \n230\n may cause or otherwise be associated with the rotational waves having the lowest (or smallest) determined amplitudes (or largest decrease in the amplitude of the rotational waves).', 'In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces an apparatus comprising a control system operable to control a driver for rotating a drill string, wherein the control system comprises a processor and a memory storing a computer program code, wherein the computer program code comprises a stick-slip algorithm, and wherein the control system is operable to: (A) receive a plurality of different numerical parameters; and (B) for each of the different numerical parameters: (1) incorporate the numerical parameter into the stick-slip algorithm; and (2) execute the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing rotational waves travelling along the drill string.', 'The control system may comprise a torque sensor operable to facilitate torque measurements indicative of torque at a corresponding portion of the drill string.', 'In such implementations, among others within the scope of the present disclosure, the control system may be operable to: determine amplitude of the rotational waves travelling along the drill string based on the torque measurements for each of the different numerical parameters; and determine optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters may be associated with the lowest of the determined amplitudes of the rotational waves.', 'The torque sensor may be a surface torque sensor operable to facilitate torque measurements indicative of torque at an upper end of the drill string.', 'The control system may comprise a rotational speed sensor operable to facilitate rotational speed measurements indicative of rotational speed of a corresponding portion of the drill string.', 'In such implementations, among others within the scope of the present disclosure, the control system may be operable to: determine amplitude of the rotational waves travelling along the drill string based on the rotational speed measurements for each of the different numerical parameters; and determine optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters may be associated with the lowest of the determined amplitudes of the rotational waves.', 'The rotational speed sensor may be a downhole rotational speed sensor operable to facilitate rotational speed measurements indicative of rotational speed at a lower end of the drill string.', 'The different numerical parameters may comprise at least one of a speed integral constant, a speed proportionality constant, and a torque proportionality constant.', 'Before executing the stick-slip algorithm, the control system may be operable to: receive an intended average rotational speed set-point of the drill string; incorporate the intended average rotational speed set-point of the drill string into the stick-slip algorithm; receive specifications of the drill string and/or the driver; and incorporate the specifications of the drill string into the stick-slip algorithm.', 'For each of the different numerical parameters, the control system may be operable to output a different torque command to the driver to thereby cause the driver to output a different amount of torque to rotate the drill string.', 'The present disclosure also introduces a method comprising commencing operation of a control system for controlling a driver of a drill string, wherein the control system comprises a processor and a memory storing a computer program code, wherein the computer program code comprises a stick-slip algorithm, and wherein the operating control system: (A) receives a plurality of different numerical parameters; and (B) for each of the different numerical parameters: (1) incorporates the numerical parameter into the stick-slip algorithm; and (2) executes the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing rotational waves travelling along the drill string.', 'The operating control system may also: receive torque measurements indicative of torque at a corresponding portion of the drill string; determine an amplitude of the rotational waves travelling along the drill string based on the torque measurements for each of the different numerical parameters; and determine optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters are associated with the lowest of the determined amplitudes of the rotational waves.', 'The operating control system may: receive rotational speed measurements indicative of rotational speed of a corresponding portion of the drill string; determine an amplitude of the rotational waves travelling along the drill string based on the rotational speed measurements for each of the different numerical parameters; and determine optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters are associated with the lowest of the determined amplitudes of the rotational waves.', 'The different numerical parameters may comprise at least one of a speed integral constant, a speed proportionality constant, and a torque proportionality constant.', 'Before executing the stick-slip algorithm, the operating control system may: receive an intended average rotational speed set-point of the drill string; incorporate the intended average rotational speed set-point of the drill string into the stick-slip algorithm; receive specifications of the drill string and/or the driver; and incorporate the specifications into the stick-slip algorithm.', 'For each of the different numerical parameters, the operating control system may output a different torque command to the driver thereby causing the driver to output a different amount of torque to rotate the drill string.', 'The present disclosure also introduces a method comprising commencing operation of a processing device to run a computer simulation of a drill string being rotated by a driver to drill a wellbore, wherein rotation of the driver is controlled by a stick-slip algorithm, and wherein the operating processing device: (A) receives a plurality of different numerical parameters; and (B) for each of the different numerical parameters: (1) incorporates the numerical parameter into the stick-slip algorithm; and (2) executes the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string.', 'The operating processing device may: determine the amplitude of the rotational waves travelling along the drill string for each of the different numerical parameters; and determine optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters are associated with the lowest of the determined amplitudes of the rotational waves.', 'The different numerical parameters may comprise at least one of a speed integral constant, a speed proportionality constant, and a torque proportionality constant.', 'Before executing the stick-slip algorithm, the operating processing device may: receive an intended average rotational speed set-point of the drill string; incorporate the intended average rotational speed set-point of the drill string into the stick-slip algorithm; receive specifications of the drill string and/or the driver; and incorporate the specifications into the stick-slip algorithm.', 'The computer simulation may be or comprise a numerical simulation.', 'The computer simulation may be or comprise a physics-based analytic model that utilizes constrained optimizations.', 'The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure.', 'A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same functions and/or achieving the same benefits of the embodiments introduced herein.', 'A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the scope of the present disclosure.', 'The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. § 1.72(b) to permit the reader to quickly ascertain the nature of the technical disclosure.', 'It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.']

['1.', 'An apparatus comprising:\na control system operable to control a driver for rotating a drill string, wherein the control system comprises one or more sensors operable to facilitate measurements indicative of one or more characteristics of one or more corresponding portions of the drill string, wherein the control system comprises a processor and a memory storing a computer program code, wherein the computer program code comprises a stick-slip algorithm, and wherein the control system is operable to: execute the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing rotational waves travelling along the drill string, wherein the stick-slip algorithm: determines amplitude of the rotational waves travelling along the drill string based on the measurements for each of different numerical parameters; and determines optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters are associated with the lowest of the determined amplitudes of the rotational waves.', '2.', 'The apparatus of claim 1 wherein:\nthe one or more sensors comprise a torque sensor operable to facilitate torque measurements indicative of torque at a corresponding portion of the drill string; and\nwherein the stick-slip algorithm determines amplitude of the rotational waves travelling along the drill string based on the torque measurements for each of the different numerical parameters.', '3.', 'The apparatus of claim 2 wherein the torque sensor is a surface torque sensor operable to facilitate torque measurements indicative of torque at an upper end of the drill string.', '4.', 'The apparatus of claim 1 wherein:\nthe one or more sensors comprise a rotational speed sensor operable to facilitate rotational speed measurements indicative of rotational speed of a corresponding portion of the drill string; and\nwherein the stick-slip algorithm determines amplitude of the rotational waves travelling along the drill string based on the rotational speed measurements for each of the different numerical parameters.', '5.', 'The apparatus of claim 4 wherein the rotational speed sensor is a downhole rotational speed sensor operable to facilitate rotational speed measurements indicative of rotational speed at a lower end of the drill string.', '6.', 'The apparatus of claim 1 wherein the different numerical parameters comprise at least one of:\na speed integral constant;\na speed proportionality constant; and\na torque proportionality constant.', '7.', 'The apparatus of claim 1 wherein, before executing the stick-slip algorithm, the control system is further operable to:\nreceive an intended average rotational speed set-point of the drill string;\nincorporate the intended average rotational speed set-point of the drill string into the stick-slip algorithm;\nreceive specifications of the drill string and/or the driver; and\nincorporate the specifications of the drill string into the stick-slip algorithm.', '8.', 'The apparatus of claim 1 wherein, for each of the different numerical parameters, the control system is further operable to output a different torque command to the driver to thereby cause the driver to output a different amount of torque to rotate the drill string.', '9.', 'A method comprising:\ncommencing operation of a control system for controlling a driver of a drill string, wherein the control system receives measurements indicative of one or more characteristics of one or more corresponding portions of the drill string, wherein the control system comprises a processor and a memory storing a computer program code, wherein the computer program code comprises a stick-slip algorithm, and wherein the operating control system:\nexecutes the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing rotational waves travelling along the drill string, wherein the stick-slip algorithm: determines amplitude of the rotational waves travelling along the drill string based on the measurements for each of different numerical parameters; and determines optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters are associated with the lowest of the determined amplitudes of the rotational waves.\n\n\n\n\n\n\n10.', 'The method of claim 9 wherein the operating control system:\nreceives torque measurements indicative of torque at a corresponding portion of the drill string; and\ndetermines an amplitude of the rotational waves travelling along the drill string based on the torque measurements for each of the different numerical parameters.', '11.', 'The method of claim 9 wherein the operating control system:\nreceives rotational speed measurements indicative of rotational speed of a corresponding portion of the drill string; and\ndetermines an amplitude of the rotational waves travelling along the drill string based on the rotational speed measurements for each of the different numerical parameters.\n\n\n\n\n\n\n12.', 'The method of claim 9 wherein the different numerical parameters comprise at least one of:\na speed integral constant;\na speed proportionality constant; and\na torque proportionality constant.', '13.', 'The method of claim 9 wherein, before executing the stick-slip algorithm, the operating control system also:\nreceives an intended average rotational speed set-point of the drill string;\nincorporates the intended average rotational speed set-point of the drill string into the stick-slip algorithm;\nreceives specifications of the drill string and/or the driver; and\nincorporates the specifications into the stick-slip algorithm.', '14.', 'The method of claim 9 wherein, for each of the different numerical parameters, the operating control system also outputs a different torque command to the driver thereby causing the driver to output a different amount of torque to rotate the drill string.', '15.', 'A method comprising:\ncommencing operation of a processing device to run a computer simulation of a drill string being rotated by a driver to drill a wellbore, wherein rotation of the driver is controlled by a stick-slip algorithm, and wherein the operating processing device: executes the stick-slip algorithm to determine a control command that causes the driver to rotate the drill string to perform drilling operations while reducing amplitude of rotational waves travelling along the drill string, wherein the stick-slip algorithm: determines the amplitude of the rotational waves travelling along the drill string for each of the different numerical parameters; and determines optimal ones of the different numerical parameters based on the determined amplitudes of the rotational waves, wherein the optimal ones of the different numerical parameters are associated with the lowest of the determined amplitudes of the rotational waves.', '16.', 'The method of claim 15 wherein the different numerical parameters comprise at least one of:\na speed integral constant;\na speed proportionality constant; and\na torque proportionality constant.\n\n\n\n\n\n\n17.', 'The method of claim 15 wherein, before executing the stick-slip algorithm, the operating processing device also:\nreceives an intended average rotational speed set-point of the drill string;\nincorporates the intended average rotational speed set-point of the drill string into the stick-slip algorithm;\nreceives specifications of the drill string and/or the driver; and\nincorporates the specifications into the stick-slip algorithm.', '18.', 'The method of claim 15 wherein the computer simulation is or comprises a numerical simulation.', '19.', 'The method of claim 15 wherein the computer simulation comprises a physics-based analytic model that utilizes constrained optimizations.']

['FIG.', '1 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG.', '2 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG.', '3 is a table related to one or more aspects of the present disclosure.', '; FIG.', '4 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.', '; FIG. 1 is a schematic view of at least a portion of an example implementation of a well construction system 100 according to one or more aspects of the present disclosure.', 'The well construction system 100 represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'The well construction system 100 may be or comprise a well construction rig (i.e., a drilling rig).', 'Although the well construction system 100 is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', '; FIG.', '2 is a schematic view of at least a portion of an example implementation of a control system 200 operable to monitor and control operation of a drill string driver (e.g., a top drive) according to one or more aspects of the present disclosure.', 'The control system 200 may form a portion of or operate in conjunction with the well construction system 100 shown in FIG.', '1, and thus may comprise one or more features of the well construction system 100 shown in FIG.', '1, including where indicated by the same reference numerals.', 'Accordingly, the following description refers to FIGS.', '1 and 2, collectively.;', 'FIG. 3 is table 300 showing behavior of the drill string 120 controlled by the control system 200 shown in FIG.', '2 utilizing the stick-slip algorithm 222 that is completed and/or configured, one at a time, by six different sets 302 of numerical parameters 230 during test drilling operations performed by the well construction system 100 shown in FIG.', '1.', 'Accordingly, the following description refers to FIGS.', '1-3, collectively.;', 'FIG. 4 is a schematic view of at least a portion of an example implementation of a processing device 400 (or system) according to one or more aspects of the present disclosure.', 'The processing device 400 may be or form at least a portion of one or more electronic devices shown in one or more of the FIGS.', '1 and 2.', 'Accordingly, the following description refers to FIGS.', '1, 2, and 4, collectively.']

US11828900

Elastic adaptive downhole acquisition system

Sep 27, 2019

Yiqiao Tang, Yi-Qiao Song, Martin Hurlimann, Yanxian Lin

SCHLUMBERGER TECHNOLOGY CORPORATION

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['A method can include performing an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; and responsive to the request, receiving an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.']

['Description\n\n\n\n\n\n\nRELATED APPLICATIONS', 'This application claims priority to and the benefit of a U.S. Provisional Application having Ser.', 'No. 62/738,318 filed 28 Sep. 2018, which is incorporated by reference herein.', 'BACKGROUND\n \nVarious types of operations can be performed using a system that includes memory and telemetry circuitry where the memory may be limited and/or where the telemetry may be limited.', 'SUMMARY\n \nA method can include performing an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; and responsive to the request, receiving an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'A system can include a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: perform an operation using the system where the operation depends on a decision made via a digital decision model stored in the memory of the system; responsive to a decision state of the digital decision model, transmit a request to update the digital decision model; and, responsive to the request, receive an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'One or more computer-readable storage media can include processor-executable instructions executable to instruct a processor to: call for performance of an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; responsive to a decision state of the digital decision model, call for transmission of a request to update the digital decision model; and, responsive to the request, call for storage in the memory of a received updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'Various other apparatuses, systems, methods, etc., are also disclosed.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFeatures and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.\n \nFIG.', '1\n illustrates examples of equipment in a geologic environment;\n \nFIG.', '2\n illustrates an example of a system and examples of types of holes;\n \nFIG.', '3\n illustrates an example of a system;\n \nFIG.', '4\n illustrates an example of a system;\n \nFIG.', '5\n illustrates an example of a system;\n \nFIG.', '6\n illustrates examples of systems;\n \nFIG.', '7\n illustrates an example of a method and an example of a system;\n \nFIG.', '8\n illustrates an example of a method and an example of a tool;\n \nFIG.', '9\n illustrates an example of a system;\n \nFIG.', '10\n illustrates an example of a microprocessor and an example of circuitry;\n \nFIG.', '11\n illustrates an example of a graphical user interface;\n \nFIG.', '12\n illustrates an example of a method;\n \nFIG.', '13\n illustrates examples of systems;\n \nFIG.', '14\n illustrates examples of plots;\n \nFIG.', '15\n illustrates an example of a diagram of an example of a method;\n \nFIG.', '16\n illustrates an example of a plot;\n \nFIG.', '17\n illustrates example plots and an example of a diagram of an example of a method;\n \nFIG.', '18\n illustrates example plots and an example of a diagram of an example of a method;\n \nFIG.', '19\n illustrates example plots of an example of a method;\n \nFIG.', '20\n illustrates an example plot of an example of a method;\n \nFIG.', '21\n illustrates an example diagram of an example of a method;\n \nFIG.', '22\n illustrates example plots of an example of a method;\n \nFIG.', '23\n illustrates example plots of an example of a method;\n \nFIG.', '24\n illustrates an examples of pseudocode for examples of methods;\n \nFIG.', '25\n illustrates examples of computing and networking equipment; and\n \nFIG.', '26\n illustrates example components of a system and a networked system.', 'DETAILED DESCRIPTION', 'The following description includes embodiments of the best mode presently contemplated for practicing the described implementations.', 'This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.', 'As mentioned, various types of operations can be performed using a system that includes memory and telemetry circuitry where the memory may be limited and/or where the telemetry may be limited.', 'As an example, various operations can be performed in a field.', 'For example, consider exploration as an initial phase in petroleum operations that includes generation of a prospect or play or both, and drilling of an exploration well or borehole.', 'Appraisal, development and production phases may follow successful exploration.', 'A borehole may be referred to as a wellbore and can include an openhole portion or an uncased portion and/or may include a cased portion.', 'A borehole may be defined by a bore wall that is composed of a rock that bounds the borehole.', 'As to a well or a borehole, whether for one or more of exploration, sensing, production, injection or other operation(s), it can be planned.', 'Such a process may be referred to generally as well planning, a process by which a path can be mapped in a geologic environment.', 'Such a path may be referred to as a trajectory, which can include coordinates in a three-dimensional coordinate system where a measure along the trajectory may be a measured depth, a total vertical depth or another type of measure.', 'During drilling, wireline investigations, etc., equipment may be moved into and/or out of a well or borehole.', 'Such operations can occur over time and may differ with respect to time.', 'As an example, drilling can include using one or more logging tools that can perform one or more logging operations while drilling or otherwise with a drillstring (e.g., while stationary, while tripping in, tripping out, etc.).', 'As an example, a wireline operation can include using one or more logging tools that can perform one or more logging operations.', 'A planning process may call for performing various operations, which may be serial, parallel, serial and parallel, etc.', 'As an example, a well plan can be generated based at least in part on imposed constraints and known information.', 'As an example, a well plan may be provided to a well owner, approved, and then implemented by a drilling service provider (e.g., a directional driller or “DD”).', 'In such an example, a rig may be used to drill, for example, according to a well plan.', 'During a period of time during which a well plan is implemented, a rig may transition from one state to another state, which may be referred to as rigstates.', 'As an example, a state may be a drilling state or may be a state where drilling into a formation (e.g., rock) is not occurring (e.g., an idle state, a tripping-in state, a tripping-out state, etc.).', 'As an example, a well design system can account for one or more capabilities of a drilling system or drilling systems that may be utilized at a wellsite.', 'As an example, a drilling engineer may be called upon to take such capabilities into account, for example, as one or more of various designs and specifications are created.', 'As an example, a state such as a rigstate may correspond to a capability, for example, while the capability is being utilized.', 'As an example, a well design system, which may be a well planning system, may take into account automation.', 'For example, where a wellsite includes wellsite equipment that can be automated, for example, via a local and/or a remote automation command, a well plan may be generated in digital form that can be utilized in a well drilling system where at least some amount of automation is possible and desired.', 'For example, a digital well plan can be accessible by a well drilling system where information in the digital well plan can be utilized via one or more automation mechanisms of the well drilling system to automate one or more operations at a wellsite.', 'As an example, drilling or one or more other operations may occur responsive to measurements.', 'For example, a logging while drilling operation may acquire measurements and adjust drilling based at least in part on such measurements.', 'As an example, a logging operation can include moving a logging tool, stopping a logging tool, or otherwise controlling a logging tool based at least in part on measurements acquired by the logging tool or, for example, another logging tool (e.g., sensor unit, etc.).', 'As an example, a nuclear magnetic resonance (NMR) unit can be utilized to determine properties of objects, substances or objects and substances.', 'In various operations, a downhole tool can include one or more NMR units that can acquire NMR measurements.', 'Such measurements may provide for characterization of one or more objects, one or more substances, etc.', 'Such measurements may be acquired using wireline technology, drilling technology (e.g., logging while drilling, etc.), or other downhole technology.', 'As an example, NMR technology can be utilized in a geologic environment to characterize the geologic environment (e.g., formation characterization, fluid characterization, etc.).', 'FIG.', '1\n shows an example of a geologic environment \n120\n.', 'In \nFIG.', '1\n, the geologic environment \n120\n may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir \n121\n and that may be, for example, intersected by a fault \n123\n (e.g., or faults).', 'As an example, the geologic environment \n120\n may be outfitted with a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n122\n may include communication circuitry to receive and/or to transmit information with respect to one or more networks \n125\n.', 'Such information may include information associated with downhole equipment \n124\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n126\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more pieces of equipment may provide for measurement, collection, communication, storage, analysis, etc. of data (e.g., for one or more produced resources, etc.).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, geolocation, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n125\n that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n120\n as optionally including equipment \n127\n and \n128\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n129\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n127\n and/or \n128\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, NMR logging, assessment of one or more fractures, injection, production, etc.', 'As an example, the equipment \n127\n and/or \n128\n may provide for measurement, collection, communication, storage, analysis, etc. of data such as, for example, formation data, fluid data, production data (e.g., for one or more produced resources), etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.\n \nFIG.', '1\n also shows an example of equipment \n170\n and an example of equipment \n180\n.', 'Such equipment, which may be systems of components, may be suitable for use in the geologic environment \n120\n.', 'While the equipment \n170\n and \n180\n are illustrated as land-based, various components may be suitable for use in an offshore system.', 'As shown in \nFIG.', '1\n, the equipment \n180\n can be mobile as carried by a vehicle; noting that the equipment \n170\n can be assembled, disassembled, transported and re-assembled, etc.', 'The equipment \n170\n includes a platform \n171\n, a derrick \n172\n, a crown block \n173\n, a line \n174\n, a traveling block assembly \n175\n, drawworks \n176\n and a landing \n177\n (e.g., a monkeyboard).', 'As an example, the line \n174\n may be controlled at least in part via the drawworks \n176\n such that the traveling block assembly \n175\n travels in a vertical direction with respect to the platform \n171\n.', 'For example, by drawing the line \n174\n in, the drawworks \n176\n may cause the line \n174\n to run through the crown block \n173\n and lift the traveling block assembly \n175\n skyward away from the platform \n171\n; whereas, by allowing the line \n174\n out, the drawworks \n176\n may cause the line \n174\n to run through the crown block \n173\n and lower the traveling block assembly \n175\n toward the platform \n171\n.', 'Where the traveling block assembly \n175\n carries pipe (e.g., casing, etc.)', ', tracking of movement of the traveling block \n175\n may provide an indication as to how much pipe has been deployed.', 'A derrick can be a structure used to support a crown block and a traveling block operatively coupled to the crown block at least in part via line.', 'A derrick may be pyramidal in shape and offer a suitable strength-to-weight ratio.', 'A derrick may be movable as a unit or in a piece by piece manner (e.g., to be assembled and disassembled).', 'As an example, drawworks may include a spool, brakes, a power source and assorted auxiliary devices.', 'Drawworks may controllably reel out and reel in line.', 'Line may be reeled over a crown block and coupled to a traveling block to gain mechanical advantage in a “block and tackle” or “pulley” fashion.', 'Reeling out and in of line can cause a traveling block (e.g., and whatever may be hanging underneath it), to be lowered into or raised out of a bore.', 'Reeling out of line may be powered by gravity and reeling in by a motor, an engine, etc.', '(e.g., an electric motor, a diesel engine, etc.).', 'As an example, a crown block can include a set of pulleys (e.g., sheaves) that can be located at or near a top of a derrick or a mast, over which line is threaded.', 'A traveling block can include a set of sheaves that can be moved up and down in a derrick or a mast via line threaded in the set of sheaves of the traveling block and in the set of sheaves of a crown block.', 'A crown block, a traveling block and a line can form a pulley system of a derrick or a mast, which may enable handling of heavy loads (e.g., drillstring, pipe, casing, liners, etc.) to be lifted out of or lowered into a bore.', 'As an example, line may be about a centimeter to about five centimeters in diameter as, for example, steel cable.', 'Through use of a set of sheaves, such line may carry loads heavier than the line could support as a single strand.', 'As an example, a derrick person may be a rig crew member that works on a platform attached to a derrick or a mast.', 'A derrick can include a landing on which a derrick person may stand.', 'As an example, such a landing may be about 10 meters or more above a rig floor.', 'In an operation referred to as trip out of the hole (TOH), a derrick person may wear a safety harness that enables leaning out from the work landing (e.g., monkeyboard) to reach pipe located at or near the center of a derrick or a mast and to throw a line around the pipe and pull it back into its storage location (e.g., fingerboards), for example, until a time at which it may be desirable to run the pipe back into the bore.', 'As an example, a rig may include automated pipe-handling equipment such that the derrick person controls the machinery rather than physically handling the pipe.', 'As an example, a trip may refer to the act of pulling equipment from a bore and/or placing equipment in a bore.', 'As an example, equipment may include a drillstring that can be pulled out of the hole and/or place or replaced in the hole.', 'As an example, a pipe trip may be performed where a drill bit has dulled or has otherwise ceased to drill efficiently and is to be replaced.\n \nFIG.', '2\n shows an example of a wellsite system \n200\n (e.g., at a wellsite that may be onshore or offshore).', 'As shown, the wellsite system \n200\n can include a mud tank \n201\n for holding mud and other material (e.g., where mud can be a drilling fluid that may help to transport cuttings, etc.), a suction line \n203\n that serves as an inlet to a mud pump \n204\n for pumping mud from the mud tank \n201\n such that mud flows to a vibrating hose \n206\n, a drawworks \n207\n for winching drill line or drill lines \n212\n, a standpipe \n208\n that receives mud from the vibrating hose \n206\n, a kelly hose \n209\n that receives mud from the standpipe \n208\n, a gooseneck or goosenecks \n210\n, a traveling block \n211\n, a crown block \n213\n for carrying the traveling block \n211\n via the drill line or drill lines \n212\n (see, e.g., the crown block \n173\n of \nFIG.', '1\n), a derrick \n214\n (see, e.g., the derrick \n172\n of \nFIG.', '1\n), a kelly \n218\n or a top drive \n240\n, a kelly drive bushing \n219\n, a rotary table \n220\n, a drill floor \n221\n, a bell nipple \n222\n, one or more blowout preventors (BOPs) \n223\n, a drillstring \n225\n, a drill bit \n226\n, a casing head \n227\n and a flow pipe \n228\n that carries mud and other material to, for example, the mud tank \n201\n.', 'In the example system of \nFIG.', '2\n, a borehole \n232\n is formed in subsurface formations \n230\n by rotary drilling; noting that various example embodiments may also use directional drilling or one or more other types of drilling.', 'As shown in the example of \nFIG.', '2\n, the drillstring \n225\n is suspended within the borehole \n232\n and has a drillstring assembly \n250\n that includes the drill bit \n226\n at its lower end.', 'As an example, the drillstring assembly \n250\n may be a bottom hole assembly (BHA).', 'The wellsite system \n200\n can provide for operation of the drillstring \n225\n and other operations.', 'As shown, the wellsite system \n200\n includes the platform \n215\n and the derrick \n214\n positioned over the borehole \n232\n.', 'As mentioned, the wellsite system \n200\n can include the rotary table \n220\n where the drillstring \n225\n passes through an opening in the rotary table \n220\n.', 'As shown in the example of \nFIG.', '2\n, the wellsite system \n200\n can include the kelly \n218\n and associated components, etc., or a top drive \n240\n and associated components.', 'As to a kelly example, the kelly \n218\n may be a square or hexagonal metal/alloy bar with a hole drilled therein that serves as a mud flow path.', 'The kelly \n218\n can be used to transmit rotary motion from the rotary table \n220\n via the kelly drive bushing \n219\n to the drillstring \n225\n, while allowing the drillstring \n225\n to be lowered or raised during rotation.', 'The kelly \n218\n can pass through the kelly drive bushing \n219\n, which can be driven by the rotary table \n220\n.', 'As an example, the rotary table \n220\n can include a master bushing that operatively couples to the kelly drive bushing \n219\n such that rotation of the rotary table \n220\n can turn the kelly drive bushing \n219\n and hence the kelly \n218\n.', 'The kelly drive bushing \n219\n can include an inside profile matching an outside profile (e.g., square, hexagonal, etc.) of the kelly \n218\n; however, with slightly larger dimensions so that the kelly \n218\n can freely move up and down inside the kelly drive bushing \n219\n.', 'As to a top drive example, the top drive \n240\n can provide functions performed by a kelly and a rotary table.', 'The top drive \n240\n can turn the drillstring \n225\n.', 'As an example, the top drive \n240\n can include one or more motors (e.g., electric and/or hydraulic) connected with appropriate gearing to a short section of pipe called a quill, that in turn may be screwed into a saver sub or the drillstring \n225\n itself.', 'The top drive \n240\n can be suspended from the traveling block \n211\n, so the rotary mechanism is free to travel up and down the derrick \n214\n.', 'As an example, a top drive \n240\n may allow for drilling to be performed with more joint stands than a kelly/rotary table approach.', 'In the example of \nFIG.', '2\n, the mud tank \n201\n can hold mud, which can be one or more types of drilling fluids.', 'As an example, a wellbore may be drilled to produce fluid, inject fluid or both (e.g., hydrocarbons, minerals, water, etc.).', 'In the example of \nFIG.', '2\n, the drillstring \n225\n (e.g., including one or more downhole tools) may be composed of a series of pipes threadably connected together to form a long tube with the drill bit \n226\n at the lower end thereof.', 'As the drillstring \n225\n is advanced into a wellbore for drilling, at some point in time prior to or coincident with drilling, the mud may be pumped by the pump \n204\n from the mud tank \n201\n (e.g., or other source) via the lines \n206\n, \n208\n and \n209\n to a port of the kelly \n218\n or, for example, to a port of the top drive \n240\n.', 'The mud can then flow via a passage (e.g., or passages) in the drillstring \n225\n and out of ports located on the drill bit \n226\n (see, e.g., a directional arrow).', 'As the mud exits the drillstring \n225\n via ports in the drill bit \n226\n, it can then circulate upwardly through an annular region between an outer surface(s) of the drillstring \n225\n and surrounding wall(s) (e.g., open borehole, casing, etc.), as indicated by directional arrows.', 'In such a manner, the mud lubricates the drill bit \n226\n and carries heat energy (e.g., frictional or other energy) and formation cuttings to the surface where the mud (e.g., and cuttings) may be returned to the mud tank \n201\n, for example, for recirculation (e.g., with processing to remove cuttings, etc.).', 'The mud pumped by the pump \n204\n into the drillstring \n225\n may, after exiting the drillstring \n225\n, form a mudcake that lines the wellbore which, among other functions, may reduce friction between the drillstring \n225\n and surrounding wall(s) (e.g., borehole, casing, etc.).', 'A reduction in friction may facilitate advancing or retracting the drillstring \n225\n.', 'During a drilling operation, the entire drillstring \n225\n may be pulled from a wellbore and optionally replaced, for example, with a new or sharpened drill bit, a smaller diameter drillstring, etc.', 'As mentioned, the act of pulling a drillstring out of a hole or replacing it in a hole is referred to as tripping.', 'A trip may be referred to as an upward trip or an outward trip or as a downward trip or an inward trip depending on trip direction.', 'As an example, consider a downward trip where upon arrival of the drill bit \n226\n of the drillstring \n225\n at a bottom of a wellbore, pumping of the mud commences to lubricate the drill bit \n226\n for purposes of drilling to enlarge the wellbore.', 'As mentioned, the mud can be pumped by the pump \n204\n into a passage of the drillstring \n225\n and, upon filling of the passage, the mud may be used as a transmission medium to transmit energy, for example, energy that may encode information as in mud-pulse telemetry.', 'As an example, mud-pulse telemetry equipment may include a downhole device configured to effect changes in pressure in the mud to create an acoustic wave or waves upon which information may modulated.', 'In such an example, information from downhole equipment (e.g., one or more components of the drillstring \n225\n) may be transmitted uphole to an uphole device, which may relay such information to other equipment for processing, control, etc.', 'As an example, telemetry equipment may operate via transmission of energy via the drillstring \n225\n itself.', 'For example, consider a signal generator that imparts coded energy signals to the drillstring \n225\n and repeaters that may receive such energy and repeat it to further transmit the coded energy signals (e.g., information, etc.).', 'As an example, the drillstring \n225\n may be fitted with telemetry equipment \n252\n that includes a rotatable drive shaft, a turbine impeller mechanically coupled to the drive shaft such that the mud can cause the turbine impeller to rotate, a modulator rotor mechanically coupled to the drive shaft such that rotation of the turbine impeller causes said modulator rotor to rotate, a modulator stator mounted adjacent to or proximate to the modulator rotor such that rotation of the modulator rotor relative to the modulator stator creates pressure pulses in the mud, and a controllable brake for selectively braking rotation of the modulator rotor to modulate pressure pulses.', 'In such example, an alternator may be coupled to the aforementioned drive shaft where the alternator includes at least one stator winding electrically coupled to a control circuit to selectively short the at least one stator winding to electromagnetically brake the alternator and thereby selectively brake rotation of the modulator rotor to modulate the pressure pulses in the mud.', 'In the example of \nFIG.', '2\n, an uphole control and/or data acquisition system \n262\n may include circuitry to sense pressure pulses generated by telemetry equipment \n252\n and, for example, communicate sensed pressure pulses or information derived therefrom for process, control, etc.', 'The assembly \n250\n of the illustrated example includes a logging-while-drilling (LWD) module \n254\n, a measurement-while-drilling (MWD) module \n256\n, an optional module \n258\n, a rotary-steerable system (RSS) and/or motor \n260\n, and the drill bit \n226\n.', 'Such components or modules may be referred to as tools where a drillstring can include a plurality of tools.', 'As to a RSS, it involves technology utilized for directional drilling.', 'Directional drilling involves drilling into the Earth to form a deviated bore such that the trajectory of the bore is not vertical; rather, the trajectory deviates from vertical along one or more portions of the bore.', 'As an example, consider a target that is located at a lateral distance from a surface location where a rig may be stationed.', 'In such an example, drilling can commence with a vertical portion and then deviate from vertical such that the bore is aimed at the target and, eventually, reaches the target.', 'Directional drilling may be implemented where a target may be inaccessible from a vertical location at the surface of the Earth, where material exists in the Earth that may impede drilling or otherwise be detrimental (e.g., consider a salt dome, etc.), where a formation is laterally extensive (e.g., consider a relatively thin yet laterally extensive reservoir), where multiple bores are to be drilled from a single surface bore, where a relief well is desired, etc.', 'One approach to directional drilling involves a mud motor; however, a mud motor can present some challenges depending on factors such as rate of penetration (ROP), transferring weight to a bit (e.g., weight on bit, WOB) due to friction, etc.', 'A mud motor can be a positive displacement motor (PDM) that operates to drive a bit during directional drilling.', 'A PDM operates as drilling fluid is pumped through it where the PDM converts hydraulic power of the drilling fluid into mechanical power to cause the bit to rotate.', 'A PDM can operate in a so-called sliding mode, when the drillstring is not rotated from the surface.', 'A RSS can drill directionally where there is continuous rotation from surface equipment, which can alleviate the sliding of a steerable motor (e.g., a PDM).', 'A RSS may be deployed when drilling directionally (e.g., deviated, horizontal, or extended-reach wells).', 'A RSS can aim to minimize interaction with a borehole wall, which can help to preserve borehole quality.', 'A RSS can aim to exert a relatively consistent side force akin to stabilizers that rotate with the drillstring or orient the bit in the desired direction while continuously rotating at the same number of rotations per minute as the drillstring.', 'The LWD module \n254\n may be housed in a suitable type of drill collar and can contain one or a plurality of selected types of logging tools (e.g., NMR unit or units, etc.).', 'It will also be understood that more than one LWD and/or MWD module can be employed, for example, as represented by the module \n256\n of the drillstring assembly \n250\n.', 'Where the position of an LWD module is mentioned, as an example, it may refer to a module at the position of the LWD module \n254\n, the module \n256\n, etc.', 'An LWD module can include capabilities for measuring, processing, and storing information, as well as for communicating with the surface equipment.', 'In the illustrated example, the LWD module \n254\n may include a seismic measuring device, an NMR measuring device, etc.', 'The MWD module \n256\n may be housed in a suitable type of drill collar and can contain one or more devices for measuring characteristics of the drillstring \n225\n and the drill bit \n226\n.', 'As an example, the MWD tool \n254\n may include equipment for generating electrical power, for example, to power various components of the drillstring \n225\n.', 'As an example, the MWD tool \n254\n may include the telemetry equipment \n252\n, for example, where the turbine impeller can generate power by flow of the mud; it is understood that other power and/or battery systems may be employed for purposes of powering various components.', 'As an example, the MWD module \n256\n may include one or more of the following types of measuring devices: a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device.', 'As an example, one or more NMR measuring devices (e.g., NMR units, etc.) may be included in a drillstring (e.g., a BHA, etc.) where, for example, measurements may support one or more of geosteering, geostopping, trajectory optimization, etc.', 'As an example, motion characterization data can be utilized for control of NMR measurements (e.g., acquisition, processing, quality assessment, etc.).', 'FIG.', '2\n also shows some examples of types of holes that may be drilled.', 'For example, consider a slant hole \n272\n, an S-shaped hole \n274\n, a deep inclined hole \n276\n and a horizontal hole \n278\n.', 'As an example, a drilling operation can include directional drilling where, for example, at least a portion of a well includes a curved axis.', 'For example, consider a radius that defines curvature where an inclination with regard to the vertical may vary until reaching an angle between about 30 degrees and about 60 degrees or, for example, an angle to about 90 degrees or possibly greater than about 90 degrees.', 'As an example, a trajectory and/or a drillstring may be characterized in part by a dogleg severity (DLS), which can be a two-dimensional parameter specified in degrees per 30 meters (e.g., or degrees per 100 feet).', 'As an example, a directional well can include several shapes where each of the shapes may aim to meet particular operational demands.', 'As an example, a drilling process may be performed on the basis of information as and when it is relayed to a drilling engineer.', 'As an example, inclination and/or direction may be modified based on information received during a drilling process.', 'As an example, deviation of a bore may be accomplished in part by use of a downhole motor and/or a turbine.', 'As to a motor, for example, a drillstring can include a positive displacement motor (PDM).', 'As an example, a system may be a steerable system and include equipment to perform a method such as geosteering.', 'As mentioned, a steerable system can be or include an RSS.', 'As an example, a steerable system can include a PDM or a turbine on a lower part of a drillstring where, just above a drill bit, a bent sub can be mounted.', 'As an example, above a PDM, MWD equipment that provides real time or near real time data of interest (e.g., inclination, direction, pressure, temperature, real weight on the drill bit, torque stress, etc.) and/or LWD equipment may be installed.', 'As to the latter, LWD equipment can make it possible to send to the surface various types of data of interest, including for example, geological data (e.g., gamma ray log, resistivity, density and sonic logs, etc.).', 'The coupling of sensors providing information on the course of a well trajectory, in real time or near real time, with, for example, one or more logs characterizing the formations from a geological viewpoint, can allow for implementing a geosteering method.', 'Such a method can include navigating a subsurface environment, for example, to follow a desired route to reach a desired target or targets.', 'As an example, a drillstring can include an azimuthal density neutron (ADN) tool for measuring density and porosity; a MWD tool for measuring inclination, azimuth and shocks; a compensated dual resistivity (CDR) tool for measuring resistivity and gamma ray related phenomena; a combinable magnetic resonance (CMR) tool for measuring properties (e.g., relaxation properties, etc.); one or more variable gauge stabilizers; one or more bend joints; and a geosteering tool, which may include a motor and optionally equipment for measuring and/or responding to one or more of inclination, resistivity and gamma ray related phenomena.', 'As an example, geosteering can include intentional directional control of a wellbore based on results of downhole geological logging measurements in a manner that aims to keep a directional wellbore within a desired region, zone (e.g., a pay zone), etc.', 'As an example, geosteering may include directing a wellbore to keep the wellbore in a particular section of a reservoir, for example, to minimize gas and/or water breakthrough and, for example, to maximize economic production from a well that includes the wellbore.\n \nReferring again to \nFIG.', '2\n, the wellsite system \n200\n can include one or more sensors \n264\n that are operatively coupled to the control and/or data acquisition system \n262\n.', 'As an example, a sensor or sensors may be at surface locations.', 'As an example, a sensor or sensors may be at downhole locations.', 'As an example, a sensor or sensors may be at one or more remote locations that are not within a distance of the order of about one hundred meters from the wellsite system \n200\n.', 'As an example, a sensor or sensor may be at an offset wellsite where the wellsite system \n200\n and the offset wellsite are in a common field (e.g., oil and/or gas field).', 'As an example, one or more of the sensors \n264\n can be provided for tracking pipe, tracking movement of at least a portion of a drillstring, etc.\n \nAs an example, the system \n200\n can include one or more sensors \n266\n that can sense and/or transmit signals to a fluid conduit such as a drilling fluid conduit (e.g., a drilling mud conduit).', 'For example, in the system \n200\n, the one or more sensors \n266\n can be operatively coupled to portions of the standpipe \n208\n through which mud flows.', 'As an example, a downhole tool can generate pulses that can travel through the mud and be sensed by one or more of the one or more sensors \n266\n.', 'In such an example, the downhole tool can include associated circuitry such as, for example, encoding circuitry that can encode signals, for example, to reduce demands as to transmission.', 'As an example, circuitry at the surface may include decoding circuitry to decode encoded information transmitted at least in part via mud-pulse telemetry.', 'As an example, circuitry at the surface may include encoder circuitry and/or decoder circuitry and circuitry downhole may include encoder circuitry and/or decoder circuitry.', 'As an example, the system \n200\n can include a transmitter that can generate signals that can be transmitted downhole via mud (e.g., drilling fluid) as a transmission medium.', 'As an example, data acquired by an NMR unit may be processed in a manner that can reduce data load, which can facilitate transmission.', 'For example, consider downhole processing of NMR measurements to reduce a total number of bits to be transmitted (e.g., consider downhole data compression, downhole data analysis, etc.).', 'As mentioned, a drillstring can include various tools that may make measurements.', 'As an example, a wireline tool or another type of tool may be utilized to make measurements.', 'As an example, a tool may be configured to acquire electrical borehole images.', 'As an example, the fullbore Formation MicroImager (FMI) tool (Schlumberger Limited, Houston, Texas) can acquire borehole image data.', 'A data acquisition sequence for such a tool can include running the tool into a borehole with acquisition pads closed, opening and pressing the pads against a wall of the borehole, delivering electrical current into the material defining the borehole while translating the tool in the borehole, and sensing current remotely, which is altered by interactions with the material.', 'Analysis of formation information may reveal features such as, for example, vugs, dissolution planes (e.g., dissolution along bedding planes), stress-related features, dip events, etc.', 'As an example, a tool may acquire information that may help to characterize a reservoir, optionally a fractured reservoir where fractures may be natural and/or artificial (e.g., hydraulic fractures).', 'As an example, information acquired by a tool or tools may be analyzed using a framework such as the TECHLOG framework.', 'As an example, the TECHLOG framework can be interoperable with one or more other frameworks such as, for example, the PETREL framework.\n \nFIG.', '3\n shows an example of a system \n300\n that includes a drilling workflow framework \n301\n, a seismic-to-simulation framework \n302\n, a drilling framework \n304\n, a client layer \n310\n, an applications layer \n340\n and a storage layer \n360\n.', 'As shown the client layer \n310\n can be in communication with the applications layer \n340\n and the applications layer \n340\n can be in communication with the storage layer \n360\n.', 'In such an example, a computational framework may be provided for handling of logging measurements and/or data derived from logging measurements.', 'For example, logging information may be provided to the seismic-to-simulation framework \n302\n and/or to the drilling framework \n304\n.', 'Such information may be utilized for model building (e.g., constructing a multidimensional model of a geologic environment), generating a trajectory for a well (e.g., or an extension thereof), generating a stimulation plan (e.g., fracturing, chemical treatment, etc.), controlling one or more drilling operations, etc.', 'In the example of \nFIG.', '3\n, the client layer \n310\n can include features that allow for access and interactions via one or more private networks \n312\n, one or more mobile platforms and/or mobile networks \n314\n and via the “cloud” \n316\n, which may be considered to include distributed equipment that forms a network such as a network of networks.', 'In the example of \nFIG.', '3', ', the applications layer \n340\n includes the drilling workflow framework \n301\n.', 'The applications layer \n340\n also includes a database management component \n342\n that includes one or more search engine features (e.g., sets of executable instructions to perform various actions, etc.).', 'As an example, one or more components may optionally be implemented within a framework or, for example, in a manner operatively coupled to a framework (e.g., as an add-on, a plug-in, etc.).', 'As an example, a component for structuring search results (e.g., in a list, a hierarchical tree structure, etc.) may optionally be implemented within a framework or, for example, in a manner operatively coupled to a framework (e.g., as an add-on, a plug-in, etc.).', 'In the example of \nFIG.', '3\n, the applications layer \n340\n can include communicating with one or more resources such as, for example, the seismic-to-simulation framework \n302\n, the drilling framework \n304\n and/or one or more sites, which may be or include one or more offset wellsites.', 'As an example, the applications layer \n340\n may be implemented for a particular wellsite where information can be processed as part of a workflow for operations such as, for example, operations performed, being performed and/or to be performed at the particular wellsite.', 'As an example, an operation may involve directional drilling, for example, via geosteering.', 'As an example, an operation may involve logging via one or more downhole tools.', 'In the example of \nFIG.', '3\n, the storage layer \n360\n can include various types of data, information, etc., which may be stored in one or more databases \n362\n.', 'As an example, one or more servers \n364\n may provide for management, access, etc., to data, information, etc., stored in the one or more databases \n362\n.', 'As an example, the database management component \n342\n may provide for searching as to data, information, etc., stored in the one or more databases \n362\n.', 'As an example, the system \n300\n of \nFIG.', '3\n may be implemented to perform one or more portions of one or more workflows associated with the system \n200\n of \nFIG.', '2\n.', 'As an example, the drilling workflow framework \n301\n may interact with a technical data framework (e.g., a logging data framework, etc.) and the drilling framework \n304\n before, during and/or after performance of one or more drilling operations.', 'In such an example, the one or more drilling operations may be performed in a geologic environment (see, e.g., the environment \n120\n of \nFIG.', '1\n) using one or more types of equipment (see, e.g., equipment of \nFIGS.', '1\n and \n2\n).', 'As an example, an architecture utilized in a system such as, for example, the system \n300\n, may include features of the AZURE architecture (Microsoft Corporation, Redmond, Washington).', 'As an example, a cloud portal block can include one or more features of an AZURE portal that can manage, mediate, etc. access to one or more services, data, connections, networks, devices, etc.', 'As an example, the system \n300\n may include features of the GOOGLE cloud architecture (Google, Mountain View, California).', 'As an example, the system \n300\n can include a cloud computing platform and infrastructure, for example, for building, deploying, and managing applications and services (e.g., through a network of datacenters, etc.).', 'As an example, such a cloud platform may provide PaaS and IaaS services and support one or more different programming languages, tools and frameworks, etc.\n \nFIG.', '4\n shows an example of a wellsite system \n400\n, specifically, \nFIG.', '4\n shows the wellsite system \n400\n in an approximate side view and an approximate plan view along with a block diagram of a system \n470\n.', 'In the example of \nFIG.', '4\n, the wellsite system \n400\n can include a cabin \n410\n, a rotary table \n422\n, drawworks \n424\n, a mast \n426\n (e.g., optionally carrying a top drive, etc.), mud tanks \n430\n (e.g., with one or more pumps, one or more shakers, etc.), one or more pump buildings \n440\n, a boiler building \n442\n, a hydraulic pumping units (HPU) building \n444\n (e.g., with a rig fuel tank, etc.), a combination building \n448\n (e.g., with one or more generators, etc.), pipe tubs \n462\n, a catwalk \n464\n, a flare \n468\n, etc.', 'Such equipment can include one or more associated functions and/or one or more associated operational risks, which may be risks as to time, resources, and/or humans.', 'A wellsite can include a prime mover as a source of power.', 'As an example, a prime mover can include one to four or more diesel engines, which may produce several thousand horsepower.', 'Such engines can be operatively coupled to one or more electric generators.', 'Electrical power may be distributed by a silicon-controlled-rectifier (SCR) system.', 'Rigs that convert diesel power to electricity may be referred to as electric rigs or diesel electric rigs.', 'As an example, a rig can be configured for transmission of power from one or more diesel engines to one or more rig components (e.g., drawworks, pumps, rotary table, etc.) through mechanical belts, chains, clutches, etc.', 'Such a configuration may be referred to a mechanical rig or a so-called “power rig”.', 'As shown in the example of \nFIG.', '4\n, the wellsite system \n400\n can include a system \n470\n that includes one or more processors \n472\n, memory \n474\n operatively coupled to at least one of the one or more processors \n472\n, instructions \n476\n that can be, for example, stored in the memory \n474\n, and one or more interfaces \n478\n.', 'As an example, the system \n470\n can include one or more processor-readable media that include processor-executable instructions executable by at least one of the one or more processors \n472\n to cause the system \n470\n to control one or more aspects of the wellsite system \n400\n.', 'In such an example, the memory \n474\n can be or include the one or more processor-readable media where the processor-executable instructions can be or include instructions.', 'As an example, a processor-readable medium can be a computer-readable storage medium that is not a signal and that is not a carrier wave.\n \nFIG.', '', '4\n also shows a battery \n480\n that may be operatively coupled to the system \n470\n, for example, to power the system \n470\n.', 'As an example, the battery \n480\n may be a back-up battery that operates when another power supply is unavailable for powering the system \n470\n.', 'As an example, the battery \n480\n may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery \n480\n can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a system management bus (SMBus) or other type of bus.', 'In the example of \nFIG.', '4\n, services \n490\n are shown as being available, for example, via a cloud platform.', 'Such services can include data services \n492\n, query services \n494\n and drilling services \n496\n.', 'As an example, the services \n490\n may be part of a system such as the system \n300\n of \nFIG.', '3\n.', 'As an example, a system such as, for example, the system \n300\n of \nFIG.', '3\n may be utilized to perform a workflow.', 'Such a system may be distributed and allow for collaborative workflow interactions and may be considered to be a platform (e.g., a framework for collaborative interactions, etc.).', 'As an example, a workflow can commence with an evaluation stage, which may include a geological service provider evaluating a formation.', 'As an example, a geological service provider may undertake the formation evaluation using a computing system executing a software package tailored to such activity; or, for example, one or more other suitable geology platforms may be employed (e.g., alternatively or additionally).', 'As an example, the geological service provider may evaluate the formation, for example, using earth models, geophysical models, basin models, petrotechnical models, combinations thereof, and/or the like.', 'Such models may take into consideration a variety of different inputs, including offset well data, seismic data, pilot well data, other geologic data, etc.', 'The models and/or the input may be stored in the database maintained by the server and accessed by the geological service provider.', 'As an example, a workflow may progress to a geology and geophysics (“G&G”) service provider, which may generate a well trajectory, which may involve execution of one or more G&G software packages.', 'Examples of such software packages include the PETREL framework.', 'As an example, a system or systems may utilize a framework such as the DELFI framework (Schlumberger Limited, Houston, Texas).', 'Such a framework may operatively couple various other frameworks to provide for a multi-framework workspace.', 'As an example, a G&G service provider may determine a well trajectory or a section thereof, based on, for example, one or more model(s) provided by a formation evaluation, and/or other data, e.g., as accessed from one or more databases (e.g., maintained by one or more servers, etc.).', 'As an example, a well trajectory may take into consideration various “basis of design” (BOD) constraints, such as general surface location, target (e.g., reservoir) location, and the like.', 'As an example, a trajectory may incorporate information about tools, bottom-hole assemblies, casing sizes, etc., that may be used in drilling the well.', 'A well trajectory determination may take into consideration a variety of other parameters, including risk tolerances, fluid weights and/or plans, bottom-hole pressures, drilling time, etc.', 'Well planning can include determining a path of a well that can extend to a reservoir, for example, to economically produce fluids such as hydrocarbons therefrom.', 'Well planning can include selecting a drilling and/or completion assembly which may be used to implement a well plan.', 'As an example, various constraints can be imposed as part of well planning that can impact design of a well.', 'As an example, such constraints may be imposed based at least in part on information as to known geology of a subterranean domain, presence of one or more other wells (e.g., actual and/or planned, etc.) in an area (e.g., consider collision avoidance), etc.', 'As an example, one or more constraints may be imposed based at least in part on characteristics of one or more tools, components, etc.', 'As an example, one or more constraints may be based at least in part on factors associated with drilling time and/or risk tolerance.\n \nFIG.', '5\n shows an example of an environment \n501\n that includes a subterranean portion \n503\n where a rig \n510\n is positioned at a surface location above a bore \n520\n.', 'In the example of \nFIG.', '5\n, various wirelines services equipment can be operated to perform one or more wirelines services including, for example, acquisition of data from one or more positions within the bore \n520\n.', 'In the example of \nFIG.', '5\n, the bore \n520\n includes drillpipe \n522\n, a casing shoe \n524\n, a cable side entry sub (CSES) \n523\n, a wet-connector adaptor \n526\n and an openhole section \n528\n.', 'While the drillpipe \n522\n is shown in the example of \nFIG.', '5\n along with casing, wireline operations may be performed in bores with or without drillpipe, with or without casing, etc.', 'As an example, the bore \n520\n can be a vertical bore or a deviated bore where one or more portions of the bore may be vertical and one or more portions of the bore may be deviated, including substantially horizontal.', 'In the example of \nFIG.', '5\n, the CSES \n523\n includes a cable clamp \n525\n, a packoff seal assembly \n527\n and a check valve \n529\n.', 'These components can provide for insertion of a logging cable \n530\n that includes a portion \n532\n that runs outside the drillpipe \n522\n to be inserted into the drillpipe \n522\n such that at least a portion \n534\n of the logging cable runs inside the drillpipe \n522\n.', 'In the example of \nFIG.', '5\n, the logging cable \n530\n runs past the wet-connect adaptor \n526\n and into the openhole section \n528\n to a logging string \n540\n.', 'As shown in the example of \nFIG.', '5\n, a logging truck \n550\n (e.g., a wirelines services vehicle) can deploy the wireline \n530\n under control of a system \n560\n.', 'As shown in the example of \nFIG.', '5\n, the system \n560\n can include one or more processors \n562\n, memory \n564\n operatively coupled to at least one of the one or more processors \n562\n, instructions \n566\n that can be, for example, stored in the memory \n564\n, and one or more interfaces \n568\n.', 'As an example, the system \n560\n can include one or more processor-readable media that include processor-executable instructions executable by at least one of the one or more processors \n562\n to cause the system \n560\n to control one or more aspects of equipment of the logging string \n540\n and/or the logging truck \n550\n.', 'In such an example, the memory \n564\n can be or include the one or more processor-readable media where the processor-executable instructions can be or include instructions.', 'As an example, a processor-readable medium can be a computer-readable storage medium that is not a signal and that is not a carrier wave.\n \nFIG.', '', '5\n also shows a battery \n570\n that may be operatively coupled to the system \n560\n, for example, to power the system \n560\n.', 'As an example, the battery \n570\n may be a back-up battery that operates when another power supply is unavailable for powering the system \n560\n (e.g., via a generator of the wirelines truck \n550\n, a separate generator, a power line, etc.).', 'As an example, the battery \n570\n may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery \n570\n can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.', 'As an example, the system \n560\n can be operatively coupled to a client layer \n580\n.', 'In the example of \nFIG.', '5', ', the client layer \n580\n can include features that allow for access and interactions via one or more private networks \n582\n, one or more mobile platforms and/or mobile networks \n584\n and via the “cloud” \n586\n, which may be considered to include distributed equipment that forms a network such as a network of networks.', 'As an example, the system \n560\n can include circuitry to establish a plurality of connections (e.g., sessions).', 'As an example, connections may be via one or more types of networks.', 'As an example, connections may be client-server types of connections where the system \n560\n operates as a server in a client-server architecture.', 'For example, clients may log-in to the system \n560\n where multiple clients may be handled, optionally simultaneously.', 'As an example, the logging string \n540\n can include one or more NMR units, which may be part of one or more tools that are movable via movement of the logging string \n540\n.\n \nFIG.', '6\n shows some examples of systems \n600\n and \n650\n where each of the systems \n600\n and \n650\n is a distributed system, which can be defined as a heterogeneous system.', 'For example, the system \n600\n shows a system X \n610\n and a system Y \n630\n, which can be in communication via one or more types of telemetry technologies.', 'In such an example, the system X \n610\n and the system Y \n630\n can include telemetry circuitry.', 'For example, the system X \n610\n can include a digital decision model (DDM) generator \n612\n that can generate a DDM \n632\n that can be transmitted to the system Y \n630\n.', 'In such an example, the system Y \n630\n can perform one or more actions that depend on the DDM \n632\n as stored local to the system Y \n630\n such as in memory of the system Y \n630\n.', 'As to the example systems \n650\n, these include an implantable medical system \n651\n where equipment is implanted in a mammal such as a human, a space exploration system \n652\n where equipment is in space outside of the atmosphere of the Earth, an implantable structural system \n653\n where equipment is embedded in a physical structure, a remote terrestrial system \n654\n where equipment is located at a location on the Earth or in the Earth, a periodic and/or bandwidth limited telemetry system \n655\n where equipment is configured, located, etc., with limitations, and one or more other types of systems \n656\n.', 'As to the implantable medical system \n651\n, consider an electronic medical therapy delivery system being implanted in a human body via a surgical procedure.', 'In such an example, an external telemetry wand operatively coupled to an external system may be utilized to communicate with the internal, implanted system.', 'In such an example, a hardware upgrade to the internal, implanted system may demand surgery, which may be contraindicated.', 'In such an example, the internal, implantable system may be upgraded via download of an updated DDM.', 'In such an example, the updated DDM may be updated using data acquired by the internal, implantable system and the updated DDM may provide for improved operation of the internal, implantable system (e.g., as to delivery of therapy, sensing signals, detecting conditions, etc.).', 'As to the space exploration system \n652\n, consider a deep space vehicle system that has limited telemetry (e.g., time, bandwidth, etc.)', 'and/or', 'physical condition limited telemetry (e.g., due to location, solar radiation, etc.).', 'In such an example, the deep space vehicle system can include hardware that is not amenable to upgrade and can include memory that can store a DDM, which may be updated via another system such as an Earth-based system or a system based on another planet, vehicle, station, etc.', 'As to the implantable structural system \n653\n, consider a structural sensor system that is embedded in a structure such as a bridge, a dam, a nuclear power plant, a building, etc.', 'In such an example, once embedded, hardware of the structural sensor system can be impractical.', 'As an example, telemetry may be utilized to transmit a DDM to the structural sensor system to thereby update its operation.', 'As to the remote terrestrial system \n654\n, consider an ocean bottom sensor system that is not readily amenable to hardware upgrade.', 'In such an example, telemetry can be utilized to update a DDM of the ocean bottom sensor system.', 'While the ocean is mentioned, consider a mountain deployed sensor system or a harsh environment deployed sensor system.', 'Such examples may be limited in access, hardware upgrade, etc., and benefit from an ability to update a DDM to improve operation.', 'As to the periodic and/or bandwidth limited telemetry system \n655\n, consider location, noise, technology, etc., as some examples of limitations in telemetry.', 'Such a system may benefit from update of a DDM to improve operation.\n \nFIG.', '7\n shows an example of a method \n700\n that includes a performance block \n710\n for performing an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; a transmission block \n720\n for, responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; and a reception block \n730\n for, responsive to the request, receiving an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'As shown, the method \n700\n can also include a performance block \n740\n that performs the operation using the system according to at least one of the at least one new decision state.', 'The method \n700\n of \nFIG.', '7\n is shown as including various computer-readable storage medium (CRM) blocks \n711\n, \n721\n, \n731\n, and \n741\n that can include processor-executable instructions that can instruct a computing system, which can be a control system, to perform one or more of the actions described with respect to the method \n700\n.', 'As shown in the example of \nFIG.', '7\n, the system \n790\n can include one or more computers \n792\n that include one or more processors \n793\n, memory \n794\n operatively coupled to at least one of the one or more processors \n793\n, instructions \n796\n that can be, for example, stored in the memory \n794\n, and one or more interfaces \n795\n.', 'As an example, the system \n790\n can include one or more processor-readable media that include processor-executable instructions executable by at least one of the one or more processors \n793\n to cause the system \n790\n to perform actions such as, for example, one or more actions of the method \n700\n.', 'As an example, the instructions \n796\n can include instructions of one or more of the CRM blocks \n711\n, \n721\n, \n731\n, and \n741\n.', 'The memory \n794\n can be or include the one or more processor-readable media where the processor-executable instructions can be or include instructions.', 'As an example, a processor-readable medium can be a computer-readable storage medium that is non-transitory that is not a signal and that is not a carrier wave.', 'As an example, the system \n790\n can include subsystems.', 'For example, the system \n790\n can include a plurality of subsystems that may operate using equipment that is distributed where a subsystem may be referred to as being a system.', 'For example, consider a downhole tool system and a surface system as described with respect to \nFIG.', '2\n, \nFIG.', '4\n, \nFIG.', '5\n, \nFIG.', '6\n, etc.', 'As an example, operations of the blocks \n710\n, \n720\n, \n730\n and \n740\n of the method \n700\n may be performed using a downhole tool system.', 'The method \n700\n may be implemented using, for example, a downhole system and/or a surface system, which may be a cloud-based or cloud-coupled system.', 'As an example, the method \n700\n can be adaptive in that the digital decision model (DDM) can be utilized to determine a parameter or a parameter set using a first system that acquires measurements and/or results thereof and in that the DDM can be updated using a second system where the updated DDM is transmitted to the first system for further decisions making (e.g., determinations as to one or more parameters, parameter sets, etc.).', 'As an example, a system can perform operations according to one or more timers, event triggers, instructions, etc.', 'For example, one type of remote system may perform sensing operations once a year, such a system takes several years to navigate a digital decision model (DDM); whereas, another type of remote system may perform sensing operations once a minute and be able to navigate a DDM in an hour or less.', 'Such examples demonstrate that time may not necessarily be factor for determining when to update a digital decision model (DDM).', 'As an example, time may be utilized, for example, in combination with a number of operations performed.', 'Consider a system that is expected to perform a sufficient number of operations in a period of time to navigate a DDM to place the DDM in a state that is expected to call for an update.', 'If that system does not call for an update in the period of time, a trigger may be utilized to “check-in” on the DDM to see if there is an issue with the system, the DDM, etc., which may result, for example, in generation of an updated DDM and transmission thereof to the system.', 'As explained, a downhole tool can be a system that may be positioned in different environments where different parameter sets may be utilized.', 'A digital decision model (DDM) can provide for decisions as to selection of appropriate parameter sets for different environments.', 'Such an approach may provide for improved operation of the downhole tool such as improved measurements (e.g., greater SNR), improve efficiency (e.g., power utilization, etc.), or one or more improved performance aspects.', 'Various examples are given with reference to downhole tools such as a downhole tool that can be utilized for NMR logging.', 'Various equipment may be utilized in one or more other types of systems, such as, for example, one or more of the systems \n600\n and \n650\n of \nFIG.', '6\n.', 'As mentioned, a combinable magnetic resonance (CMR) tool can be utilized for NMR logging.', 'As an example, NMR measurements can be utilized for determining one or more of reservoir permeability, water cut, and hydrocarbon pore volume.', 'As an example, NMR measurements may be utilized to evaluate porosity and permeability independent of mineralogy.', 'As an example, NMR measurements may be suitable for characterizing thinly laminated reservoirs; low-contrast, low-resistivity pay zones; and carbonates.', 'As an example, a tool can include circuitry for implementing an enhanced-precision mode (EPM) pulse acquisition scheme to refine precision of NMR data associated with the smallest pores and heavy crude oils.', 'As an example, processing of EPM acquisition data can provide total porosity along with partitioning into micro-, meso-, and macroporosity and estimates of the bound and free fluid.', 'As an example, in complex lithologies, such information can facilitate determining the irreducibile water saturation and potential for water production.', 'As an example, a tool can include magnets such as permanent magnets that may extend above and/or below an antenna, which may be utilized for delivery of an oscillating magnetic field and/or receipt of responses from nuclei to a delivered oscillating magnetic field.', 'As an example, consider a tool that includes magnets arranged above and below (e.g., approximately 12 cm above and approximately 12 cm below) an antenna (e.g., approximately 2.5 cm).', 'Such an arrangement of components can be utilized to create a longer pre-polarizing field that can provide for increased logging speed (e.g., consider logging speeds to 1,200 meters per hour or more in a fast-relaxation environment).', 'As an example, an acquisition scheme can be implemented that provides for increased logging speed, increased vertical resolution and/or an arrangement of components (e.g., magnet(s) and antenna(s)) that may be beneficial to one or more logging operations.', 'As an example, where total acquisition time of an acquisition scheme can be reduced, the length of an NMR unit may be reduced, which may reduce mass and demands of movement of a logging string (e.g., consider lesser energy for rotation of a reel, etc.).', 'FIG.', '8\n shows an example of a method \n800\n with respect to an NMR unit and a sensed region where the method \n800\n includes exposing the sensed region to a static magnetic field of the permanent magnet (or magnets), utilizing an antenna (e.g., or other transmitter) to generate an oscillating field that penetrates the sensed region, and utilizing the antenna (e.g., as a receiver) to receive energy released by nuclei in the sensed region.', 'As shown, one or more components can be eccentric such that the NMR unit can have an orientation with respect to the sensed region, which can be a portion of a wall of a borehole.\n \nFIG.', '8\n also shows an example of a tool \n850\n, which can include one or more features such as a stabilizer, a pad, a turbine, etc.', 'The tool \n850\n includes an NMR unit \n870\n, for which an approximate cross-sectional view along a line A-A is shown.', 'In the cross-sectional view, the NMR unit \n870\n is shown to include magnets \n872\n, an antenna \n874\n and circuitry \n880\n, which can include RF emission circuitry, antenna circuitry and analog-to-digital conversion circuitry (e.g., an analog-to-digital converter (ADC)).', 'As an example, the NMR unit \n870\n can include one or more passages for one or more conduits.', 'For example, consider a power conduit, a data transmission conduit, a power and data conduit, etc.', 'As an example, the tool \n850\n can include a power source or be operatively coupled to a power source, which may be a fluid driven turbine (e.g., turbogenerator, etc.), a surface power source (see, e.g., the logging truck \n550\n, the battery \n570\n, etc.).', 'As an example, a power source may be a power grid, a generator (e.g., gas, wind, fuel, etc.), a solar panel, a battery, etc.', 'As to the circuitry \n880\n, it can include one or more processors and memory accessible to at least one of the one or more processors.', 'For example, the circuitry \n880\n can include a processor that executes instructions that control energy emissions to generate an oscillating magnetic field, as may be according to a programmed pulse sequence.', 'As an example, the circuitry \n880\n can include one or more switches, which may be operatively coupled to sources of energy, which can include a source to generate pulsed emissions and/or a source that is an antenna or antennas that receive signals from nuclei in a formation.', 'For example, a switch may act to control an antenna to use the antenna for transmission of energy and then to use the antenna for reception of energy.', 'Received energy can be directed to an analog-to-digital converter that can convert analog signals to digital data according to a selected sampling rate and/or bit depth.', 'As an example, the digital data can be stored to memory and optionally processed by the processor (e.g., downhole) and/or transmitted to another processor, storage device, etc., which may be uphole or part of the downhole tool or another downhole tool.', 'As an example, a processor or processors can be configured using executable instructions to perform one or more operations on data such as, for example, inversion to derive one or more values (e.g., T\n2 \nvalues, T\n1 \nvalues, etc.).', 'As shown in the example of \nFIG. \n8\n, the circuitry \n880\n can include a sequencer \n882\n, a transmitter \n884\n, a receiver \n886\n, and an ADC \n888\n.', 'The sequencer \n882\n can include instructions or otherwise be instructed to control the transmitter \n884\n, which can be operatively coupled to the antenna \n874\n for transmission of oscillating magnetic fields.', 'The receiver \n886\n can be operatively coupled to the antenna \n874\n for reception of echo signals where such signals can be in analog form and converted into digital echo data using the ADC \n888\n.', 'As shown in the example of \nFIG. \n8\n, other circuitry \n889\n can be included, which may be operatively coupled to one or more data and/or power lines.', 'For example, consider one or more data and/or power lines operatively coupled to an uphole (e.g., surface) unit or system.', 'As an example, the sequencer \n882\n may be programmable via instructions, commands, etc., received from memory locally, from a surface unit or system, another component of a downhole string, etc.', 'As an example, a method can include controlling emissions, which may be via RF emission circuitry.', 'As an example, such circuitry can include the sequencer \n882\n and the transmitter \n884\n as operatively coupled to the antenna \n874\n.', 'As an example, a method can include acquiring digital echo data, which may be via antenna circuitry and analog-to-digital conversion circuitry.', 'As an example, such circuitry can include the antenna \n874\n, the receiver \n886\n and the ADC \n888\n.', 'As an example, compression circuitry may be included to compress digital echo data (e.g., consider one or more of window summing, singular value decomposition, etc.).', 'Data compression may reduce data density for transmission of data uphole to a surface unit or system (e.g., via the circuitry \n889\n, etc.).', 'As an example, the tool \n850\n can be dimensioned for receipt in a borehole with a diameter of approximately 10 cm or more, which may depend on features such as a centralizer, pads, etc.', 'As an example, the tool \n850\n can be of a maximum diameter of a tool body of approximately 5 cm or more.', 'For example, consider an outer tool body diameter of approximately 12 cm at an NMR unit (e.g., an NMR unit with a 12 cm cross-sectional dimension).', 'As an example, an NMR unit can be skid-mounted to cut through mud cake and for contact with a formation.', 'As an example, contact may be enhanced through one or more components such as an eccentralizing arm or power calipers.', 'As mentioned, internal permanent magnets can be utilized to provide a static polarizing magnetic field.', 'As an example, an NMR unit may be sensitive to a volume of about 1 cm to 3 cm or more into a formation where the volume may extend a length of an antenna along a longitudinal axis of the NMR unit (e.g., 5 cm to 15 cm or more), which can be a factor in vertical resolution.', 'As an example, an antenna can be operated as a transmitter, a receiver or both a transmitter and a receiver.', 'As a transmitter, an antenna can transmit a sequence for an oscillating magnetic field (e.g., consider a CPMG pulse sequence, etc.).', 'As a receiver, an antenna can receive pulse echoes from a formation, including substances in the formation such as one or more fluids.\n \nFIG.', '9\n shows an example of a system \n900\n with respect to a subsurface region that includes a surface \n901\n, various types of formations \n902\n-N-\n3\n, \n902\n-N-\n2\n, \n902\n-N-\n1\n, and \n902\n-N, which may be referred to as formations \n902\n or individually as individual formations, and that includes a borehole \n905\n where the formations \n902\n define a wall of the borehole (e.g., a borehole wall).', 'As shown in the example of \nFIG.', '9\n, the formations \n902\n can be of different thicknesses, of different materials, and may be disposed at different angles with respect to the surface \n901\n.', 'As an example, the borehole \n905\n may be vertical or deviated.', 'As an example, the borehole \n905\n may include a vertical portion and a deviated portion.', 'As an example, in a deviated portion, the borehole \n905\n may traverse the formations \n902\n in a manner that increases path length such that the path length of the borehole \n905\n in each of the formations \n902\n is greater than the thickness of each of the formations \n902\n.', 'As shown in the example of \nFIG.', '9\n, the system \n900\n includes surface equipment \n910\n, telemetry medium and/or equipment \n930\n and NMR equipment \n950\n.', 'As explained, whether the system \n900\n includes drilling equipment or logging equipment, the NMR equipment \n950\n can move in the borehole \n905\n.', 'For example, the NMR equipment \n950\n can be tripped in, move with drilling, tripped out, maintained at a stationary position, etc.', 'As to movement of the NMR equipment \n950\n, it may be referenced with respect to spatial coordinates, which may provide for a measured depth and/or a vertical depth.', 'As an example, movement along the borehole \n905\n can be characterized with respect to velocity, acceleration, translation, vibration, rotation, etc.', 'In the example of \nFIG.', '9\n, the NMR equipment \n950\n can be operated to acquire NMR data for the different formations \n902\n.', 'Where the formations \n902\n differ in their materials (e.g., types of materials, composition of materials, etc.), the NMR equipment \n950\n may operate more efficiently when an acquisition protocol is matched to one or more formation characteristics.', 'For example, formation characteristics may result in different relaxation time constants (e.g., T\n1 \nand/or T\n2\n).', 'In such an example, an acquisition protocol for a slow T\n2 \n(e.g., AP\n1\n) may differ from an acquisition protocol for a fast T\n2 \n(e.g., AP\n2\n).', 'In such an example, if AP\n1\n is applied to a non-optimal formation type (e.g., fast T\n2\n), the resulting NMR data may be of lesser quality.', 'For example, the NMR data may be of a lower signal to noise ratio (SNR).', 'As an example, for NMR measurements, an acquisition protocol (AP) may be characterized by a pulse sequence (PS).', 'As an example, the NMR equipment \n950\n can include circuitry that can automatically change an AP, which can include changing a PS.', 'As an example, the system \n900\n can include computational resources that can automatically adjust the NMR equipment \n950\n, which may be responsive to a formation characteristic.', 'In such an example, the telemetry medium and/or equipment \n930\n may be adjusted.', 'For example, consider an adjustment to telemetry mode, compression of data, organization of data, etc.', 'As an example, as the NMR equipment \n950\n moves in the borehole \n905\n, the NMR equipment \n950\n may be adjusted in real time such that one or more adjustments are made to the NMR equipment \n950\n based on one or more formation characteristics of the formations \n902\n.', 'Such an approach may provide for more efficient operation of the NMR equipment \n950\n, which may provide improved SNR, improved power utilization, improved telemetry, etc.', 'As an example, the NMR equipment \n950\n can automatically adjust acquisition, for example, by selecting a particular acquisition protocol (AP) from a group of acquisition protocols (APs).', 'As an example, an automatic adjustment may include adjusting one or more parameters of an acquisition protocol (AP).', 'As an example, the NMR equipment \n950\n can include and/or be operatively coupled to a trained machine model that can receive input and generate output.', 'In such an example, the output may be utilized to control operation of the NMR equipment \n950\n.', 'As mentioned with respect to \nFIG.', '8', ', the NMR unit \n870\n (e.g., NMR equipment) can include the circuitry \n880\n.', 'Such circuitry may be “lightweight”.', 'As an example, NMR equipment can include a microprocessor that has associated specifications.', 'For example, consider a microprocessor with a relatively low clock rate (e.g., less than 100 MHz).', 'As an example, NMR equipment can include memory that has associated specifications.', 'For example, consider random access memory (RAM) with a relatively low amount of memory (e.g., less than 10 MB).', 'FIG.', '10\n shows an example of a microprocessor \n1000\n that may be utilized in a downhole tool such as an NMR unit (e.g., NMR equipment) along with an example of circuitry \n1080\n that can include a plurality of microprocessors \n1000\n-\n1\n, \n1000\n-\n2\n, \n1000\n-\n3\n, \n1000\n-\n4\n, and \n1000\n-\n5\n.', 'As shown, the circuitry \n1080\n can include a modem processor \n1000\n-\n1\n, a controller processor \n1000\n-\n2\n, a sequencer processor \n1000\n-\n3\n, a processing and diagnostics processor \n1000\n-\n4\n, and an acquisition processor \n1000\n-\n5\n.', 'Also shown in the example circuitry \n1080\n of \nFIG.', '10\n are memory, an ADC, a transmitter, a receiver and an antenna (see, e.g., the circuitry \n880\n of \nFIG.', '8\n).', 'As an example, the microprocessor \n1000\n can include various features such as registers, cache, memory (e.g., for instructions and data), busses, a clock, address generators, interrupts, logic units, etc.', 'As an example, the microprocessor \n1000\n can include various features of an INTEL Corporation (Sunnyvale, California) microprocessor such as one or more of the NIOS family microprocessors (e.g., NIOS II, etc.).', 'As an example, a microprocessor such as the microprocessor \n1000\n may be utilized with and/or include one or more features of a device such as the CYCLONE device (Altera, San Jose, California).', 'For example, a CYCLONE III device can include a NIOS II family microprocessor.', 'The NIOS II family of microprocessors includes a 32-bit embedded-processor architecture designed specifically for the ALTERA family of field-programmable gate array (FPGA) integrated circuits.', 'A NIOS II processor can include an instruction cache, 60 MHz clock, hardware multipliers, external SRAM (for executable code and data) such as 2 MB on a modem and on a sequencer and 4 MB on a controller along with 8 MB external cache for storing FPGA image and software and a 4 GB recording cache (controller coupled).', 'In such an example, each FPGA can possess “system on a chip” (SoC) characteristics and custom instructions to tailor functionality to the specific portion of circuitry.\n \nFIG.', '11\n shows an example of a graphical user interface (GUI) \n1100\n that includes graphics derived from NMR data as acquired by an NMR unit of a downhole tool.', 'The GUI \n1100\n shows four tracks in log form, with respect to depth and various other scales.', 'The GUI \n1100\n may include, for example, a gamma ray track, which may help to provide indication of position (e.g., depth, measured depth, etc.).', 'As shown, the first track includes a plot of total porosity (e.g., lithology-independent), the second track includes graphics of volumes of clay-bound water, capillary-bound water, and free fluid derived from a measured T\n2 \ndistribution, the third track includes permeability estimate graphics as derived using Timur-Coates and Schlumberger-Doll-Research (SDR) permeability equations and the fourth track includes the measured T\n2 \ndistribution as well as the logarithmic mean T\n2 \nvalues at various depths.', 'As to depth, indicators as to 25 and 50 are shown, which can be utilized to determine a resolution (e.g., a vertical resolution, which may be with respect to a direction in vertical depth or a direction in measured depth).', 'As may be appreciated, a higher vertical resolution can provide greater insight into characteristics of a formation.', 'As an example, a tool for NMR can include multiple sensors, including a large antenna for fluid characterization and complementary small aperture antennae for high-resolution acquisition modes.', 'As an example, an automated switching method may optionally include switching of an antenna.', 'As an example, a tool for NMR can include sensors that can be operated either separately or simultaneously at various logging speeds.', 'For example, consider a tool that can operate at logging speeds up to 1,000 meters per hour or more.', 'As an example, a tool for NMR can provide for analyses of responses for high-resolution identification of long T\n1 \nfluids such as light hydrocarbons.', 'As to logging speed, consider the logging truck \n550\n of \nFIG.', '5\n as including a reel (e.g., a wireline reel, coiled tubing reel, etc.) that can be rotated by a motor to cause the logging string \n540\n to translate in the openhole section \n528\n, which can be directional such as toward the end of the borehole (inwardly) or toward the surface of the borehole (outwardly).', 'Such directional movement may be referred to as tripping in or tripping out.', 'The logging speed can depend on the type of pulse sequence utilized for NMR and/or a switching method may include selecting a pulse sequence using one or more motion signals, etc.', 'As an example, a pulse sequence that takes more time can result in slower logging speeds while a sequence that takes lesser time may result in faster logging speeds (e.g., depending on physical constraints of a system, an environment, etc.).', 'In the example of \nFIG.', '5\n, the logging truck \n550\n can include the system \n560\n where the system \n560\n controls a reel that controls movement of the logging string \n540\n.', 'For example, rotation of the reel can be controlled to achieve a desired logging speed of the logging string \n540\n.', 'As an example, logging may occur with continuous motion or with starts and stops.', 'As an example, a logging speed may be an average speed that includes time(s) associated with one or more stop/start cycles.', 'Referring again to the GUI \n1100\n and the fourth track, T\n2 \ndistributions are illustrated graphically for a series of depths.', 'The GUI \n1100\n shows a single T\n2 \ndistribution amplified to demonstrate that T\n2 \nvalues can have a peak or peaks for a volume of investigation at a particular depth.', 'As an example, a higher vertical resolution can provide for more T\n2 \ndistributions over a particular segment of a borehole.', 'As an example, a sequence that can be executed in lesser time with acceptable data quality can provide for a greater logging speed, which may allow for receiving data for a segment of a borehole in a shorter period of time (e.g., more rapid formation evaluation, etc.).', 'As an example, a method can include various parameters such as a speed parameter, a number of NMR measurements at different depths per unit time parameter, a sequence duration parameter, a maximum speed parameter as to NMR measurements, a maximum speed parameter as to physical constraints on a logging tool and/or a logging system, a maximum data rate or bit rate for transmission of data from a downhole tool, a maximum processing rate as to processing of data (e.g., downhole and/or uphole), etc.\n \nFIG. \n12\n shows an example of a method \n1200\n that includes various actions along with approximate graphical representations.', 'The method \n1200\n includes an exposure block \n1210\n for exposing nuclei to a static magnetic field, an exposure block \n1220\n for exposing the nuclei to an oscillating magnetic field, a sequence block \n1230\n for performing the exposing according to a pre-determined sequence that includes data acquisition, an analysis block \n1240\n for analyzing at least a portion of acquired data, an inversion block \n1250\n for inverting at least a portion of the acquired data and converting a decay curve into a distribution of T\n2 \nmeasurements and an analysis block \n1260\n for analyzing a distribution of T\n2 \nmeasurements with respect to porosity (e.g., pore sizes in the formation investigated), which can correspond to water environments (e.g., clay-bound water, capillary-bound water, free water, etc.).', 'Hydrogen nuclei behave like tiny bar magnets and tend to align with the magnetic field of permanent magnets, such as those in an NMR logging tool.', 'During a set wait time (WT), the nuclei polarize at an exponential buildup rate, T\n1\n, including multiple components (C).', 'Next, a train of RF pulses can adjust spins of the hydrogen nuclei causing them to tip 90 degrees and then precess about the permanent magnetic field where 180 degree pulses can re-focus the hydrogen nuclei at particular times.', 'The formation fluids can generate RF echoes responsive to successive 180 degree pulses where the RF echoes are received and measured by the antenna of the NMR logging tool.', 'The time between the 180 degree pulses can be defined as the echo spacing or echo time.', 'The amplitudes of the echoes decay at a superposition of exponential relaxation times, Ta, which tend to be functions of pore-size distribution, fluid properties, formation mineralogy and molecular diffusion.', 'As an example, an inversion technique can be applied that converts a decay curve into a distribution of T\n2 \nmeasurements (see, e.g., T\n2 \ndistribution of the GUI \n1100\n of \nFIG.', '11\n).', 'In general, for brine-filled rocks, the distribution is related to the pore sizes in the rocks.', 'NMR logging can face various challenges such as one or more of the three challenges described below.', 'First, it tends to be slow due to real world physics, specifically, the prolonged time to polarize hydrogen atoms in a static magnetic field; second, it tends to have poor SNR owing to the intrinsically weak coupling between nuclear spins and the instrument detectors; and third, an NMR logging program tends to demand substantial job planning, demanding local knowledge and domain resources and resulting in a lengthy operational workflow.', 'Methods that reduce logging time, enhance SNR, and streamline job design are generally desirable.', 'NMR is a routinely used technique for reservoir characterization due to its capability of measuring the hydrogen nuclei in the fluids.', 'As both water and hydrocarbons like oil and gas contain hydrogen nuclei, they can be measured and quantified by NMR tools.', 'Furthermore, NMR measurement of sample properties, such as relaxation times (T\n1 \nand T\n2\n) and diffusion coefficients enable understanding of the dynamics of these fluids, resulting in the interpretation of their physical state (e.g., free or bound), the sizes of the pores they are confined in, the viscosity and type of hydrocarbons, and the permeability, and other properties of the rock system.', 'NMR relaxation such as measured by T\n2 \nhas been shown to be directly proportional to the surface-to-volume ratio of a porous material, \n 1/\nT\n2\n=ρS/V\np\n\u2003\u2003(1) \n where S is the total surface area of the material, V\np \nis the pore volume, and p is the surface relaxivity.', 'Above, surface relaxivity p is a quantity (in units of micron/second) that defines the strength of the surface relaxation phenomenon.', 'Because of this relationship, NMR is used in petroleum exploration to obtain estimates of porosity, pore size, bound fluids, permeability, and other rock and fluid properties (e.g., “petrophysical data”).', 'For example, it is known that a T\n2 \ndistribution is closely related to the pore size distribution.', 'Reservoir rocks often exhibit a wide range of T\n2\ns due to the difference in pore sizes, with observed T\n2 \nfrom several seconds down to tens of microseconds.', 'Signals at long T\n2 \n(e.g., greater than 100 milliseconds) tend to be from large pores and such fluids may be considered producible.', 'For shorter T\n2 \nsignals (e.g., 3 milliseconds to 50 milliseconds), the fluids are often considered to be bound by capillary force of the pores.', 'For example, fluids in sandstone rocks with T\n2 \nbelow 30 ms are considered bound by capillary force and tend not to produce.', 'Thus, a cutoff value, T\n2 \ncut (e.g., T\n2 \ncut=30 ms) can be used to calculate the bound fluid volume: \n \nBFV=∫\nT\n2\nmin\nT\n2\ncut\nf\n(\nT\n2\n)\ndT\n2\n\u2003\u2003(2) \n where f(T\n2\n) is the T\n2 \ndistribution, and T\n2 \nmin is the minimum T\n2 \nobtained in the T\n2 \ndistribution.', 'For a fully saturated sample, porosity can be obtained by integrating f(T\n2\n) through the entire T\n2 \ndomain as: \n ∫\nT\n2\nmin\nT\n2\nmax\nf\n(\nT\n2\n)\ndT\n2\n\u2003\u2003(3) \n where T\n2\nmax is the maximum T\n2 \nexhibited in the sample.', 'Signals with even shorter T\n2 \n(e.g., T\n2 \nless than approximately 3 milliseconds) can be due to clay bound water or viscous (heavy) hydrocarbon.', 'Some rocks contain a substantial amount of kerogen that is solid organic matter and may exhibit T\n2\ns down to tens of microseconds.', 'As explained, NMR measurements can be acquired using specially designed data acquisition schemes (e.g., pulse sequences) which describe the timings of transmission and reception of electromagnetic signals.', 'A pulse sequence for the measurement of T\n2 \nrelaxation time distribution can be a CPMG echo train.', 'As an example, signals of an echo train can be acquired.', 'As an example, a signal amplitude, D, can be measured as a function of the echo time, t\necho\n, (the time of the echo from the beginning of the first 90-degree pulse), \n \nt\necho\n=n*TE\n\u2003\u2003(4) \n where n is the number of echo and TE is the echo spacing (e.g., the time between two adjacent 180-degree pulses).', 'The signal amplitude tends to follow an exponential decay form, \n \n \n \n \n \n \n \n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n \ne\n \n\u2062\n \nc\n \n\u2062\n \nh\n \n\u2062\n \no\n \n \n \n)\n \n \n=\n \n \n \nS\n \n\u2061\n \n(\n \n0\n \n)\n \n \n\u2062\n \n \nexp\n \n(\n \n \n \n-\n \nn\n \n \n*\n \n \n \nT\n \n\u2062\n \nE\n \n \n \nT\n \n2\n \n \n \n \n)\n \n \n \n \n \n \n \n(\n \n5\n \n)\n \n \n \n \n \n \n \n for a sample of a single T\n2\n.', 'For samples embodying a range of T\n2 \ndistribution, the total signal is a sum of T\n2 \ncomponents,\n \n \n \n \n \n \n \n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n \ne\n \n\u2062\n \nc\n \n\u2062\n \nh\n \n\u2062\n \no\n \n \n \n)', '=\n \n \n∫\n \n \nd\n \n\u2062\n \n \nT\n \n2\n \n \n\u2062\n \n \nf\n \n\u2061\n \n(\n \n \nT\n \n2\n \n \n)\n \n \n\u2062\n \n \nexp\n \n(\n \n \n \n-\n \nn\n \n \n*\n \n \n \nT\n \n\u2062\n \nE\n \n \n \nT\n \n2\n \n \n \n \n)\n \n \n \n \n \n \n \n \n(\n \n6\n \n)\n \n \n \n \n \n \n \n where f(T\n2\n) is the T\n2 \ndistribution.', 'In practice, fluid properties other than T\n2 \nare measured by a wide variety of pulse sequences.', 'For example, relaxation time T\n1 \nis measured through inversion or saturation recovery pulse sequences, and translational diffusion coefficient, D\nc\n, is measured by diffusion-editing or pulse-field gradient pulse sequences.', 'In an inversion-recovery T\n1 \nmeasurement, the echo signal may be determined by the following equation:\n \n \n \n \n \n \n \n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n\u2062\n \n1\n \n \n)', '=\n \n \n∫\n \n \n \ndT\n \n1\n \n \n\u2062\n \n \nf\n \n\u2061\n \n(\n \n \nT\n \n1\n \n \n)', '\u2062\n \n \n(\n \n \n1\n \n-\n \n \n2\n \n\u2062\n \n \nexp\n \n(\n \n \n-\n \n \n \nt\n \n\u2062\n \n1\n \n \n \nT\n \n1\n \n \n \n \n)\n \n \n \n \n)\n \n \n \n \n \n \n \n \n(\n \n7\n \n)\n \n \n \n \n \n \n \n where t1 is often called the “encoding time.”', 'In practice, a list of t1 values can be used to measure the signal, and the resulting signal D(t1) is subsequently inverted to obtain the sample T\n1 \ndistribution, f(T\n1\n).', 'An optimal choice of a {t1} list may be a function of sample T\n1 \ndistribution.', 'For example, with T\n1\n=1 ms, maximum t1 can be under 5 ms; while when T\n1\n=1 s, {t1} can cover as long as 5 s. As an example, a method can include determining in real-time a {t1} sequence that suits the acquisition parameter for specific material under study.', 'A combination of pulse sequences can simultaneously measure more than one NMR property of fluids.', 'For example, a combination of inversion recovery and CPMG sequences can provide a two-dimensional mapping of fluid T\n1\n-T\n2 \ndistribution—a technique that can be utilized in evaluating shale and tight formations.', 'High-dimensional measurements can be particularly time consuming as they demand traversing through a high-dimensional pulsing parameter table.', 'As an example, parameters {t1, t2} can be parameters of a pulse sequence where a signal can be determined by: \n \nD\n(\nt\n1,\nt\n2)=∫\ndT\n1\ndT\n2\nf\n(\nT\n2\n,T\n1\n)(1−\ne\n−t1/T\n1\n)\ne\n−t2/T\n2\n\u2003\u2003(8) \n where f(T\n2\n, T\n1\n) is the joint distribution of T\n1 \nand T\n2 \nrelaxation times of the material under investigation.', 'As an example, a few parameter sets (e.g., sets of different {t1 t2} values) may be prepared while engineering an NMR tool, individually optimized for different formation types (shale, heavy oil, light oil, etc.).', 'As to entering and exiting a formation layer during a logging operation, as an example, a method may be utilized that can include selecting one of the optimized pulse sequences for execution.', 'Such an adaptive approach can involve real-time modeling of acquired NMR signals.', 'As an example, an NMR measurement may be described by a series of time sequences of RF pulses, gradient pulses, data acquisition, and synchronized operations of peripheral circuitries, such as duplexers.', 'In such an example, each element of the time sequence can be further characterized by system parameters, such as duration, phase, amplitude and duty-cycle of RF and gradient pulses.', 'Consider parameters such as p1, p2, . . .', ', and a suite of parameters as P={p1, p2, . . .', '}.', 'As an example, an approach as to determining parameters P can be utilized for one or more other types of instruments, which may be various logging instruments with or without NMR capabilities.', 'For example, consider transmission power/current, receiver sensitivity, bandwidth, and frequency for various downhole tools (e.g., EM tools, etc.); and/or one or more of detector acquisition window, pulse neutron power, and pulse rate for nuclear downhole tools.', 'As an example, real-time optimization can provide for improvements to data quality and/or operational efficiency and/or, for example, preserving useful lifetime of an instrument or instruments with a common power supply, common telemetry circuitry, etc.', 'As an example, a heterogeneous computing infrastructure may help reduce hardware functionalities, optimize performance and lower overall cost for instrument designs.', 'In addition to NMR well-logging, one or more other types of multi-dimensional NMR spectroscopy experiments may utilize one or more methods to improve measurement robustness and/or to accelerate (e.g., simplify) planning.', 'As an example, NMR properties measured in a spectroscopy experiment may include chemical shift, spin-spin coupling, heteronuclear interactions, spin spatial dependence, etc.', 'As an example, a method can be an iterative procedure of quantifying forward model uncertainty at a workstation, porting the quantification results to a regression-tree, loading the tree to an edge device, feeding back acquired data and flag back to the workstation.', 'In such an example, elasticity attributes of a regression-tree can allow for accommodating various limits (e.g., consider edge device limits as to fast memory such as RAM) and/or limits as to incomplete knowledge about one or more samples under study.', 'As an example, an approach can utilize a system that is distributed, for example, a system that utilizes a combination of high-performance computing (HPC) and edge computing infrastructures for automating and optimizing logging operations, where data acquisitions are dynamically adjusted with an incremental knowledge of a reservoir.', 'An adaptive approach can be utilized with an aim to improve efficiency and quality of data acquisition and to automate job planning.', 'As an example, a digital decision model (DDM) can be implemented in an elastic manner where “elasticity” is based on its operation, for example, to update the DDM.', 'As an example, a DDM can be a tree type of model where states of the model are determined by decisions made.', 'For example, a decision may correspond to a leaf of a tree, which can be a terminal leaf at a particular level of resolution of one or more operational parameters (e.g., a parameter, a parameter set, etc.) that is or are utilized to dictate how a system performs an operation or operations.', 'As an example, a terminal state can be a state where a tree is at a terminal leaf, which may cause a system to perform in a less than possible optimal manner.', 'In such an example, the system can transmit a request, optionally along with data, to a remote system that can generate an updated digital decision model (DDM) for subsequent transmission to the system for use in decision making as to how one or more operations are performed.', 'Such an approach can result in elasticity as to operations and, for example, extensibility in that a decision may result in performance of a new or different type of operation.', 'As an example, a method can include elastic regression-tree learning in a heterogeneous computing environment.', 'As mentioned, a system may include one or more sensors where the system may be implanted, remote, embedded, etc.', 'In such a system, intelligence may demand performance of a sensor function with minimal operator interference.', 'As mentioned, even where computing resources may be in close proximity to a system, a hardware upgrade to that system may be limited (e.g., consider surgery to upgrade hardware in an implanted medical system).', 'As mentioned, a system may suffer from latency, for example, in long-range data transmission (e.g., consider downhole equipment, outer space equipment, etc.).', 'As an example, a workflow can provide for optimizing sensor performance of the same sample and/or for different samples.', 'For example, a same sample may be for a structural sensor system embedded in a bridge where changes may be expected to occur over time; whereas, for different samples, consider a downhole tool that is conveyed in a borehole to sense physical properties of different samples with respect to position (e.g., depth) in the borehole.', 'As an example, an elastic regression-tree method can provide for distributing computing tasks between an embedded chipset (e.g., a hardware limited system) and a computing workstation (e.g., a hardware upgradeable system, a cloud-based system, etc.).', 'A reconciliation of computing resources of different natures can allow for efficient data acquisition in an automated manner, for example, as may be involved in deployment of edge intelligence systems.', 'In the field of subsurface measurements of oilfield exploration reservoir conditions of extreme temperature and pressure (e.g., greater than 150 degrees C. and greater than 1,000 atmospheres) can pose challenges towards deploying artificial intelligence (AI) types of units.', 'As mentioned, a system may be constrained or otherwise limited such that there is a desired to more fully leverage an embedded environment of limited capacity for sensor optimization and automation.', 'As to an example of a heterogeneous system, consider the example specifications in Table 1 below.', 'TABLE 1\n \n \n \n \n \n \n \n \nExample embedded MCU vs. full-fledged workstation.', 'Attribute\n \nMicroprocessor\n \nWorkstation\n \n \n \n \n \n \n \nCPU clock-rate\n \n10 s-100 s MHz\n \nGHz\n \n \n \n \nRAM\n \n10 s KB-MB\n \n10 s GB\n \n \n \n \nLatency\n \n ε, may be utilized for tree construction, so the tree in its entirety may be deployed to a constrained system.', 'The use of elevated ε\nT \ncan lead to a low-resolution tree that resolves the sample properties q at a reduced level.', 'After running the tree on the constrained system to a decision leaf (e.g., a state of the digital decision model (DDM)), the acquired data can be utilized, at least in part, to construct an updated tree with a progressively reduced ε\nT\n.', 'To keep the tree size under a memory limit, the size of the property space may also be decreased.', 'Such a procedure can be repeated until ε\nT \napproaches ε.', 'After each iteration, the envelop of the sampling space may be reduced while the density increases, thereby acting as a “zoom-in” attribute.\n \nFIG.', '17\n shows an example of a diagram \n1700\n of a zoom-in attribute.', 'The diagram \n1700\n shows a first row Π\nq\n, with black dots as the original sampling points, other dots (e.g., circles) as the Solution Ensembles before (A) and after (B) a “zoom-in” operation; the second row show p-domain signals, with black traces from Π\nq\n, II white filled traces from the respective Solution Ensembles, a thick black filled trace from the sample ground truth, and black dots are the acquired data; and the third row shows the first regression tree in A, the second “zoom-in” tree in B, and the traversal pathway in white with a thick black outline.', 'Specifically, \nFIG.', '17\n shows an example of a zoom-in attribute for a 2D sampling space, bounded by (q\n1L\n0\n,q\n1U\n0\n) for {tilde over (q)}\n1 \nand (q\n2L\n0\n,q\n2U\n0\n) for {tilde over (q)}\n2\n.', 'The first tree, tree\n1\n, was generated by ε\nT,1 \nof tree size no larger than 80, the limit shown in \nFIG.', '16\n.', 'The first tree, tree\n1\n, was loaded to the MCU and executed to a leaf, with {p\ni\n, S\ni\n}(i=1, 2, . . . )', 'the acquisition parameters and corresponding data.', 'As an example, a zoom-in procedure can include: \n \n \n \n1.', 'Determining extremes of {tilde over (q)} of the leaf, which in this example are {q\n1L\n1\n,q\n1U\n1\n} for q\n1 \nand {q\n2L\n1\n,q\n2U\n1\n} for q\n2\n;\n \n2.', "Generating n\n0 \n{tilde over (q)}'s uniformly in each dimension, bounded by the extremes so that q\n1L\n1\n≤q\n1\n≤q\n1U\n1 \nand q\n1L\n1\n≤{tilde over (q)}\n2\n≤q\n2U\n1\n;\n \n3.", "Constructing a new property space Π\nq,2 \nof {tilde over (q)}'s that satisfy the inequality: (S\ni\n−f(p\ni\n,{tilde over (q)}))\n2\n≤ε\n2\n∀i.", '4. Generating a second, updated tree, tree\n2\n, with Π\nq,2 \nand ε\nT,2\n, where ε\nT,2\n≥ε and N\ntree,2\n≤80.', 'As shown, the second, updated tree, tree\n2\n, can be subsequently transmitted and loaded to memory of a constrained system.', 'As an example, such a procedure may be repeated until ε\nT \nreaches ε.', 'As an example, when the leaf is a non-convex set, the uniform sampling in point \n2\n above can provide for generating a large number of {tilde over (q)} that fails the test in point \n3\n above.', 'As an example, to increase the number of qualified {tilde over (q)}, a method can include applying a convex hull to the leaf and its siblings (see, e.g., \nFIG. \n24\n).\n \nFIG.', '18\n shows an example of a diagram \n1800\n of a zoom-out attribute.', 'In the example of \nFIG.', '18\n, the diagram shows the first row representing Π\nq\n, with black dots as the original sampling points, open circles as the Solution Ensemble after “zoom-out” in B, and the large open circle as the sample ground truth; the second row shows p—domain signals, with black traces from Π\nq\n, white filled traces from the Solution Ensemble, the thick black filled trace from the sample ground truth, and each black dot being the acquired data; and the third row shows the first regression tree in A, the second “zoom-out” tree in B, and the acquisition pathway in being a white filled pathway with a thick black border.', 'As mentioned, a request to update a digital decision model (DDM) can occur responsive to a state of the DDM.', 'For example, a state can be a failure of a tree to reach a leaf (e.g., to make a particular decision).', 'In response to such a state, a request may be issued to instruct a workstation to make an attempt or attempts to expand the property space Π\nq \nwith sparser sampling of {tilde over (q)} over a wider space until it includes the ground truth.', 'As shown in \nFIG.', '18\n, a method can expand the original FIG.', 'Π\nq \n2-fold along each of the dimensions at a time, until the constructed p-domain signals agree with acquired data points within the instrument noise margin.', 'The diagram \n1800\n of \nFIG.', '18\n illustrates the zoom-out attribute in a 2D sampling space.', 'As mentioned, various methods may be utilized in a logging environment using one or more downhole tools.', 'As an example, a multiclass regression tree and its elastic attributes can be utilized to instruct a downhole tool to perform NMR measurements.', 'An NMR measurement may be carried out by a time sequence of transmission and acquisition events.', 'The measurement results, S, may be interpreted by nonlinear regression models with inputs of the measurement parameters, p. Sample properties, q, such as diffusion coefficient, relaxation times, and chemical shift of molecules, may be obtained by various inversion methods.', 'As an example, a method can be implemented to dynamically optimize the NMR measurements, given computational constraints of NMR equipment (e.g., an NMR system).', 'In such an example, optimization can be guided by a regression tree constructed a priori, and newly acquired signals S.\n \nIn various examples, NMR measurements are simulated, for example, using a software stack, written in the C programming language for an embedded system and in MATLAB for a workstation.', 'The embedded system included a TMS320F28335 DELFINO MCU (Texas Instruments, Dallas, Texas) with 68 KB RAM and 150 MHz CPU speed as the embedded chipset while the workstation was a PC with 48 GB RAM and an INTEL XEON E5 CPU (3.6 GHz).', 'The two computing units were connected by a USB cable through a RS-485 serial communication.', 'In each experiment, simulated data, generated from a sample ground truth, were synthesized at the workstation and loaded to the MCU RAM.', 'The regression tree, also operated at the MCU RAM, queries the synthetic data at a sequence of measurement parameters, and returns the acquired points and an exit flag upon completing the iterative procedure.', 'In particular, a class of NMR experiments were simulated as find use in remote sensing applications, with the following regression model:\n \n \n \n \n \n \n \n \n \nS\n \n=\n \n \n \n \ne\n \n \n \n-\n \nρ\n \n \n/\n \n \nT\n \n2\n \n \n \n \n\u2062\n \n \ne\n \n \n \n-\n \nA\n \n \n\u2062\n \n \n \nρ\n \n3\n \n \n·\n \nD\n \n \n \n \n \n+\n \nε\n \n \n \n,\n \n \n \n \n \n(\n \n15\n \n)\n \n \n \n \n \n \n \n where p is the measurement parameter in a time interval.', 'T\n2\n (relaxation time) and D (molecular diffusion coefficient or Dc) are the two sample properties of interest.', 'A is a calibration constant, which was set to unity and that may be utilized where desired by setting it to a different value.', 'Both sample properties take a wide numerical range as in encountered samples.', 'For example, it was reported that T\n2 \nmay vary from 10\n−3 \nto a few seconds and D from 10\n−6 \nto 10\n−4 \ncm\n2\n/s.', 'The properties {T\n2\n,D} may be estimated by measuring S for each value of p in Π\np \nand subsequently applying inversion routines to the acquired data set {S(Π\np\n)}.', 'In contrast, an example method determined {T\n2\n,D} with a small number of acquisitions using values {p\ni\n} that are dynamically adjusted for each individual sample.', 'Table 2, below, provides a summary of results for the simulated NMR experiments.', 'No.\n \n{T\n2\n, D × 10\n5\n}\n0\n \nSNR\n \np\ni \n× 10\n2\n \n{T\n2\n, D × 10\n5\n}\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1\n \n{0.5, 1}\n \n40\n \n{6.38, 3.2, 7.43}\n \n{1.7 ± 1.3, 1.1 ± 0.2}\n \n \n \n2\n \n{0.3, 1}\n \n100\n \n{6.38, 3.2,\n \n{0.31 ± 0.05,\n \n \n \n \n \n \n7.59, 3.35}\n \n1.00 ± 0.08}\n \n \n \n3\n \n{0.04, 0.2}\n \n40\n \n{6.38, 2.89, 3.2}\n \n{0.040 ± 0.003,\n \n \n \n \n \n \n \n0.39 ± 0.27}\n \n \n \n \n \n \n \n \n \n \nFor the three experiments, labeled 1, 2 and 3, for different instrument noise characteristics and sample properties, Π\np \nwas a fixed 1D array of 100 linearly spaced time intervals from 2×10\n−4 \ns to 1.5×10\n−1 \ns, from which the simulated data, {S(p\ni\n)}, were generated.', 'The initial sampling space for the sample properties, Π\nq,1\n, was constructed from 100 logarithmically spaced relaxation times {tilde over (T)}\n2 \nfrom 0.1 s to 3 s and 100 logarithmically spaced diffusion coefficients {tilde over (D)} from 0.4×10\n−5 \nto 3×10\n−5 \ncm\n2\n/s.', 'In total, Π\nq,1 \nincluded 10\n4 \n{{tilde over (T)}\n2\n,{tilde over (D)}} pairs.', 'In the first experiment, the sample ground truth was set at {T\n2\n,D}\n0\n={0.5 s,1×10\n−5 \ncm\n2\n/s} and a normally distributed instrument noise of amplitude ε=0.025 and variance 1.', 'At the workstation, a 51-node regression tree was constructed with tree noise ε\nT\n=ε and the regression model of Equation 6.', 'Since the number of nodes was under the MCU limit, the tree was loaded into the MCU RAM.', 'FIGS.', '19\n, \n20\n and \n21\n show an example of running a regression tree in a simulated NMR experiment where the regression tree is an example of a digital decision model (DDM).', 'In \nFIG. \n19\n, a series of plots \n1900\n are shown; in \nFIG.', '20\n, a plot \n2000\n is shown; and in \nFIG.', '21\n, the regression tree \n2100\n is shown.', 'In \nFIG. \n19\n, the series of plots \n1900\n are for A, B and C, which are three iterations of realtime optimization on data acquisition.', 'In the first row, open regions about an open circle are the Solution Ensembles after the previous acquisition, and the open circle indicates the sample ground truth.', "In the second row, the black traces show constructed {tilde over (S)}'s from their respective Solution Ensembles, and black dots are the acquired data.", 'In \nFIG. \n20\n, the plot \n2000\n, labeled “D” shows the maximum variance of the Solution Ensembles over three acquisitions, with the dashed line being the instrument noise floor (e.g., for an acquisition system such as the system \n1351\n of \nFIG.', '13\n).', 'In \nFIG. \n21\n, the regression tree \n2100\n, labeled “E” shows the regression tree \n2100\n as a 51-node tree, which is used in the experiment, where, for example, each bar can be coded, for example, with bounds, etc.', 'For example, a bar can be positioned underneath each node that represents the mean of two bounds of its interval attribute and, for example, the number can be the parameter index in II at which the acquisition is taken.', 'As shown in the series of plots \n1900\n, for A, B and C, the optimization routine traversed through the regression tree \n2100\n to a leaf, corresponding to a Solution Ensemble that contained the ground truth {T\n2\n,D}\n0\n.', 'As the tree was made with the instrument ε, reaching the leaf indicated that χ\nmax\n2 \nof the synthetic p—domain data fell below ε\n2\n, as shown in the plot \n2000\n of \nFIG.', '20\n (see “D”).', 'Also shown in \nFIG.', '21\n is the acquisition pathway through the regression tree \n2100\n (see “E”), with measurements taken at {Π\np\n43\n=0.0638, H\np\n22\n=0.032, Π\np\n55\n=0.0743}.', 'In the second experiment, the sample ground truth was {T\n2\n,D}\n0\n={0.3 s,1×10\n−5 \ncm\n2\n/s} and a normally distributed noise of amplitude ε=0.01.', 'The regression tree, built with instrument noise ε, resulted in N\ntree\n=239 that was too large to load to the particular MCU (e.g., the memory limit of the acquisition system was insufficient to load the digital decision model (DDM)).', 'In such a situation, a smaller tree can be constructed (e.g., a smaller sized DDM), for example, with ε\nT,1\n=0.025 was constructed with N\ntree\n=80.', 'This tree\n1 \non the MCU made 3 queries before reaching a decision leaf, returning the acquired data with an exit flag (e.g., as to a terminal state or leaf state) that requested a zoom-in operation at the workstation.\n \nFIG.', '22\n shows an example of a series of plots \n2000\n for an example of a zoom-in process in a simulated NMR experiment.', 'In \nFIGS.', '22\n, A, B and C represent the iterations of real-time optimization on data acquisition.', 'In the first row, the outlined regions represent the Solution Ensembles before (A), after three (B), and four (C) acquisitions, and the open circle is the sample ground truth.', "In the second row, black traces are constructed {tilde over (S)}'s from their respective Solution Ensembles, and black dots represent acquired data.", 'In \nFIG.', '22\n, the plot labeled D shows the maximum variance of Solution Ensembles over 4 acquisitions, with the dashed line being the instrument noise floor.', 'Subsequently, a second tree was constructed at the workstation, constrained by {p\ni\n,S(p\ni\n)} with ε\nT\n=ε.', 'The tree\n2 \nof 1 node was loaded to the MCU, making one query as shown in the diagram of \nFIG.', '22\n (see “C”).', 'In the third experiment, instrument noise amplitude was set at 0.025 and the sample ground truth was set at {T\n2\n,D}\n0\n={0.04 s,0.2×10\n−5 \ncm\n2\n/s}.', 'As {T\n2\n,D}\n0 \nlay outside the property space Π\nq,1\n, tree\n1 \nwith ε\nT,1\n=0.025 failed to reach a leaf.', 'It made two queries and returned the acquired data and an exit flag instructing a zoom-out operation.\n \nFIG.', '23\n shows an example of a series of plots \n2300\n of an example of a zoom-out process in a simulated NMR experiment.', 'As shown in \nFIGS.', '23\n, A, B and C are the three iterations of realtime optimization on data acquisition.', 'In the first row, the outlined regions are the Solution Ensembles after the previous acquisition, and the open circle is the sample ground truth.', "In the second row, black traces are constructed S's from their respective Solution Ensembles, and black dots represent the acquired data.", 'In \nFIG. \n23\n, the plot labeled D shows the maximum variance of SE over three acquisitions, with the dashed line being the instrument noise floor.', 'Subsequently, a sparser yet wider sampling space, Π\nq,2\n, was constructed with 100 logarithmically spaced {tilde over (T)}\n2 \nfrom 0.025 s to 12 s and 100 logarithmically spaced {tilde over (D)} from 0.1×10\n−5 \nto 1.2×10\n−4 \ncm\n2\n/s.', 'The new sampling space was further tested to ensure that both {p\n1\n, S\n1\n} and {p\n2\n, S\n2\n} were consistent within its envelope.', 'Keeping ε\nT,2 \nunchanged at 0.025, the tree\n2 \nof 1 node was executed, yielding one more acquisition point.', 'With two regression trees and three queries, the optimization workflow found the true sample property, permitted by the instrument noise limit as shown in the plot labeled D in \nFIG. \n23\n.', 'In the three examples, the workflow started from acquiring at the root node, and managed to dynamically optimize data acquisitions with different sample properties and instrument noise.', 'In each experiment, the variance of the last Solution Ensemble reflects sensitivities of each physical property to both the nonlinear model and the instrument noise, as shown in the fifth column of Table 2.', 'Remote sensing systems tend to perform sensing operations according to prescribed protocols and at times demand professional interventions.', 'As an example, a method such as the method \n700\n of \nFIG.', '7\n can provide elasticity in that, in a constrained system, updates can occur dynamically to a digital decision model (DDM) for making decisions as to how one or more sensing operations are performed.', 'As an example, a system may be configured as the system \n1350\n of \nFIG.', '13\n where flags may be utilized to request dynamic updates to one or more digital decision models (DDMs) that can be loaded in memory.', 'As shown as an example, an algorithm can be utilized for NMR measurements where, for example, singular points in Π\nq \ncan be sample ground truths.', 'As an example, advanced measurements on complex samples may include both mathematically sophisticated models and continuous distributions of multiple physical quantities.', 'As explained, a method can include quantifying model uncertainty where making of observations and/or decisions falls within an envelope of a Bayesian network.', 'As an example, a method may be applied to one or more sensors of a parametric model.', 'As an example, a method may be applied to optimize performance of one or more sensor arrays of nonparametric and/or hybrid models.', 'As an example, one or more workflows may be automated, coordinated and quantifiable for measurements in a heterogeneous computing environment.\n \nFIG.', '24\n shows examples of pseudocode algorithms \n2410\n and \n2430\n for examples of methods for a zoom-in attribute for 2D sampling space with non-convex sets.', 'As an example, a convex hull of a set of points in 2D space can be a polygon with a minimal area that includes the whole set.', 'As an example, an algorithm can apply qHull to generate a convex hull of a set of vectors and inHull to decide if a given vector is in or out of a convex hull.', "For inHull, as an example, consider a MATLAB script developed by J. D'Errico (10226-inhull).", 'As an example, a zoom-in procedure can aim to increase the density of sampling points, as qualified, of a reached decision leaf.', "In such an example, an approach can propose likely qualified {tilde over (q)}'s in an efficient manner.", "Denoting L the set of {tilde over (q)}'s of the leaf, a strategy is to increase sampling points within the envelop of L that contains the sample ground truth.", 'Determining the envelop of L can be nontrivial when it is a non-convex set.', 'In \nFIG.', '24\n, the example algorithm \n2410\n is shown as being executable to determine the envelope of L (represented as acceptedQSet).', 'In the algorithm, it is denoted S\ni\n(i=1, 2, . . . )', "as the {tilde over (q)} sets for the leaf's siblings and generate n\n0 \n{tilde over (q)}'s, qCandidate, from L.", 'The algorithm \n2410\n then calculates the convex hull of L, acceptedCH, and subsequently accepts a subset of qCandidate that is within acceptedCH.', 'To further reduce non-qualified sampling points in qCandidate, an approach can include calculating the convex hull of each S\ni \nand excluding sampling points in the remaining qCandidate that fall within rejectedCH\ni\n, but not within L.', 'In such an approach a final qCandidate can be used.', 'As an example, one or more issues may arise when deriving the convex hulls.', "For example, the number of {tilde over (q)}'s in L can be small, and sometimes fall onto one line, such as when L has 1 or 2 {tilde over (q)}'s.", 'In those cases, the convex hull can be ill-defined.', 'In other cases, due to the discrete nature of sampling points the convex hull of L may include several non-overlapping polygons.', 'If the ground truth lies in one of the in-between gaps, it can be missed in the initial qCandidate.', 'As an example, a method can include expanding L so that a properly defined, continuous convex hull can be derived.', 'The example algorithm \n2430\n in \nFIG.', '24\n shows such an approach with nDim=2.', 'Once expanded, the new L can be subsequently used as an input for convex hull sampling.', 'As an example, a method can include performing an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; and, responsive to the request, receiving an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'In such an example, the method can be performed while the system is moving (e.g., consider a downhole tool being conveyed in a borehole).', 'As an example, a digital decision model can be or include a regression tree model.', 'As an example, a digital decision model may be defined by attributes such that transmission, reception, etc., of the attributes effectively transmits, receives the digital decision model.', 'As an example, a digital decision model can depend on one or more specifications of one or more sensors of a system.', 'As an example, an operation can be a sensing operation and, for example, a digital decision model can depend on signal to noise of the sensing operation.', 'As an example, a method can include a system that is moving in an environment, where the system performs a sensing operation that acquires sensor measurements of samples in the environment while the system is moving.', 'In such an example, the system may navigate a digital decision model (DDM) while the system is moving.', 'In such an example, where the environment changes, the DDM may be navigated to result in use of operational parameters that improve performance of the system (e.g., to tailor the system to changes in the environment).', 'As an example, a digital decision model can depend on a signal to noise ratio of a sensing operation of a system where the signal to noise ratio changes responsive to physical changes in an environment that occur responsive to the system moving in the environment.', 'In such an example, an improvement in signal to noise ratio for a particular environment may be an improvement to performance of the system.', 'As an example, a system can be a downhole system for deployment in a borehole in a geologic environment and an operation can be a nuclear magnetic resonance measurement operation that measures nuclear magnetic resonance signals of an in situ sample in the geologic environment.', 'For example, a method can include performing an NMR measurement operation using a downhole system (e.g., a NMR tool, etc.) where the operation depends on a decision made via a digital decision model stored in memory of the downhole system; responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model (e.g., to a surface system at least in part via downhole to surface telemetry); and, responsive to the request, receiving an updated digital decision model by the downhole system, where the updated digital decision model includes at least one new decision state that improves performance of the NMR measurement operation of the downhole system.', 'As an example, a decision state can be a terminal state of a digital decision model.', 'For example, consider a tree with leafs where each leaf can be a terminal state.', 'As an example, a DDM can include nodes where one or more nodes can be a terminal state node.', 'As an example, decision states can include one or more non-terminal states of a digital decision model.', 'As an example, a non-terminal state may be a state that exists after a number of iterations where, for example, a terminal state is not reached.', 'As an example, a method can include selecting, based on a decision state of a digital decision model stored in memory, a flag from a plurality of different flags stored in the memory, where a request for an updated digital decision model corresponds to the selected flag, where the decision state is a terminal state of the digital decision model, and where at least one new decision state of the updated digital decision model is a decision state that extends from the terminal state.', 'As an example, such a method may be referred to as a zoom-in model, which may refine one or more parameters for operation of a system.', 'As shown in \nFIG.', '17\n, an updated digital decision model can include one or more additional states (e.g., leaves, etc.) that extend from a terminal state (e.g., a terminal leaf) of the digital decision model that gave rise to a request for the updated digital decision model.', 'As an example, a system can include at least one of a plurality of different flags stored in memory that is selectable for a non-terminal state of a digital decision model.', 'For example, consider a flag that is for a zoom-out operation where an example is shown in \nFIG.', '18\n where a level with leaves is extended to include an additional leaf that is at the same level as the leaves.', 'Such an approach may be utilized where iterative use of the digital decision model does not cause the digital decision model to arrive at a terminal state (e.g., a terminal leaf, etc.).', 'While two types of decision states and corresponding flags are mentioned, a system can include one or more other decision states and one or more other corresponding flags.', 'As mentioned, an elastic approach may be utilized for parameters such as power parameters, signal to noise parameters, etc.', 'In such examples, various decision states can exist with corresponding flags that can call for (e.g., request) an update or updates to one or more digital decision models.', 'As an example, a method can include performing an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; and, responsive to the request, receiving an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'As an example, in such a method, responsive to use of the updated digital decision model, it may be determined (e.g., locally and/or remotely) that the updated digital decision model is sufficient in that it provides for desirable operation.', 'In such an example, the determination may cause one or more actions of the system to be suspended, which may preserve power, free memory, etc.', 'In such an example, the updated digital decision model may be in a decision state that may be a terminal state, for example, with corresponding operational parameters, where the system continues to operate according to those operational parameters.', 'In such an approach, one or more conditions, which may be or include one or more conditions other than a decision state condition, may trigger an assessment that may result in a call for another updated digital decision model.', 'For example, consider a downhole tool that is conveyed along a length of a borehole where a change in temperature may trigger such an assessment, reaching a particular depth (e.g., vertical or measured) may trigger such an assessment, etc.', 'As an example, an operation can be a sensing operation and a decision state can depend on a measurement value acquired by the sensing operation.', 'As an example, the measurement value may be characterized by a signal to noise ratio where the decision state may depend at least in part on the signal to noise ratio.', 'As an example, a signal to noise ratio may depend on one or more factors, which can include signal acquisition programmable factors, environmental factors and/or equipment factors (e.g., instrument factors).', 'As an example, a method can include performing an operation utilizing at least one new decision state of an updated DDM.', 'For example, a DDM may be limited in its number of decision states in that the decision states do not provide for optimal operation of equipment.', 'In such an example, a new DDM can include one or more new decision states that allow for more optimal operation of the equipment.', 'As mentioned, as an example, a database may be accessible via a constrained system where the database includes a plurality of DDMs where one of the DDM may be selected and transmitted to the constrained system where once received the DDM may be implemented to make decisions as to how the constrained system is operated.', 'As an example, a system can be a downhole system that performs operations that include a downhole sensing operation and where the downhole system can transmit a request to a surface system.', 'In such an example, the downhole system and the surface system can be a heterogeneous system.', 'As an example, the surface system can transmit an updated digital decision model and the downhole system can receive the transmitted updated digital decision model as transmitted by the surface system.', 'In such an example, the downhole system can receive via utilizing a downhole telemetry technique, which may be wired, wireless, etc.', 'As an example, a downhole telemetry technique can include a mud-pulse telemetry technique where pulses are made that travel through mud as a drilling fluid (e.g., drilling mud).', 'As an example, a method can include restricting an updated digital decision model to a size that depends on memory of a constrained system.', 'In such an example, a method can include restricting that includes adjusting the size of an updated digital decision model based on, for example, a signal to noise ratio of signals acquired by performing signal acquisition operations by the constrained system.', 'As an example, a decision state of a digital decision model can result in a request for a zoom-in process that adds at least one node/leaf to a terminal node/leaf of the digital decision model.', 'As an example, a decision state of a digital decision model can result in a request for a zoom-out process that adds at least one branch to a layer of the digital decision model.', 'As an example, a system can be an implantable medical system and an operation thereof can be or include a therapeutic operation.', 'As an example, a system can be a remote sensing system and an operation thereof can be or include a sensing operation.', 'As an example, a system can be an embedded system that is embedded in a structural body and an operation thereof can include a sensing operation that senses at least one physical property of the structural body (e.g., stress, strain, chemical environment, vibration, moisture, etc.).', 'As an example, a system can include a downhole tool and an uphole system with more computing facility than the downhole tool, where a digital decision model (DDM) is stored in memory of the downhole tool, and the execution of the DDM is performed in the downhole tool, and where updating of the digital decision model is performed at the uphole system.', 'For example, the downhole tool can transmit one or more of data, flags, etc., to the uphole system and, in response, the uphole system can generate and transmit an updated digital decision model (DDM) to the downhole system.', 'Such a method may occur iteratively, for example, as the downhole tool moves and experiences one or more changes in conditions, which may be, for example, changes that the downhole tool aims to characterize via measurements (e.g., sensor measurements).', 'As an example, an environment can be stratified where, geologically, it may be characterized via stratigraphy.', 'As an example, a downhole tool can be conveyed in a borehole to make sensor measurements that can help in characterization of the environment, which may include measurements that can improve characterization via stratigraphy (e.g., lithostratigraphy (lithologic stratigraphy) and/or biostratigraphy (biologic stratigraphy)).', 'As an example, a system can be an embedded system tool.', 'For example, the tool can be transportable and optionally powered by its own internal power supply and/or a transportable power generator (e.g., turbine, solar, etc.).', 'As an example, an embedded system tool can include telemetry circuitry that can communicate with another system such as a high-performance computing system (HPC system), which may be, for example, a workstation type of computing system.', 'In such an example, a digital decision model can be stored in memory of the embedded system tool where execution of the decision model is performed in the embedded system tool where updating of the digital decision model is performed by the HPC system, which can, via telemetry, transmit the updated digital decision model to the embedded system tool.', 'In such an example, the embedded system tool can be a downhole tool that has less memory than the HPC system, which can be a surface system (e.g., an uphole system).', 'As an example, a system can include a downhole tool and an uphole system with more computing facility that the downhole system where a digital decision model (DDM) is transmitted from the uphole system to the downhole tool, which may occur periodically, for example, with one or more updated DDMs to improve performance of the downhole tool.', 'As an example, a system can include a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: perform an operation using the system where the operation depends on a decision made via a digital decision model stored in the memory of the system; responsive to a decision state of the digital decision model, transmit a request to update the digital decision model; and, responsive to the request, receive an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'As an example, one or more computer-readable storage media can include processor-executable instructions executable to instruct a processor to: call for performance of an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; responsive to a decision state of the digital decision model, call for transmission of a request to update the digital decision model; and, responsive to the request, call for storage in the memory of a received updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'In some embodiments, a method or methods may be executed by a computing system.', 'FIG.', '25\n shows an example of a system \n2500\n that can include one or more computing systems \n2501\n-\n1\n, \n2501\n-\n2\n, \n2501\n-\n3\n and \n2501\n-\n4\n, which may be operatively coupled via one or more networks \n2509\n, which may include wired and/or wireless networks.', 'As an example, a system can include an individual computer system or an arrangement of distributed computer systems.', 'In the example of \nFIG. \n25\n, the computer system \n2501\n-\n1\n can include one or more sets of instructions \n2502\n, which may be or include processor-executable instructions, for example, executable to perform various tasks (e.g., receiving information, requesting information, processing information, simulation, outputting information, etc.).', 'As an example, a set of instructions may be executed independently, or in coordination with, one or more processors \n2504\n, which is (or are) operatively coupled to one or more storage media \n2506\n (e.g., via wire, wirelessly, etc.).', 'As an example, one or more of the one or more processors \n2504\n can be operatively coupled to at least one of one or more network interface \n2507\n.', 'In such an example, the computer system \n2501\n-\n1\n can transmit and/or receive information, for example, via the one or more networks \n2509\n (e.g., consider one or more of the Internet, a private network, a cellular network, a satellite network, etc.).', 'As an example, the computer system \n2501\n-\n1\n may receive from and/or transmit information to one or more other devices, which may be or include, for example, one or more of the computer systems \n2501\n-\n2\n, etc.', 'A device may be located in a physical location that differs from that of the computer system \n2501\n-\n1\n.', 'As an example, a location may be, for example, a processing facility location, a data center location (e.g., server farm, etc.), a rig location, a wellsite location, a downhole location, etc.', 'As an example, a processor may be or include a microprocessor, microcontroller, processor component or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'As an example, the storage media \n2506\n may be implemented as one or more computer-readable or machine-readable storage media.', 'As an example, storage may be distributed within and/or across multiple internal and/or external enclosures of a computing system and/or additional computing systems.', 'As an example, a storage medium or storage media may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLUERAY disks, or other types of optical storage, or other types of storage devices.', 'As an example, a storage medium or media may be located in a machine running machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'As an example, various components of a system such as, for example, a computer system, may be implemented in hardware, software, or a combination of both hardware and software (e.g., including firmware), including one or more signal processing and/or application specific integrated circuits.', 'As an example, a system may include a processing apparatus that may be or include a general purpose processors or application specific chips (e.g., or chipsets), such as ASICs, FPGAs, PLDs, or other appropriate devices.\n \nFIG.', '26\n shows components of a computing system \n2600\n and a networked system \n2610\n.', 'The system \n2600\n includes one or more processors \n2602\n, memory and/or storage components \n2604\n, one or more input and/or output devices \n2606\n and a bus \n2608\n.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components \n2604\n).', 'Such instructions may be read by one or more processors (e.g., the processor(s) \n2602\n) via a communication bus (e.g., the bus \n2608\n), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device \n2606\n).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.', 'According to an embodiment, components may be distributed, such as in the network system \n2610\n.', 'The network system \n2610\n includes components \n2622\n-\n1\n, \n2622\n-\n2\n, \n2622\n-\n3\n, . . .', '2622\n-N.', 'For example, the components \n2622\n-\n1\n may include the processor(s) \n2602\n while the component(s) \n2622\n-\n3\n may include memory accessible by the processor(s) \n2602\n.', 'Further, the component(s) \n2622\n-\n2\n may include an I/O device for display and optionally interaction with a method.', 'The network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.', 'As an example, a device may be a mobile device that includes one or more network interfaces for communication of information.', 'For example, a mobile device may include a wireless network interface (e.g., operable via IEEE 802.11, ETSI GSM, BLUETOOTH, satellite, etc.).', 'As an example, a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM slot, audio/video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery.', 'As an example, a mobile device may be configured as a cell phone, a tablet, etc.', 'As an example, a method may be implemented (e.g., wholly or in part) using a mobile device.', 'As an example, a system may include one or more mobile devices.', 'As an example, a system may be a distributed environment, for example, a so-called “cloud” environment where various devices, components, etc. interact for purposes of data storage, communications, computing, etc.', 'As an example, a device or a system may include one or more components for communication of information via one or more of the Internet (e.g., where communication occurs via one or more Internet protocols), a cellular network, a satellite network, etc.', 'As an example, a method may be implemented in a distributed environment (e.g., wholly or in part as a cloud-based service).', 'As an example, information may be input from a display (e.g., consider a touchscreen), output to a display or both.', 'As an example, information may be output to a projector, a laser device, a printer, etc. such that the information may be viewed.', 'As an example, information may be output stereographically or holographically.', 'As to a printer, consider a 2D or a 3D printer.', 'As an example, a 3D printer may include one or more substances that can be output to construct a 3D object.', 'For example, data may be provided to a 3D printer to construct a 3D representation of a subterranean formation.', 'As an example, layers may be constructed in 3D (e.g., horizons, etc.), geobodies constructed in 3D, etc.', 'As an example, holes, fractures, etc., may be constructed in 3D (e.g., as positive structures, as negative structures, etc.).', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words “means for” together with an associated function.']

['1.', 'A method comprising:\nsensing, via one or more sensors coupled to a downhole tool disposed in a well, one or more parameters associated with at least one of: the downhole tool or the well;\nreceiving data from the one or more sensors;\nproviding the data to a digital decision model stored in memory of a system;\nreceiving, from the digital decision model, a decision indicative of a selected decision state of a plurality of available decision states, wherein the decision is determined by the digital decision model based on the data;\ncontrolling one or more operations of the downhole tool based on the decision;\ndetermining that operation of the digital decision model would be improved by adding an additional decision state to the plurality of available decision states;\ntransmitting, to a digital decision model generator, a request to update the digital decision model to add the additional decision state to the plurality of available decision states;\nresponsive to the request, receiving, from the digital decision model generator, an updated digital decision model, wherein the updated digital decision model comprises the plurality of available decision states and the additional decision state;\nstoring the updated digital decision model in the memory of the system;\nreceiving, from the updated digital decision model, another decision; and\ncontrolling the one or more operations of the downhole tool based on the decision from the updated digital decision model.', '2.', 'The method of claim 1, wherein the digital decision model comprises a regression tree model.', '3.', 'The method of claim 1, wherein the system is moving in an environment, wherein the data received from the one or more sensors comprises one or more measurements of samples in the environment while the system is moving, wherein the digital decision model depends on a signal to noise ratio of the sensing, and wherein the signal to noise ratio changes responsive to physical changes in the environment that occur responsive to the system moving in the environment.', '4.', 'The method of claim 1, further comprising:\nselecting, based on the selected decision state, a flag from a plurality of different flags stored in the memory, wherein the request to update the digital decision model corresponds to the selected flag, wherein the selected decision state comprises a terminal state of the digital decision model, and wherein the additional decision state of the updated digital decision model extends from the terminal state, and wherein at least one of the plurality of different flags stored in the memory is selectable for a non-terminal state of the digital decision model.', '5.', 'The method of claim 1, wherein the selected decision state depends on a measurement value of the data received from the one or more sensors.', '6.', 'The method of claim 1, wherein the transmitting comprises transmitting the request to a surface system, and wherein the receiving comprises receiving the updated digital decision model from the surface system utilizing a downhole telemetry technique.', '7.', 'The method of claim 1, wherein the system comprises a downhole system for deployment in a borehole in a geologic environment, and wherein the sensing comprises a nuclear magnetic resonance measurement operation that measures nuclear magnetic resonance signals of an in situ sample in the geologic environment.\n\n\n\n\n\n\n8.', 'The method of claim 1, further comprising restricting the updated digital decision model to a size that depends on the memory of the system, and wherein the restricting comprises adjusting the size of the updated digital decision model based on a signal to noise ratio of signals in the data received from the one or more sensors.', '9.', 'The method of claim 1, wherein the system comprises the downhole tool and surface equipment, and wherein the surface equipment is configured to, responsive to the request transmitted by the downhole tool being received by the surface equipment:\ngenerate the updated digital decision model; and\ntransmit the updated digital decision model from the surface equipment to the downhole tool.', '10.', 'The method of claim 1, wherein the selected decision state of the digital decision model requests a zoom-in process that adds at least one terminal structure to the digital decision model.', '11.', 'The method of claim 1, wherein the selected decision state of the digital decision model requests a zoom-out process that adds at least one branch to a layer of the digital decision model.\n\n\n\n\n\n\n12.', 'A system comprising:\na processor;\nmemory accessible to the processor;\nprocessor-executable instructions stored in the memory and executable by the processor to instruct the system to: sense, via one or more sensors coupled to a downhole tool disposed in a well, one or more parameters associated with at least one of: the downhole tool or the well; receive data from the one or more sensors; provide the data to a digital decision model stored in the memory of a system; receive, from the digital decision model, a decision indicative of a selected decision state of a plurality of available decision states, wherein the decision is determined by the digital decision model based on the data; control one or more operations of the downhole tool based on the decision; determine that operation of the digital decision model would be improved by adding an additional decision state to the plurality of available decision states; transmit, to a digital decision model generator, a request to update the digital decision model to add the additional decision state to the plurality of available decision states; responsive to the request, receive, from the digital decision model generator, an updated digital decision model, wherein the updated digital decision model comprises the plurality of available decision states and the additional decision state; store the updated digital decision model in the memory of the system; receive, from the updated digital decision model, another decision; and control the one or more operations of the downhole tool based on the decision from the updated digital decision model.', '13.', 'One or more non-transitory computer-readable storage media comprising processor-executable instructions executable to instruct a processor to:\nsense, via one or more sensors coupled to a downhole tool disposed in a well, one or more parameters associated with at least one of: the downhole tool or the well;\nreceive data from the one or more sensors;\nprovide the data to a digital decision model stored in a memory of a system;\nreceive, from the digital decision model, a decision indicative of a selected decision state of a plurality of available decision states, wherein the decision is determined by the digital decision model based on the data;\ncontrol one or more operations of the downhole tool based on the decision;\ndetermine that operation of the digital decision model would be improved by adding an additional decision state to the plurality of available decision states;\ntransmit, to a digital decision model generator, a request to update the digital decision model to add the additional decision state to the plurality of available decision states;\nresponsive to the request, receive, from the digital decision model generator, an updated digital decision model, wherein the updated digital decision model comprises the plurality of available decision states and the additional decision state;\nstore the updated digital decision model in the memory of the system;\nreceive, from the updated digital decision model, another decision; and\ncontrol the one or more operations of the downhole tool based on the decision from the updated digital decision model.', '14.', 'The one or more non-transitory computer-readable storage media of claim 13, wherein the digital decision model comprises a regression tree model.', '15.', 'The one or more non-transitory computer-readable storage media of claim 13, wherein the system is moving in an environment, wherein the data received from the one or more sensors comprises one or more measurements of samples in the environment while the system is moving, wherein the digital decision model depends on a signal to noise ratio of the sensing, and wherein the signal to noise ratio changes responsive to physical changes in the environment that occur responsive to the system moving in the environment.', '16.', 'The one or more non-transitory computer-readable storage media of claim 13, wherein the processor-executable instructions are executable to instruct the processor to select, based on the selected decision state, a flag from a plurality of different flags stored in the memory, wherein the request to update the digital decision model corresponds to the selected flag, wherein the selected decision state comprises a terminal state of the digital decision model, wherein the additional decision state of the updated digital decision model extends from the terminal state, and wherein at least one of the plurality of different flags stored in the memory is selectable for a non-terminal state of the digital decision model.', '17.', 'The one or more non-transitory computer-readable storage media of claim 13, wherein the selected decision state depends on a measurement value of the data received from the one or more sensors.', '18.', 'The one or more non-transitory computer-readable storage media of claim 13, wherein the system comprises a downhole system for deployment in a borehole in a geologic environment, and wherein the sensing comprises a nuclear magnetic resonance measurement operation that measures nuclear magnetic resonance signals of an in situ sample in the geologic environment.']

['FIG. 1 illustrates examples of equipment in a geologic environment;; FIG.', '2 illustrates an example of a system and examples of types of holes;; FIG.', '3 illustrates an example of a system;; FIG.', '4 illustrates an example of a system;; FIG.', '5 illustrates an example of a system;; FIG.', '6', 'illustrates examples of systems;; FIG.', '7 illustrates an example of a method and an example of a system;; FIG. 8 illustrates an example of a method and an example of a tool;; FIG.', '9 illustrates an example of a system;; FIG.', '10 illustrates an example of a microprocessor and an example of circuitry;; FIG.', '11 illustrates an example of a graphical user interface;; FIG.', '12 illustrates an example of a method;; FIG. 13 illustrates examples of systems;; FIG.', '14 illustrates examples of plots;; FIG.', '15 illustrates an example of a diagram of an example of a method;; FIG.', '16 illustrates an example of a plot;; FIG.', '17 illustrates example plots and an example of a diagram of an example of a method;; FIG.', '18 illustrates example plots and an example of a diagram of an example of a method;; FIG.', '19 illustrates example plots of an example of a method;; FIG.', '20 illustrates an example plot of an example of a method;; FIG.', '21 illustrates an example diagram of an example of a method;; FIG.', '22 illustrates example plots of an example of a method;; FIG.', '23 illustrates example plots of an example of a method;; FIG.', '24 illustrates an examples of pseudocode for examples of methods;; FIG.', '25 illustrates examples of computing and networking equipment; and; FIG.', '26 illustrates example components of a system and a networked system.; FIG.', '1 shows an example of a geologic environment 120.', 'In FIG.', '1, the geologic environment 120 may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir 121 and that may be, for example, intersected by a fault 123 (e.g., or faults).', 'As an example, the geologic environment 120 may be outfitted with a variety of sensors, detectors, actuators, etc.', 'For example, equipment 122 may include communication circuitry to receive and/or to transmit information with respect to one or more networks 125.', 'Such information may include information associated with downhole equipment 124, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment 126 may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more pieces of equipment may provide for measurement, collection, communication, storage, analysis, etc. of data (e.g., for one or more produced resources, etc.).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, geolocation, etc.', 'For example, FIG. 1 shows a satellite in communication with the network 125 that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', '; FIG. 1 also shows the geologic environment 120 as optionally including equipment 127 and 128 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 129.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 127 and/or 128 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, NMR logging, assessment of one or more fractures, injection, production, etc.', 'As an example, the equipment 127 and/or 128 may provide for measurement, collection, communication, storage, analysis, etc. of data such as, for example, formation data, fluid data, production data (e.g., for one or more produced resources), etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.; FIG. 1 also shows an example of equipment 170 and an example of equipment 180.', 'Such equipment, which may be systems of components, may be suitable for use in the geologic environment 120.', 'While the equipment 170 and 180 are illustrated as land-based, various components may be suitable for use in an offshore system.', 'As shown in FIG.', '1, the equipment 180 can be mobile as carried by a vehicle; noting that the equipment 170 can be assembled, disassembled, transported and re-assembled, etc.; FIG.', '2 shows an example of a wellsite system 200 (e.g., at a wellsite that may be onshore or offshore).', 'As shown, the wellsite system 200 can include a mud tank 201 for holding mud and other material (e.g., where mud can be a drilling fluid that may help to transport cuttings, etc.), a suction line 203 that serves as an inlet to a mud pump 204 for pumping mud from the mud tank 201 such that mud flows to a vibrating hose 206, a drawworks 207 for winching drill line or drill lines 212, a standpipe 208 that receives mud from the vibrating hose 206, a kelly hose 209 that receives mud from the standpipe 208, a gooseneck or goosenecks 210, a traveling block 211, a crown block 213 for carrying the traveling block 211 via the drill line or drill lines 212 (see, e.g., the crown block 173 of FIG. 1), a derrick 214 (see, e.g., the derrick 172 of FIG. 1), a kelly 218 or a top drive 240, a kelly drive bushing 219, a rotary table 220, a drill floor 221, a bell nipple 222, one or more blowout preventors (BOPs) 223, a drillstring 225, a drill bit 226, a casing head 227 and a flow pipe 228 that carries mud and other material to, for example, the mud tank 201.; FIG.', '2 also shows some examples of types of holes that may be drilled.', 'For example, consider a slant hole 272, an S-shaped hole 274, a deep inclined hole 276 and a horizontal hole 278.; FIG.', '3 shows an example of a system 300 that includes a drilling workflow framework 301, a seismic-to-simulation framework 302, a drilling framework 304, a client layer 310, an applications layer 340 and a storage layer 360.', 'As shown the client layer 310 can be in communication with the applications layer 340 and the applications layer 340 can be in communication with the storage layer 360.', 'In such an example, a computational framework may be provided for handling of logging measurements and/or data derived from logging measurements.', 'For example, logging information may be provided to the seismic-to-simulation framework 302 and/or to the drilling framework 304.', 'Such information may be utilized for model building (e.g., constructing a multidimensional model of a geologic environment), generating a trajectory for a well (e.g., or an extension thereof), generating a stimulation plan (e.g., fracturing, chemical treatment, etc.), controlling one or more drilling operations, etc.; FIG.', '4 shows an example of a wellsite system 400, specifically, FIG.', '4 shows the wellsite system 400 in an approximate side view and an approximate plan view along with a block diagram of a system 470.; FIG.', '4 also shows a battery 480 that may be operatively coupled to the system 470, for example, to power the system 470.', 'As an example, the battery 480 may be a back-up battery that operates when another power supply is unavailable for powering the system 470.', 'As an example, the battery 480 may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery 480 can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a system management bus (SMBus) or other type of bus.; FIG.', '5 shows an example of an environment 501 that includes a subterranean portion 503 where a rig 510 is positioned at a surface location above a bore 520.', 'In the example of FIG.', '5, various wirelines services equipment can be operated to perform one or more wirelines services including, for example, acquisition of data from one or more positions within the bore 520.; FIG. 5 also shows a battery 570 that may be operatively coupled to the system 560, for example, to power the system 560.', 'As an example, the battery 570 may be a back-up battery that operates when another power supply is unavailable for powering the system 560 (e.g., via a generator of the wirelines truck 550, a separate generator, a power line, etc.).', 'As an example, the battery 570 may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery 570 can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.; FIG.', '6 shows some examples of systems 600 and 650 where each of the systems 600 and 650 is a distributed system, which can be defined as a heterogeneous system.', 'For example, the system 600 shows a system X 610 and a system Y 630, which can be in communication via one or more types of telemetry technologies.', 'In such an example, the system X 610 and the system Y 630 can include telemetry circuitry.', 'For example, the system X 610 can include a digital decision model (DDM) generator 612 that can generate a DDM 632 that can be transmitted to the system Y 630.', 'In such an example, the system Y 630 can perform one or more actions that depend on the DDM 632 as stored local to the system Y 630 such as in memory of the system Y 630.; FIG.', '7 shows an example of a method 700 that includes a performance block 710 for performing an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; a transmission block 720 for, responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; and a reception block 730 for, responsive to the request, receiving an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system.', 'As shown, the method 700 can also include a performance block 740 that performs the operation using the system according to at least one of the at least one new decision state.', '; FIG.', '8 shows an example of a method 800 with respect to an NMR unit and a sensed region where the method 800 includes exposing the sensed region to a static magnetic field of the permanent magnet (or magnets), utilizing an antenna (e.g., or other transmitter) to generate an oscillating field that penetrates the sensed region, and utilizing the antenna (e.g., as a receiver) to receive energy released by nuclei in the sensed region.', 'As shown, one or more components can be eccentric such that the NMR unit can have an orientation with respect to the sensed region, which can be a portion of a wall of a borehole.', '; FIG. 8 also shows an example of a tool 850, which can include one or more features such as a stabilizer, a pad, a turbine, etc.', 'The tool 850 includes an NMR unit 870, for which an approximate cross-sectional view along a line A-A is shown.', 'In the cross-sectional view, the NMR unit 870 is shown to include magnets 872, an antenna 874 and circuitry 880, which can include RF emission circuitry, antenna circuitry and analog-to-digital conversion circuitry (e.g., an analog-to-digital converter (ADC)).', 'As an example, the NMR unit 870 can include one or more passages for one or more conduits.', 'For example, consider a power conduit, a data transmission conduit, a power and data conduit, etc.', 'As an example, the tool 850 can include a power source or be operatively coupled to a power source, which may be a fluid driven turbine (e.g., turbogenerator, etc.), a surface power source (see, e.g., the logging truck 550, the battery 570, etc.).', 'As an example, a power source may be a power grid, a generator (e.g., gas, wind, fuel, etc.), a solar panel, a battery, etc.; FIG.', '9 shows an example of a system 900 with respect to a subsurface region that includes a surface 901, various types of formations 902-N-3, 902-N-2, 902-N-1, and 902-N, which may be referred to as formations 902 or individually as individual formations, and that includes a borehole 905 where the formations 902 define a wall of the borehole (e.g., a borehole wall).', 'As shown in the example of FIG.', '9, the formations 902 can be of different thicknesses, of different materials, and may be disposed at different angles with respect to the surface 901.', 'As an example, the borehole 905 may be vertical or deviated.', 'As an example, the borehole 905 may include a vertical portion and a deviated portion.', 'As an example, in a deviated portion, the borehole 905 may traverse the formations 902 in a manner that increases path length such that the path length of the borehole 905 in each of the formations 902 is greater than the thickness of each of the formations 902.; FIG.', '10 shows an example of a microprocessor 1000 that may be utilized in a downhole tool such as an NMR unit (e.g., NMR equipment) along with an example of circuitry 1080 that can include a plurality of microprocessors 1000-1, 1000-2, 1000-3, 1000-4, and 1000-5.', 'As shown, the circuitry 1080 can include a modem processor 1000-1, a controller processor 1000-2, a sequencer processor 1000-3, a processing and diagnostics processor 1000-4, and an acquisition processor 1000-5.', 'Also shown in the example circuitry 1080 of FIG.', '10 are memory, an ADC, a transmitter, a receiver and an antenna (see, e.g., the circuitry 880 of FIG.', '8).;', 'FIG.', '11 shows an example of a graphical user interface (GUI) 1100 that includes graphics derived from NMR data as acquired by an NMR unit of a downhole tool.', 'The GUI 1100 shows four tracks in log form, with respect to depth and various other scales.', 'The GUI 1100 may include, for example, a gamma ray track, which may help to provide indication of position (e.g., depth, measured depth, etc.).', 'As shown, the first track includes a plot of total porosity (e.g., lithology-independent), the second track includes graphics of volumes of clay-bound water, capillary-bound water, and free fluid derived from a measured T2 distribution, the third track includes permeability estimate graphics as derived using Timur-Coates and Schlumberger-Doll-Research (SDR) permeability equations and the fourth track includes the measured T2 distribution as well as the logarithmic mean T2 values at various depths.; FIG.', '12 shows an example of a method 1200 that includes various actions along with approximate graphical representations.', 'The method 1200 includes an exposure block 1210 for exposing nuclei to a static magnetic field, an exposure block 1220 for exposing the nuclei to an oscillating magnetic field, a sequence block 1230 for performing the exposing according to a pre-determined sequence that includes data acquisition, an analysis block 1240 for analyzing at least a portion of acquired data, an inversion block 1250 for inverting at least a portion of the acquired data and converting a decay curve into a distribution of T2 measurements and an analysis block 1260 for analyzing a distribution of T2 measurements with respect to porosity (e.g., pore sizes in the formation investigated), which can correspond to water environments (e.g., clay-bound water, capillary-bound water, free water, etc.).', '; FIG.', '13 shows an example of a system 1310 and an example of a system 1350.', 'As shown, the system 1310 includes a system 1311 that is constrained in one or more manners and includes circuitry such as a sensor 1312, a microprocessor unit (MCU) 1313, memory 1314 and an interface 1315.', 'The system 1310 can acquire data using the sensor 1312 according to one or more parameters as may be set by the MCU 1313 that can depend on execution of instructions stored in the memory 1314 where the instructions can be received, at least in part, via the interface 1315 as can be transmitted by a workstation system 1318 where telemetry between the system 1311 and the workstation system 1318 is limited.', 'As shown, the system 1311 may transmit information (e.g., data, etc.) to the workstation system 1318 via the interface 1315.', 'The system 1310 is heterogeneous in that the circuitry of the workstation system 1318 differs from the circuitry of the system 1311 where, for example, the workstation system 1318 can be, for example, readily hardware upgraded, can include more memory than the memory 1314, can include processing circuitry that is more powerful than the MCU 1313, etc.; FIG.', '14 shows a series of plots 1400 for three consecutive acquisitions, A, B and C, guided by the quantification of model uncertainties.', 'The first row is the sampling space, Πq, with black dots representing the sampling points, open circles representing the SE after each acquisition, and the large circle representing the true sample properties, {q1,q2}0.', 'The second row is the p-domain signals, with thin black traces representing the constructed data sets from original Πq, open traces from SEs, the thick black trace from {q1,q2}0, and black dots with error bars representing the acquired data.', 'The third row is the calculated variance, σ2, for the Solution Ensemble at each p in Πp, with the open/solid circles representing the variance before and after an acquisition, and the dashed line representing the instrument noise level.', 'The regression model in the example of FIG.', '14 is according to Equation 15.; FIG.', '15 shows an example of a method for construction and use of a multiclass regression tree 1500, which can be a DDM.', 'FIG.', '15 includes a series of plots and diagrams labeled (A) as a heuristic illustration of constructing a multiclass regression tree, which may be at a workstation, where decision nodes are in the same line types as the corresponding p—domain signals and ε is the instrument noise level; and a diagram labeled (B), which is an illustration of use of a regression tree in a simulation where, at each node, a bar underneath is the mean of two bounds of the interval attribute (e.g., (bmax+bmin)/2), and the number is the parameter index in Πp, from 1 to 100, at which the acquisition is taken.', 'Below, a description of various examples of tree traversal are provided, which as mentioned, can include having the tree in a particular state, which may be utilized, for example, to automatically request an update to the tree.', 'As mentioned, a digital decision model (DDM) may be a tree or other type of decision structure that can be of a size suitable for loading and using in a constrained system (see, e.g., the system 1351 of FIG. 13).', '; FIG.', '16 shows an example plot 1600 with a number of nodes versus sampling points of q, with a regression model of Equation 6 (above).', 'As shown, at higher SNR (such as 80), denser sampling points are demanded to resolve minute differences of high-resolution data, which result in a large tree.', 'While a system may have insufficient memory to store trees with more than 80 decision nodes, the system may be limited to perform an optimization routine under a certain SNR envelope.; FIG.', '17 shows an example of a diagram 1700 of a zoom-in attribute.', 'The diagram 1700 shows a first row Πq, with black dots as the original sampling points, other dots (e.g., circles) as the Solution Ensembles before (A) and after (B) a “zoom-in” operation; the second row show p-domain signals, with black traces from Πq, II white filled traces from the respective Solution Ensembles, a thick black filled trace from the sample ground truth, and black dots are the acquired data; and the third row shows the first regression tree in A, the second “zoom-in” tree in B, and the traversal pathway in white with a thick black outline.; FIG.', '18 shows an example of a diagram 1800 of a zoom-out attribute.', 'In the example of FIG.', '18, the diagram shows the first row representing Πq, with black dots as the original sampling points, open circles as the Solution Ensemble after “zoom-out” in B, and the large open circle as the sample ground truth; the second row shows p—domain signals, with black traces from Πq, white filled traces from the Solution Ensemble, the thick black filled trace from the sample ground truth, and each black dot being the acquired data; and the third row shows the first regression tree in A, the second “zoom-out” tree in B, and the acquisition pathway in being a white filled pathway with a thick black border.; FIGS. 19, 20 and 21 show an example of running a regression tree in a simulated NMR experiment where the regression tree is an example of a digital decision model (DDM).', 'In FIG.', '19, a series of plots 1900 are shown; in FIG.', '20, a plot 2000 is shown; and in FIG.', '21, the regression tree 2100 is shown.; FIG.', '22 shows an example of a series of plots 2000 for an example of a zoom-in process in a simulated NMR experiment.', 'In FIGS.', '22, A, B and C represent the iterations of real-time optimization on data acquisition.', 'In the first row, the outlined regions represent the Solution Ensembles before (A), after three (B), and four (C) acquisitions, and the open circle is the sample ground truth.', "In the second row, black traces are constructed {tilde over (S)}'s from their respective Solution Ensembles, and black dots represent acquired data.", 'In FIG.', '22, the plot labeled D shows the maximum variance of Solution Ensembles over 4 acquisitions, with the dashed line being the instrument noise floor.;', 'FIG.', '23 shows an example of a series of plots 2300 of an example of a zoom-out process in a simulated NMR experiment.', 'As shown in FIGS.', '23, A, B and C are the three iterations of realtime optimization on data acquisition.', 'In the first row, the outlined regions are the Solution Ensembles after the previous acquisition, and the open circle is the sample ground truth.', "In the second row, black traces are constructed S's from their respective Solution Ensembles, and black dots represent the acquired data.", 'In FIG.', '23, the plot labeled D shows the maximum variance of SE over three acquisitions, with the dashed line being the instrument noise floor.;', 'FIG.', '24 shows examples of pseudocode algorithms 2410 and 2430 for examples of methods for a zoom-in attribute for 2D sampling space with non-convex sets.; FIG.', '26 shows components of a computing system 2600 and a networked system 2610.', 'The system 2600 includes one or more processors 2602, memory and/or storage components 2604, one or more input and/or output devices 2606 and a bus 2608.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components 2604).', 'Such instructions may be read by one or more processors (e.g., the processor(s) 2602) via a communication bus (e.g., the bus 2608), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device 2606).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.']

US11939248

System and method for using subterranean biological reactors

Apr 10, 2023

Dean Michael Willberg, Andrew Pomerantz, Thorarinn Kristjansson

Schlumberger Technology Corporation

International Search Report and Written Opinion of International Patent Application No. PCT/US2019/039002 dated Sep. 3, 2019, 6 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2019/039002 dated Jan. 7, 2021, 6 pages.

3724542; April 1973; Hamilton; 6299774; October 9, 2001; Ainsworth; 6668925; December 30, 2003; Shaw; 7297274; November 20, 2007; Wilkie; 7905683; March 15, 2011; Kearney; 20040026334; February 12, 2004; Soll; 20060178547; August 10, 2006; Bruno; 20210122656; April 29, 2021; Willberg

Foreign Citations not found.

['A system and method using a subterranean biological reactor can include a pre-reactor storage unit configured to receive a feedstock including a slurry of biologically derived material and at least one pump configured to pump the effluent from the pre-reactor storage unit.', 'The system may include at least one wellbore containing a subterranean biological reactor configured to receive the effluent from the pre-reactor storage unit.', 'At least a portion of the subterranean biological reactor may be configured to perform anaerobic digestion upon the effluent to generate a biogas.']

['Description\n\n\n\n\n\n\nRELATED APPLICATIONS', 'This application is a Continuation of U.S. application Ser.', 'No. 17/251,435, filed on Dec. 11, 2020, which is a National Stage of International Application No.', 'PCT/US2019/039002, filed on Jun. 25, 2019, which claims the benefit of U.S. Provisional Application No. 62/690,145, filed on Jun. 26, 2018; the contents of which are incorporated herein by reference.', 'FIELD OF THE INVENTION', 'This application relates to a system and apparatus directed towards subterranean biological reactors.', 'BACKGROUND\n \nThe relentless focus to increase drilling and fracturing efficiency in unconventional plays has in recent years driven down the cost of oil and gas well construction.', 'The upstream oil and gas industry has dramatically reduced drilling, construction and completion costs of on-shore unconventional and conventional wells.', 'Even more important, the reliability and efficiency of drilling and completion practices has steadily increased, and the failure rate of completing to design continues to fall.', 'Multistage hydraulic fracturing of horizontal wells, multi-well pad drilling, steam assisted gravity drainage (“SAGD”) for heavy oil wells, and other completion strategies have changed the concept of what a productive hydrocarbon asset is and what its design looks like.', 'Today, multi-well pads often contain four or more horizontal wells with coordinated trajectories and operations that optimize drainage of large reservoir blocks.', 'The advantages of this type of construction for hydrocarbon production are clear—reduced surface footprints, lower equipment mobilization costs, and the ability to share surface facilities.', 'SUMMARY\n \nIn some embodiments, a system using a subterranean biological reactor is provided.', 'The system may include a pre-reactor storage unit configured to receive a feedstock including a slurry of biologically derived material and at least one pump configured to pump the effluent from the pre-reactor storage unit.', 'The system may include at least one wellbore containing a subterranean biological reactor configured to receive the effluent from the pre-reactor storage unit.', 'At least a portion of the subterranean biological reactor may be configured to perform anaerobic digestion upon the effluent to generate a biogas.', 'One or more of the following example features may be included.', 'The feedstock may include at least one of agricultural waste, sewage, manure, food processing plant waste, fermentation processes waste, municipal solid waste, biosolids, source separated organics, locally generated waste, and transported waste.', 'The feedstock may be blended with one or more of water, microbes, nitrogen gas, chemical additives and minerals to generate chemical content suitable for the subterranean biological reactor.', 'The feedstock may be stored on site prior to injection into the subterranean biological reactor and wherein initial stages of the anaerobic digestion occur prior to injection into the subterranean biological reactor.', 'The at least one wellbore may include a plurality of wellbores connected by hydraulic fractures.', 'The subterranean biological reactor may be either isolated from one or more subterranean formations or in communication with one or more subterranean formations.', 'The at least one pump may be a positive displacement pump or centrifugal pump.', 'The biogas may include a combination of methane, carbon dioxide and trace gas species.', 'The subterranean biological reactor may include one or more downhole separators configured to separate out gas, solid and liquid.', 'The system may include an agitator selected from the group consisting of downhole static mixers, casing rotation, jetting, or rotary mixers.', 'The subterranean biological reactor may include at least one of permanently directional and operated in a backflow condition.', 'The subterranean biological reactor may be associated with one or more downhole sensors to determine at least one of temperature, pressure, pH, and solid volume fraction.', 'The biogas may be provided to a subterranean formation.', 'Spent fluid and solid residues may be returned to the surface either through the at least one wellbore.', 'The system may operate in at least one of a continuous, semi continuous, or cyclical modes.', 'In another example implementation, a method using a subterranean biological reactor is provided.', 'The method may include receiving a feedstock including a slurry of biologically derived material at a pre-reactor storage unit and pumping, using at least one pump, the effluent from the pre-reactor storage unit.', 'The method may further include receiving, at one or more wellbores containing a subterranean biological reactor, the effluent from the pre-reactor storage unit, wherein at least a portion of the subterranean biological reactor is configured to perform anaerobic digestion upon the effluent to generate a biogas.\n \nOne or more of the following example features may be included.', 'The feedstock may include at least one of agricultural waste, sewage, manure, food processing plant waste, fermentation processes waste, municipal solid waste, biosolids, source separated organics, locally generated waste, and transported waste.', 'The feedstock may be blended with one or more of water, microbes, nitrogen gas, chemical additives and minerals to generate chemical content suitable for the subterranean biological reactor.', 'The method may include storing the feedstock on site prior to injection into the subterranean biological reactor and wherein initial stages of the anaerobic digestion occur prior to injection into the subterranean biological reactor.', 'The at least one wellbore may include a plurality of wellbores connected by hydraulic fractures.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe present invention is illustrated by way of example, and not limitation, in the figures of the accompanying drawings in which like references indicate similar elements and in which:\n \nFIG.', '1\n illustrates a diagram of a subterranean biological reactor system in accordance with embodiments of the present disclosure;\n \nFIG.', '2\n illustrates a diagram of a subterranean biological reactor system showing a single wellbore isolated from the formation in accordance with embodiments of the present disclosure;\n \nFIG.', '3\n illustrates a diagram of a subterranean biological reactor system showing a single wellbore connected to the formation in accordance with embodiments of the present disclosure;\n \nFIG.', '4\n illustrates a diagram of a subterranean biological reactor system showing multiple wellbores connected to the formation in accordance with embodiments of the present disclosure; and\n \nFIG.', '5\n illustrates a diagram of a subterranean biological reactor system showing a single use pressurization or re-pressurization squeeze in accordance with embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'The discussion below is directed to certain implementations and/or embodiments.', 'It is to be understood that the discussion below may be used for the purpose of enabling a person with ordinary skill in the art to make and use any subject matter defined now or later by the patent “claims” found in any issued patent herein.', 'It is specifically intended that the claimed combinations of features not be limited to the implementations and illustrations contained herein, but include modified forms of those implementations including portions of the implementations and combinations of elements of different implementations as come within the scope of the following claims.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions may be made to achieve the developers' specific goals, such as compliance with system-related and business related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Nothing in this application is considered critical or essential to the claimed invention unless explicitly indicated as being “critical” or “essential.”', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms may be used to distinguish one element from another.', 'For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the disclosure.', 'The first object or step, and the second object or step, are both objects or steps, respectively, but they are not to be considered a same object or step.', 'Referring now to \nFIGS.', '1\n-\n5\n, embodiments of the present disclosure are provided.', 'Embodiments may include adapting oilfield drilling, completions, well-logging, well-intervention and integrated production management technologies to construct and operate subterranean biological reactors (“SBR”).', 'Accordingly, embodiments included herein may be used to create useful carbon-neutral products—such as biogenic methane—from agricultural and urban waste streams.', 'Embodiments included herein may provide cost effective enhanced oil recovery (“EOR”) services for heavy oil reservoirs and may also provide cost effective methane and carbon dioxide for EOR in spent Brownfields, and in unconventional plays that are at a late stage in primary production.', 'Embodiments included herein may be used to repurpose spent production assets (e.g., late production wells, well-pads and brownfields).', 'Some embodiments may be used to provide value-added services including waste disposal, ground water protection, and carbon sequestration (including potentially carbon-negative technologies), while additionally delaying abandonment costs.', 'Embodiments may be used to enable commercially viable means of exploiting low-grade geothermal energy and allow for re-locating large footprint waste treatment reactors underground.', 'Advances in drilling, well-construction, hydraulic fracturing and completions may be readily adapted for constructing large-volume subterranean reactors.', "If the structure, volumes and hydrodynamics of these reactors are optimized for microbial and biochemical operations, it is conceivable that SBR's could economically compete with—or exceed the performance of—conventional anaerobic digestion plants built on the surface.", 'Furthermore, the scientific literature indicates that the elevated temperatures, high pressures and isolation of the subterranean environment could be an inherent advantage of SBRs over anaerobic digesters built on the surface.', 'By strategically locating SBRs that generate biogenic methane and carbon dioxide within brownfields or heavy oil reservoirs—we could synergistically use them to drive EOR operations.', 'Finally, by permanently storing a fraction of the organic agricultural/municipal waste the process could generate carbon storage credits.', 'As is discussed in further detail below, embodiments of the present disclosure include two related designs.', 'In some embodiments, the construction and operation of a subterranean biological reactor (SBR) is disclosed.', 'This SBR may refer to a structure within a subterranean formation into which biological material may be injected, and within which the biological material undergoes at least one of the stages of anaerobic digestion thereby producing biogas (a mixture primarily composed of methane and carbon dioxide).', 'The SBR may be constructed and operated in many different configurations most often as some variation of a flow through reactor.', 'Many embodiments of these SBR structures are described in further detail below.', "In some embodiments, SBR's may be used to perform useful chemical processes, useful mechanical work, and or useful environmental services in the subterranean environment.", 'These useful processes, work or services may be performed either in concert or individually, depending on the specific SBR construction and operation—the SBR can be designed for local specific needs.', 'These processes, work and services are described in further detail below.', 'Anaerobic digestion is a technology that may be used in wastewater treatment facilities as a second stage following aerobic digestion.', 'It is a complex process carried out by a consortium (community) of different anaerobic microorganisms that involves sequential hydrolysis, acidogenesis, and methanogenesis stages in the conversion of organic materials to simpler waste products—namely methane and carbon dioxide.', 'The mass of methane produced may be significant, and is often used locally to power the waste water treatment facilities.', 'There are commercial enterprises that may be involved with connecting anaerobic digestion produced bio-gas to the utilities grid.', "Anaerobic digestion is an attractive candidate for adapting to use in SBR's.", 'Anaerobic digestion has shown itself to be robust, and not sensitive to reasonable ranges of input and environmental variations.', 'Unlike many mono-cultures, microbial consortium may be more adaptive and resilient to environmental changes.', 'Moreover, anaerobic processes tend to generate less cell mass than aerobic processes, and may lead to better conversion efficiencies to the final bio-gas products and minimize the production of solid organic wastes.', 'Anaerobic digestion may benefit by operating at elevated pressures and temperatures.', "Furthermore, surveys of black smokers and deep-ocean hydrothermal vents have shown that similar thermophilic, methanogenic, anaerobic communities exist in high-pressure extreme environments that have the potential to be harnessed for SBR's.", 'Therefore, the subterranean environment—that may be accessed through oil and gas wells, may be a better suited location for this process than on the surface.', "Embodiments of the present disclosure may be used to re-purpose recent oilfield technological developments into the creation and operation of SBR's—leveraging the unconventional oil and gas industry's experience and economies-of-scale.", 'In some embodiments, unconventional drilling and completion techniques with minimal alteration may be used to create reactors of sufficient subterranean volume for anaerobic digestion reactor design and operations.', 'In some embodiments, reliable and flexible wellbore and completion architectures, equipment and workflows may be employed.', "These technologies have many features that are useful and attractive for plug-flow anaerobic digestion reactor designs, and SBR's could benefit from the economies-of-scale already developed for unconventional oil and gas applications.", 'The development of centralized pad facilities, high density-closely spaced drilling, and the developing technologies surrounding fracture control and monitoring all play into the design and operation of “waste-to-useful” products facilities.', "In some embodiments, the determination of reactor volume—coupled with process kinetics and residence times—may be a factor in determining how effective SBR's can be at generating meaningful quantities of useful biogenic gases.", 'The large volumes of multi-stage horizontal wellbores (“MSHW”) generates significant flexibility in reactor design and operation.', 'Currently the volume of a single MSHW wellbore can range from 32-70 m\n3 \n(recent numbers from the Permian basin).', 'The pore volumes in the hydraulic fractures are highly variable and depend on the volume of proppant pumped, but these could be in the range of 200-2000 m\n3\n.', 'This number can be increased, by placing more sand at high concentrations, or by employing a channel-fracturing technique during construction.', 'The preliminary analysis in the waste to useful-products section below show that operationally significant quantities of biogenic gas can be created with reactors of these volumes.', 'In some embodiments, centralized pad facilities, high density-closely spaced wells, highly controlled fracturing programs and instrumented CT operations all could facilitate the design and operation of small footprint “waste-to-useful products” facilities.', "Footprint size is one of many potential advantages that SBR's may have over anaerobic digestion reactors on the surface.", "Furthermore, reactors that are created from two or more wellbores could substantially increase the size and efficiency of SBR's.\n \nReferring again to \nFIG.", '1\n, an embodiment depicting an example SBR consistent with the teachings of the present disclosure is provided.', 'FIG.', '1\n shows a pre-reactor storage unit \n102\n configured to receive a feedstock including a slurry of biologically derived material.', 'Storage Unit \n102\n is operably connected to at least one pump \n104\n, which is configured to pump the effluent from pre-reactor storage unit \n102\n to at least one wellbore containing a subterranean biological reactor \n106\n configured to receive the effluent from the pre-reactor storage unit.', 'At least a portion of the subterranean biological reactor \n106\n may be configured to perform anaerobic digestion upon the effluent to generate a biogas and to provide the biogas for subsequent storage.', 'In some embodiments, the biogas may be produced to the surface and sold.', 'In some embodiments, the design may include an anaerobic digestion plant to be located (in part) in the subterranean environment.', "Deploying anaerobic digestion in SBR's in situ in oilfield reservoirs significantly boosts the value creation of anaerobic reactors.", 'In commercial anaerobic digestion reactors methane production and biological oxygen demand (“BOD”) reduction are the primary value-adding objectives.', 'Carbon dioxide production in these reactors is a waste stream and a separations nuisance.', "Carbon dioxide production is a benefit for SBR's.", "One of the unique features of SBR's is that they could be used to generate bio-gas in situ within heavy oil or depleted brownfields for re-pressurization or EOR (methane-CO2) flood activities—while also providing a value-added service in the treatment of waste.", 'In some embodiments, minimizing the required hydraulic retention time (“HRT”) is an important issue to address for all the embodiments included herein.', 'The HRT in mesophilic conditions can range from 4-30 days.', 'Thermophilic anaerobic digestion can be faster.', 'For example, for a 1000 m\n3 \nSBR operating at an HRT of 4 days—the reactor could place 8000 m\n3 \n(280 MSCF) of combined CH\n4\n/CO\n4\n) into the reservoir per day.', 'If the residence time can be shortened under thermophilic digestion regimes, or by engineering processes—then the rate of gas generation and injection could be higher.', 'In some embodiments, the design may be constructed in many different configurations.', 'Some embodiments may include a feedstock comprising of a slurry containing biological derived material, for example, agricultural waste, sewage, manure, food processing plant waste, fermentation processes waste, municipal solid waste, biosolids, source separated organics, etc.', 'The biologically derived material can be generated locally (e.g., from a local feedlot), or transported to the site.', 'The feedstock can be raw (unprocessed manure) or it can be processed, for example, it can be ground and mixed with water.', 'The feedstock can be a blended combination of biological sourced materials, or it can be a combination thereof.', 'In some embodiments, the feedstock may be blended from various sources with water, nitrogen gas, chemical additives and minerals to have the right physical properties (solids fraction, density, etc.) and the right chemical content (C, N, P, S, K salinity, pH, buffer capacity etc.)', 'for the desired behavior in the anaerobic reactor.', 'The feedstock may be stored on site prior to injection into the SBR.', 'Initial stages of the anaerobic digestion may occur at the surface prior to injection into the SBR.', 'The primary container for the SBR reactor may be a wellbore, or multiple wellbores connected by hydraulic fractures (see below).', 'In some embodiments, the feedstock may be blended with microbes capable of performing anaerobic digestion quickly and robustly under the conditions occurring in the SBR.', 'In some embodiments, and depending on the specific application, the SBR reactor may either be sealed (isolated from) one or many subterranean formations, or it can be constructed to have communication with the formation (see below).', 'The feedstock may be prepared in such a fashion that it can be pumped downhole using liquid pumps (either positive displacement or centrifugal pumps).', 'In some embodiments, the feedstock may undergo anaerobic digestion at some location within the SBR and generate a biogas, which may include a combination of methane, carbon dioxide and trace gas species.', 'In some embodiments, depending on the specific embodiment, the SBR may have downhole separators in place to separate out gas and liquid/solid streams.', 'Downhole agitation may or may not be used.', 'Agitation may include, but is not limited to, downhole static mixers, casing rotation, jetting, or rotary mixers.', "In some embodiments, the flow-through SBR's may be designed to be permanently directional.", 'Additionally and/or alternatively, they can be designed to be operated in a backflow condition to facilitate reactor cleaning, and to address reactor plugging.', 'In some embodiments, the SBR may or may not be instrumented with downhole sensors to provide important operational parameter (temperature, pressure, pH, solid volume fraction, etc.).', 'In some embodiments, and depending on the reactor design, the biogas may be directly collected out of the SBR for use and sold, or it may be directed into a subterranean formation.', 'Spent fluid and solid residues may be returned to the surface either through the same wellbore or through a different wellbore.', 'Recovered solids may be used as a soil ameliorant, or landfilled.', 'In some embodiments, recovered water from the process may be recycled in preparation of additional feedstock.', 'It should be noted that the embodiments included herein may be operated in either continuous, semi continuous, or cyclical modes.', 'For example, a pre-conditioning stage of fluid to prepare the formations water saturations (i.e. flush out excess salt) can be pumped prior to use with feedstock.', 'Referring now to \nFIG.', '2\n, an embodiment showing a single wellbore-isolated from the formation is provided.', 'In this particular embodiment the drilled and cased well may be used as a sealed reactor.', 'This reactor may function as a concentric flow-through reactor, wherein everything that goes in comes back out.', 'The casing may be cemented into the formation and no perforations, ports, slots or fractures connect the wellbore to the formation.', 'In this situation the subterranean formation acts as a heat source or sink for the SBR, therefore providing thermal energy.', 'The pumps and hydrostatic head provide the pressure for operation.', 'In one variation of this embodiment, the feedstock may be pumped down the annulus at the controlled rate.', 'The biogas, water and residual water may be produced to the surface through the installed tubing.', 'The higher flow rates through the tubing—aided by both the lower cross-section and by the biogas provided lift will help keep the residual solids in suspension and return to the surface.', 'Alternatively, the flow can be periodically reversed to facilitate cleaning.', 'Specifically, \nFIG.', '2\n depicts a vertical wellbore, however, the wellbore may also be constructed in a deviated or horizontal configuration.', 'The system may include a cased and cemented wellbore \n202\n, tubing \n204\n installed in the well bore (note that this tubing may be rotated to agitate the slurry in the annulus, inflow of material from the surface facilities, outflow of effluent, the surface of the ground, the subterranean environment, the depth of the wellbore may be designed to meet pressure, temperature requirements of the anaerobic digestion process used, the slurry is being pumped down tubing and flowing back up the annulus, in other embodiments it is possible that the flow may be reversed.', 'Referring now to \nFIG.', '3\n, an embodiment showing a single wellbore connected to the formation is provided.', 'In this embodiment the drilled and cased well may be connected to at least one formation through perforations, ports, slotted liner, screen, gravel pack or hydraulic fractures.', 'This reactor would still function as a concentric flow-through reactor—but some or all the biogas generated (and possibly some water as well) may be directed into the surrounding reservoir rock.', 'In this embodiment, the subterranean formation acts as a heat source or sink for the SBR, therefore providing thermal energy to accelerate the anaerobic digestion.', 'The pumps and hydrostatic head may provide the pressure for operation.', 'However, in this situation the SBR is used to pressurize the formation with biogas.', 'For this design to work, at least some level of downhole gas/liquid separation will be required.', 'In most cases some flow of liquid would be required to carry solid residue back to the surface.', 'It should be noted that it is not necessary that the formation which acts as the heat source and formation receiving the gas be the same formation.', 'Gas injection could occur at a different location in the wellbore than where the anaerobic digestion is occurring.', 'Specifically, \nFIG.', '3\n depicts a vertical wellbore, however, the wellbore may also be constructed in a deviated or horizontal configuration.', 'The system may include a cased and cemented wellbore \n302\n, tubing \n304\n installed in the well bore (note that this tubing may be rotated to agitate the slurry in the annulus, inflow of material from the surface facilities, outflow of effluent, the surface of the ground, the subterranean environment, the region of the subterranean formation into which the biogas is being injected, a packer assembly \n306\n, a one-way check valve \n308\n that allows for the working slurry to be pumped into the lower chamber, perforations \n310\n, slotted liner or screen assembly to allow for communication between the wellbore and formation, biogas pocket in the lower chamber, reacting fluid in the lower chamber of the wellbore.', 'Referring now to \nFIG.', '4\n, an embodiment showing a multiple wellbore configuration is provided.', 'In this particular embodiment the SBR may be built using two or more wells (e.g., vertical, horizontal or deviated) and includes injection well \n402\n, return well \n404\n, and the hydraulic fractures that connect the two wells.', 'The multiple drilled and cased wells may be connected through the formation by at least one hydraulic fractures.', 'If the wellbores are horizontal, they may be connected by multiple hydraulic fractures.', 'The volume of the hydraulic fractures may also greatly increase the volume of the SBR.', 'This reactor may still function as a concentric flow-through reactor, however, some or all the biogas generated (and possibly some water as well) may be directed into the surrounding reservoir rock.', 'In this embodiment, the subterranean formation may act as a heat source or sink for the SBR, therefore providing thermal energy to accelerate the anaerobic digestion.', 'However, in this situation the SBR may be used to pressurize the formation with biogas through hydraulic fractures which themselves are an integral part of the reactor volume.', 'In some embodiments, hydraulic fracture conductivity may be a factor in the implementation of this embodiment.', 'The hydraulic fractures may have to be created with sufficient proppant, or with channel fractures so that the solid residues from the anaerobic processes can be cleared, and returned to the surface through the return well.', 'Since the circulating reactor fluid may come into direct contact with the formation, the properties of the formation rock may have an effect on the design and operation of this embodiment.', 'First, the rock should not be prone to weathering in the presence of both added water and CO\n2\n.', 'Second, the chemistry of the connate water and in situ hydrocarbons must either be compatible with the microbial complex in the SBR, or the fractures may need to be pre-treated to flush away noxious chemical prior to the beginning of the anaerobic digestion process.\n \nReferring now to \nFIG.', '5\n an embodiment showing a single-use pressurization or re-pressurization squeeze is provided.', 'In this particular embodiment, a single-use dose of feedstock and anaerobic digester culture may be injected into a wellbore and used to hydraulically fracture a formation.', 'Here, the cased and cemented wellbore \n502\n, the biologically active fluid is pumped at fracturing pressures into the formation, the perforations, sliding sleeves, slotted liner or other method of communication \n504\n between the wellbore and formation, the hydraulic fracture \n506\n created by the process, the ground, and the subterranean formation treated by this process.', 'The original dose undergoes anaerobic digestion generating biogas that pressurizes the formation.', 'This application will be helpful for pressurizing and adding gas to low pressure heavy oil wells.', 'As such, this method could be a means of pre-treating formations for solution gas or cold heavy oil production with sand) (“CHOPS”) drive mechanisms.', 'In this embodiment, the size of the hydraulic fracturing treatment with the feedstock will have to be of sufficient size to generate a meaningful volume of gas.', 'In some embodiments, the original fracturing slurry may be injected carrying sand or proppant so that the fracture will stay open and remain conductive.', 'After the initial fracturing, high bio-active liquid feedstock can be continually injected into the fracture to generate even more gas.', 'This process will likely function for a limited period till either residual solids (or cell bodies) plug up the fracture, or till waste products from the anaerobic digestion impede further cell growth.', 'In some embodiments, the present disclosure may include techniques for using an SBR to perform chemical processes, mechanical work, and/or useful environmental services in the subterranean environment.', "SBR's are versatile, and may be adapted to a number of practical applications, some of which may include, but are not limited to, generating biogas, pressurizing subterranean formations—such as for depleted brownfields and heavy oil stimulation—to enhance liquid hydrocarbon recovery, carbon storage, and enhanced use of geothermal resources.", 'In some embodiments, the present disclosure may be used for anaerobic digestion and biogenic gas production (no direct oilfield application).', "SBR's are an alternative for anaerobic digesters that are constructed on the surface, and may be operated at much higher pressures.", 'Furthermore, by using geothermal heat they may not require additional heat sources.', 'In some embodiments, the present disclosure may be used for Brownfield re-pressurization, CH\n4\n/CO\n2 \nsweeps, and enhanced liquid hydrocarbon recovery.', 'Pumping liquids to high pressures is less expensive than compressing gas to equivalent pressures.', "For example, the SBR's described above may be used to either pressurize depleted reservoirs, or serve as gas injectors for gas sweeps in enhanced oil recovery operations.", 'In some embodiments, the present disclosure may be used for heavy oil stimulation.', "For example, SBR's can be used (as described above) to charge heavy oil reservoirs with additional gas (CO\n2 \nand CH\n4\n) to increase pore pressure and to assist with either solution gas drive or CHOPS production.", 'In some embodiments, the present disclosure may be used for enhanced use of geothermal resources.', 'There are many geothermal reservoirs that have insufficient temperature gradients to drive steam-turbine electrical generation facilities.', 'However, these “cooler” reservoirs could be excellent candidates to drive higher rate thermophilic,', "anaerobic digestion SBR's at relatively shallow drilling depths.", 'In some embodiments, the present disclosure may be used for carbon capture and storage.', 'Any of the embodiments described above may be used in this arrangement, where at least some of the biogas generated remains in the subterranean formation.', 'This may occur naturally in some formations where CO\n2 \nis preferentially adsorbed to kerogen and coal cleats.', 'In some embodiments, the present disclosure may be used for biogas produced above ground and injected into a well.', 'In this utilization, the biogas may be produced above ground in a conventional anaerobic digester and injected into the well.', 'The biogas may be used to increase the pressure in the reservoir and to enhance oil/gas recovery.', 'The gas may then be brought up to the surface, a mixture of biogas and natural gas, where it may be cleaned or utilized in another manner.', 'It is specifically intended that the claimed combinations of features not be limited to the implementations and illustrations contained herein, but include modified forms of those implementations including portions of the implementations and combinations of elements of different implementations as come within the scope of the following claims.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions may be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Nothing in this application is considered critical or essential to the claimed invention unless explicitly indicated as being “critical” or “essential.”', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms may be used to distinguish one element from another.', 'For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the disclosure.', 'The first object or step, and the second object or step, are both objects or steps, respectively, but they are not to be considered a same object or step.', 'The flowchart and block diagrams in the figures illustrate the architecture, functionality, and operation of possible implementations of systems and methods and according to various embodiments of the present disclosure.', 'In this regard, each block in the flowchart or block diagrams may represent a module, segment, or portion of code, which comprises one or more executable instructions for implementing the specified logical function(s).', 'It should also be noted that, in some alternative implementations, the functions noted in the block may occur out of the order noted in the figures.', 'For example, two blocks shown in succession may, in fact, be executed substantially concurrently, or the blocks may sometimes be executed in the reverse order, depending upon the functionality involved.', 'It will also be noted that each block of the block diagrams and/or flowchart illustration, and combinations of blocks in the block diagrams and/or flowchart illustration, can be implemented by special purpose hardware-based systems that perform the specified functions or acts, or combinations of special purpose hardware and computer instructions.', 'The terminology used herein is for the purpose of describing particular embodiments and is not intended to be limiting of the disclosure.', 'As used herein, the singular forms “a”, “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will be further understood that the terms “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'The corresponding structures, materials, acts, and equivalents of means or step plus function elements in the claims below are intended to include any structure, material, or act for performing the function in combination with other claimed elements as specifically claimed.', 'The description of the present disclosure has been presented for purposes of illustration and description, but is not intended to be exhaustive or limited to the disclosure in the form disclosed.', 'Many modifications and variations will be apparent to those of ordinary skill in the art without departing from the scope and spirit of the disclosure.', 'The embodiment was chosen and described in order to best explain the principles of the disclosure and the practical application, and to enable others of ordinary skill in the art to understand the disclosure for various embodiments with various modifications as are suited to the particular use contemplated.', 'Although a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from the scope of the present disclosure, described herein.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.', 'Having thus described the disclosure of the present application in detail and by reference to embodiments thereof, it will be apparent that modifications and variations are possible without departing from the scope of the disclosure defined in the appended claims.']

['1.', 'A system comprising:\na pre-reactor storage unit configured to receive a feedstock including a slurry of biologically derived material;\nat least one pump configured to pump effluent from the pre-reactor storage unit;\nat least one wellbore containing a subterranean biological reactor configured to receive the effluent from the pre-reactor storage unit, wherein at least a portion of the subterranean biological reactor is configured to perform anaerobic digestion upon the effluent to generate a biogas, and wherein the subterranean biological reactor comprises an agitator.', '2.', 'The system according to claim 1, wherein the feedstock includes at least one of agricultural waste, sewage, manure, food processing plant waste, fermentation processes waste, municipal solid waste, biosolids, source separated organics, locally generated waste, and transported waste.', '3.', 'The system according to claim 1, wherein the feedstock is blended with one or more of water, nitrogen gas, one or more of microbes capable of performing the anaerobic digestion, chemical additives and minerals to generate chemical content suitable for the subterranean biological reactor.', '4.', 'The system of claim 1, wherein the feedstock is stored on site prior to injection into the subterranean biological reactor and wherein initial stages of the anaerobic digestion occur prior to injection into the subterranean biological reactor.', '5.', 'The system of claim 1, wherein the at least one wellbore includes a plurality of wellbores connected by hydraulic fractures.', '6.', 'The system of claim 1, wherein the subterranean biological reactor is in communication with one or more subterranean formations.', '7.', 'The system of claim 1, wherein the agitator is configured to provide agitation in an annulus between the at least one wellbore and a tubing disposed in the at least one wellbore.\n\n\n\n\n\n\n8.', 'The system of claim 1, wherein the biogas includes a combination of methane, carbon dioxide, and trace gas species.', '9.', 'The system of claim 1, wherein the subterranean biological reactor includes one or more downhole separators configured to separate out gas, solid, and liquid.', '10.', 'The system according to claim 1, wherein the agitator is configured to provide agitation via movement of a tubing disposed in the at least one wellbore, jetting, or a combination thereof.', '11.', 'The system according to claim 1, wherein the subterranean biological reactor is configured to selectively operate in a first flow direction and a second flow direction in a backflow condition, and the second flow direction is reversed relative to the first flow direction.', '12.', 'The system according to claim 1, wherein the subterranean biological reactor is associated with one or more downhole sensors to determine each of temperature, pressure, pH, and solid volume fraction.', '13.', 'The system according to claim 1, wherein the subterranean biological reactor comprises:\na packer disposed in the at least one wellbore about a tubing between an upper chamber and a lower chamber;\na valve coupled to the packer;\na reacting fluid region in the lower chamber; and\na biogas pocket in the lower chamber between the packer and the reacting fluid region, wherein the valve is configured to control flow of the effluent from the upper chamber to the lower chamber.', '14.', 'The system according to claim 1, wherein spent fluid and solid residues are returned to the surface through the at least one wellbore, and the biogas is provided to a subterranean formation.', '15.', 'The system according to claim 1, wherein the system selectively operates in continuous, semi continuous, and cyclical modes.', '16.', 'A method comprising:\nreceiving a feedstock including a slurry of biologically derived material at a pre-reactor storage unit;\npumping, using at least one pump, effluent from the pre-reactor storage unit;\nreceiving, at one or more wellbores containing a subterranean biological reactor, the effluent from the pre-reactor storage unit, wherein at least a portion of the subterranean biological reactor is configured to perform anaerobic digestion upon the effluent to generate a biogas, and wherein the subterranean biological reactor comprises an agitator.', '17.', 'The method according to claim 16, wherein the feedstock includes at least one of agricultural waste, sewage, manure, food processing plant waste, fermentation processes waste, municipal solid waste, biosolids, source separated organics, locally generated waste, and transported waste.', '18.', 'The method according to claim 16, further comprising:\nblending the feedstock with one or more of water, nitrogen gas, chemical additives, and minerals to generate chemical content suitable for the subterranean biological reactor.', '19.', 'The method of claim 16, further comprising:\nstoring the feedstock on site prior to injection into the subterranean biological reactor and wherein initial stages of the anaerobic digestion occur prior to injection into the subterranean biological reactor; and\nblending the feedstock with one or more of microbes capable of performing the anaerobic digestion.', '20.', 'The method of claim 16, wherein the agitator is configured to provide agitation via movement of a tubing disposed in the one or more wellbores.']

['FIG. 1 illustrates a diagram of a subterranean biological reactor system in accordance with embodiments of the present disclosure;; FIG. 2 illustrates a diagram of a subterranean biological reactor system showing a single wellbore isolated from the formation in accordance with embodiments of the present disclosure;; FIG.', '3 illustrates a diagram of a subterranean biological reactor system showing a single wellbore connected to the formation in accordance with embodiments of the present disclosure;; FIG.', '4 illustrates a diagram of a subterranean biological reactor system showing multiple wellbores connected to the formation in accordance with embodiments of the present disclosure; and; FIG.', '5 illustrates a diagram of a subterranean biological reactor system showing a single use pressurization or re-pressurization squeeze in accordance with embodiments of the present disclosure.']

US11920459

Estimating rate of penetration using pad displacement measurements

Dec 9, 2020

Ling Li, Riadh Boualleg, Denis Li, Prashant Saxena, Kjell Haugvaldstad

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion in International Patent Application No. PCT/US2020/064107, dated Mar. 15, 2021, 9 pages.

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2002103158; December 2002; WO; 2015123318; August 2015; WO

['A method for drilling a subterranean wellbore includes rotating a drill string in the subterranean wellbore to drill the wellbore.', 'The drill string includes a rotary steerable tool or a steerable drill bit including at least first and second axially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore.', 'Radial displacements of each of the first and second axially spaced pads are measured while drilling.', 'The measured radial displacements are processed to compute a rate of penetration of drilling.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE TO RELATED APPLICATIONS', 'This application is a 371 National Stage filing of International Patent Application No. PCT/US2020/064107, filed Dec. 9, 2020, which claims the benefit of, and priority to, U.S. Patent Application No. 62/952,107, filed Dec. 20, 2019.', 'Each of the foregoing is expressly incorporated herein by this reference in its entirety.', 'BACKGROUND\n \nLogging while drilling (LWD) and measurement while drilling (MWD) techniques for determining numerous formation and borehole characteristics are well known in oil well drilling and production applications.', 'In recent years there has been a keen interest in deploying sensors as close as possible to the drill bit (or even in the drill bit).', 'Those of skill in the art will appreciate that reducing the distance between the sensors and the bit reduces the time between drilling and measuring the formation and/or borehole properties.', 'This is believed to lead to a reduction in formation contamination (e.g., due to drilling fluid invasion or wellbore washout) and therefore to MWD and LWD measurements that are more likely to be representative of the pristine wellbore and formation properties.', 'In geosteering applications, it is further desirable to reduce the latency between cutting and logging so that steering decisions may be made in a timely fashion.', 'One difficulty in deploying sensors at or near the drill bit is that the lower BHA tends to be particularly crowded with essential drilling and steering tools, e.g., often including the drill bit, a steering tool, and a near-bit stabilizer.', 'At bit and/or near bit deployment of sensors is known, however, since LWD and MWD sensors generally require complimentary electronics, e.g., for digitizing, pre-processing, saving, and transmitting the sensor measurements, such deployments can compromise the integrity of the lower BHA.', 'SUMMARY', 'In some embodiments, a method for drilling a subterranean wellbore includes rotating a drill string in the subterranean wellbore to drill the wellbore.', 'The drill string includes a rotary steerable tool or a steerable drill bit including at least first and second axially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore.', 'Radial displacements of each of the first and second axially spaced pads are measured while rotating (drilling).', 'The measured radial displacements are processed to compute a rate of penetration of drilling.', 'In some embodiments, a method for drilling a wellbore through a subterranean formation includes rotating a drill string in the subterranean wellbore to drill.', 'The drill string includes a rotary steerable tool or a steerable drill bit including a plurality of pads configured to extend radially outward from a tool body and engage a wall of the wellbore.', 'Radial displacements of at least one of the pads are measured while rotating (e.g., drilling).', 'The measured radial displacements are processed to compute a formation index while drilling, wherein the formation index is indicative of a strength or hardness of the subterranean formation.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFor a more complete understanding of the disclosed subject matter, and advantages thereof, reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:\n \nFIG.', '1\n depicts an example drilling rig on which disclosed embodiments may be utilized.\n \nFIG.', '2\n depicts an example lower BHA portion of the drill string shown on \nFIG.', '1\n.', 'FIG.', '3\n depicts an example steerable drill bit on which disclosed embodiments may be utilized.\n \nFIGS.', '4\nA and \n4\nB\n (collectively \nFIG.', '4\n) depict cross sectional views of an example piston shown on \nFIG.', '2\n in extended (\n4\nA) and retracted (\n4\nB) positions.', 'FIG.', '5\n depicts a flow chart of a method for drilling a subterranean wellbore.\n \nFIG.', '6\nA\n depicts a cross sectional schematic of a steering tool or steerable drill bit deployed in a wellbore.\n \nFIG.', '6\nB\n depicts plots of raw displacement, center offset, and wellbore diameter as a function of measured depth obtained using the method embodiments shown on \nFIG. \n5\n.\n \nFIG.', '7\n depicts a flow chart of a method for drilling a subterranean wellbore.\n \nFIG.', '8\n depicts a plot of rate of penetration as a function of drilling time obtained using the method embodiments shown on \nFIG.', '7\n.', 'FIG.', '9\n depicts a flow chart of a method for drilling a subterranean wellbore.\n \nFIG.', '10\n depicts plots of raw displacement, rate of penetration, rotation rate, drilling fluid pressure, and formation index at as a function of drilling time.', 'DETAILED DESCRIPTION\n \nMethods for drilling a subterranean wellbore are disclosed.', 'In some embodiments, the methods include rotating a drill string in the subterranean wellbore to drill the wellbore.', 'The drill string may include a drill collar, a drill bit, and a rotary steerable tool.', 'The rotary steerable tool is configured to rotate with the drill string and includes a plurality of pads configured to extend and retract outward and inward from the tool body and thereby control the direction of drilling.', 'In some embodiments the drill string may include a steerable bit (or a rotary steerable system adjacent to the bit) including a plurality of pads configured to extend and retract and thereby control the direction of drilling.', 'Pad extension measurements made while drilling may be processed to compute a number of drilling, wellbore, and formation parameters.', 'For example, in some embodiments, the pad extension measurements may be processed to determine a wellbore caliper (e.g., including both the size and shape of the wellbore cross section).', 'In some embodiments, the piston extension measurements may be processed to determine a rate of penetration of drilling.', 'In some embodiments, the piston extension measurements may be processed to determine a formation index (e.g., a parameter related to formation hardness or strength).', 'Embodiments of the disclosure may provide various technical advantages and improvements over the prior art.', 'For example, in some embodiments, the disclosed embodiments provide an improved method and system for drilling a subterranean wellbore in which wellbore caliper, rate of penetration, and/or a formation index may be obtained from pad extension measurements made on extendable and retractable pads deployed very close to or even in the drilling bit.', 'For example, in certain embodiments, the pads may be deployed in a steerable drill bit or in a rotary steerable tool deployed immediately above the drill bit.\n \nFIG.', '1\n depicts a drilling rig \n10\n suitable for implementing various method embodiments disclosed herein.', 'A semisubmersible drilling platform \n12\n is positioned over an oil or gas formation disposed below the sea floor \n16\n.', 'A subsea conduit \n18\n extends from deck \n20\n of platform \n12\n to a wellhead installation \n22\n.', 'The platform may include a derrick and a hoisting apparatus for raising and lowering a drill string \n30\n, which, as shown, extends into wellbore \n40\n and includes a drill bit \n32\n and a rotary steerable tool \n50\n.', 'Drill string \n30\n may further include a downhole drilling motor, a downhole telemetry system, and one or more MWD or LWD tools including various sensors for sensing downhole characteristics of the wellbore and the surrounding formation.', 'The disclosed embodiments are not limited in these regards.', 'It will be understood by those of ordinary skill in the art that the deployment illustrated on \nFIG.', '1\n is merely an example.', 'It will be further understood that disclosed embodiments are not limited to use with a semisubmersible platform \n12\n as illustrated on \nFIG.', '1\n.', 'The disclosed embodiments are equally well suited for use with any kind of subterranean drilling operation, either offshore or onshore.\n \nFIG.', '2\n depicts the lower BHA portion of drill string \n30\n including drill bit \n32\n and rotary steerable tool \n50\n.', 'The rotary steerable tool may include substantially any suitable steering tool in which the rotary steerable tool collar rotates with the drill string and in which the steering is actuated by the radial extension and retraction of pads (or blades), for example, outward and inward from the tool collar.', 'For example, the PowerDrive rotary steerable systems (available from Schlumberger) fully rotate with the drill string (i.e., the outer tool collar rotates with the drill string).', 'The PowerDrive X5, X6, and Orbit rotary steerable systems make use of mud actuated pads that contact the wellbore wall and thereby steer the direction of drilling (e.g., by forcing the drill bit to cut in a desired direction).', 'The extension of the pads is rapidly and continually adjusted as the system rotates in the wellbore.', 'Certain of the disclosed embodiments may also be implemented on the PowerDrive Archer rotary steerable system, which makes use of a lower steering section joined at a swivel with an upper section.', 'The swivel is actively tilted via displacing internal pistons so as to change the angle of the lower section with respect to the upper section and maintain a desired drilling direction as the bottom hole assembly rotates in the wellbore.', 'With continued reference to \nFIG.', '2\n, the example rotary steerable tool embodiment \n50\n depicted includes a collar (tool body) \n55\n configured to rotate with the drill string (e.g., via connection to the drill string).', 'The tool includes a plurality of pads \n60\n, at least one of which is configured to extend outward from the collar \n55\n into contact with the wellbore wall and thereby actuate steering.', 'The pads \n60\n may be circumferentially spaced about the collar \n55\n and/or axially spaced along a length of the collar \n55\n.', 'In the depicted embodiment, the tool includes three circumferentially spaced pad pairs \n65\n (e.g., spaced at 120 degree intervals about the tool circumference).', 'Each pad pair \n65\n includes first and second axially spaced pads \n62\n and \n64\n deployed in/on a gauge surface \n58\n of the collar \n55\n.', 'The axially spaced pads \n62\n and \n64\n may be advantageously deployed in close axial proximity to one another.', 'The use of closely spaced pads may improve accuracy and enable certain parameters (such as rate of penetration) to be measured with minimal delay while drilling.', 'For example, pads \n62\n and \n64\n may advantageously have an axial spacing of less than about 60 cm (e.g., less than about 30 cm or less than about 15 cm).', 'The axial spacing of pads \n62\n and \n64\n may also be defined with respect to the diameter of the gauge surface \n58\n.', 'For example, the axial spacing may be less than about two times the diameter of the gauge surface (e.g., less than about the diameter of the gauge surface or less than about 0.7 times the diameter of the gauge surface).', 'Turning now to \nFIG.', '3\n, it will be understood that the disclosed embodiments are not limited to rotary drilling embodiments in which the drill bit \n32\n and rotary steerable tool \n50\n are distinct separable tools (or tool components).', 'FIG.', '3\n depicts a steerable drill bit \n70\n including a plurality of steering pads \n60\n deployed in the sidewall of the bit body \n72\n (e.g., on wellbore gauge surfaces).', 'Steerable bit \n70\n may be thought of as an integral drilling system in which the rotary steerable tool and the drill bit are integrated into a single tool (drill bit) body \n72\n.', 'Drill bit \n70\n may include substantially any suitable number of pads \n60\n, for example, three pairs of circumferentially spaced pad pairs in which each pad pair includes first and second axially spaced pads as described above with respect to \nFIG.', '2\n.', 'The disclosed embodiments are not limited in this regard.', 'With continued reference to \nFIGS.', '2\n and \n3\n, in some embodiments, the pads \n60\n may be deployed close to the cutting surface (cutting elements) of the drill bit.', 'For example, the downhole pad \n62\n (i.e., the pad closest to the cutting elements) may be deployed less than about 3 meters (e.g., less than about 1.5 meters or less than about 1 meter) above the cutting surface of the drill bit \n32\n, \n70\n.', 'In some embodiments, the downhole pad may be deployed less than about 60 cm (e.g., less than about 30 cm) above the cutting surface of the bit, e.g., when the pads are deployed in a steerable drill bit (such as drill bit \n70\n shown on \nFIG.', '3\n).', 'The deployment of the pads \n60\n may also be defined with respect to the diameter of the gauge surface \n58\n.', 'For example, the axial spacing between the downhole pad (e.g., pad \n62\n in \nFIG.', '2\n) and the cutting surface of the bit may be less than about 15 times the diameter of the gauge surface (e.g., less than about 10 times the diameter of the gauge surface or less than about 8 times the diameter of the gauge surface).', 'In embodiments in which the pads are deployed in a steerable drill bit (such as drill bit \n70\n shown on \nFIG. \n3\n), the axial spacing between the downhole pad and the cutting surface of the bit may advantageously be less than about 5 times the diameter of the gauge surface (e.g., less than about 3 times or less than about 2 times the diameter of the gauge surface).', 'FIGS.', '4\nA and \n4\nB\n (collectively \nFIG.', '4\n) depict cross sectional views of one of pads \n60\n shown in fully extended (\n4\nA) and fully retracted (\n4\nB) positions.', 'In the example embodiment shown, a piston \n82\n is deployed in a corresponding sleeve \n83\n in pad housing \n85\n.', 'As noted above, the piston \n82\n is configured to extend outward (as shown on \nFIG.', '4\nA\n) from the housing \n85\n, for example, via porting drilling fluid to cavity \n87\n (which is located radially behind the piston \n82\n).', 'In some embodiments, the piston may be biased inwards, for example, via the use of a conventional spring mechanism such that the piston \n82\n retracts when drilling fluid is diverted away from the cavity \n87\n (shown fully retracted in \nFIG.', '4\nB\n).', 'In some embodiments, the force of the piston against the borehole wall without fluid flowing to the pad is sufficient to cause the piston \n82\n to retract.', 'The pad assembly is equipped with a sensor \n90\n configured to measure the extension (radial displacement) of the piston \n82\n (e.g., the outward extension of the pad from a fully retracted position).', 'The sensor \n90\n may include a magnetic sensor configured to measure magnetic flux emanating from a magnet \n92\n deployed on the piston \n82\n.', 'For example, the magnetic sensor may include a Hall Effect sensor that measures the strength of the magnetic field emanating from magnet \n92\n and thereby computes the extension of the piston \n82\n.', 'Any suitable displacement measurement sensor may be used, e.g., any sensor that is capable of directly or indirectly measuring the varying extension of the piston may be used.', 'As noted above, at least one of the pads is instrumented such that that the radial displacement (extension) of the pad may be measured (quantified).', 'By radial displacement is meant the outward extension of the pad from the fully retracted position.', 'In some embodiments, first and second axially spaced pads are instrumented.', 'In other embodiments, each of the circumferentially spaced pads and/or axially spaced pads may be instrumented.', 'FIG.', '5\n depicts a flow chart of one example method embodiment \n100\n for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on \nFIGS.', '1\n and \n2\n or including a steerable drilling bit as depicted on \nFIG.', '3\n) is rotated in the wellbore at \n102\n to drill the well.', 'The bottom hole assembly includes a plurality of pads deployed close to the drill bit (e.g., as described above with respect to \nFIGS.', '2\n and \n3\n).', 'Pad extension measurements are made at one or more of the pads while drilling (i.e., while rotating the bottom hole assembly in the wellbore) at \n104\n and are processed at \n106\n to compute a wellbore calliper.', 'In some embodiments, the bottom hole assembly includes at least three circumferentially spaced pads (e.g., as depicted on \nFIGS.', '2\n and \n3\n).', 'Pad extension measurements are made at each of the pads in \n104\n.', 'Corresponding magnetometer measurements are made to determine a toolface angle of at least one of the pads.', 'The toolface angle of the other pads can be determined from the known circumferential spacing.', 'The piston extension measurements (e.g., the three extension measurements) may then be processed to compute the center of the wellbore, the center offset of the steering tool \n50\n or steerable bit \n70\n, the wellbore diameter, and the wellbore shape using geometry and trigonometry.\n \nFIG.', '6\nA\n depicts a cross sectional schematic of a steering tool \n50\n or steerable drill bit \n70\n deployed in wellbore \n40\n.', 'In the depicted schematic, the center of the tool C\nT \nis offset from the center of the wellbore C\nH \nby eccentering vector {right arrow over (e)}.', 'The circumferentially offset pads are extended into contact with the wellbore wall as depicted at corresponding piston displacements of d\n1\n, d\n2\n, and d\n3\n.', 'The tool radius r may be defined for example as the distance from C\nT \nto the pad when the pad is fully retracted.', 'In the tool reference frame (in which the center of the tool C\nT \nis located at (0,0)), the extended pads are located distances r+d\n1\n, r+d\n2\n, and r+d\n3 \nfrom C\nT\n.', 'It will be understood that the extended pads represent three distinct points along the circumference of the wellbore.', 'Assuming that the wellbore has a circular cross section, these points may be processed to determine the center of the wellbore C\nH \nin the tool coordinate system (as three points can be used to define a circle).', 'The center of the wellbore may then be processed in combination with the center of the tool C\nT \nto determine the eccentering vector {right arrow over (e)} (including the center offset distance and center offset direction).', 'The distance between any one of the extended pads and C\nH \ndefines the radius (and therefore the diameter) of the wellbore.', 'This process may be repeated as the tool rotates in the wellbore.', 'The extended pad positions trace out the cross sectional profile (shape) of the wellbore while rotating which enables the true cross-sectional shape of the wellbore to be reconstructed.', 'The shape of the wellbore may be compared with a circle to determine the degree of ellipticity of the wellbore or any other measure of circular deviation.', 'FIG.', '6\nB\n depicts plots of raw displacement for one of the pads at \n112\n, center offset at \n114\n, and the wellbore diameter at \n116\n as a function of drilling distance (measured depth along the wellbore).', 'In the depicted embodiment, the drilling tool was switched between neutral and active steering modes as indicated.', 'As described above, the pads are extended and retracted while the tool rotates in the wellbore.', 'During an active steering mode the pads extend and retract at predetermined toolface angles to cause the drill bit to drill in a predetermined direction.', 'For example, when building inclination, the pads are extended at the low side of the wellbore and retracted at the opposing high side of the wellbore such that the drill bit turns upward (builds inclination).', 'During a neutral mode, the toolface angle at which the pads extend and retract change with time as the tool rotates such that drilling tends to proceed straight ahead.', 'In the operation depicted on \nFIG.', '6\nB\n, the raw displacement of the pad(s) increases during steering with a maximum displacement of about 7 mm.', 'Note also that the displacement rapidly oscillates between about 0 and 7 mm as the tool rotates in the wellbore (as described above the pads are extended at a predetermined toolface angle and are retracted at an opposing toolface angle).', 'The center offset also increases while steering as expected (since the direction of drilling is steered by urging the center of the steering tool away from the center of the wellbore).', 'In this particular example, the drilling tool was offset from the center of the wellbore by about 0.1 to about 0.2 inches while steering and oscillated between 0 and 0.05 inch during the neutral phase.', 'The wellbore diameter was about constant at 8.5 inches during the operation (although the average diameter was observed to decrease slightly during active steering).', 'In some embodiments, the method \n100\n enables wellbore caliper measurements to be made while drilling and steering.', 'For example, the wellbore diameter, wellbore shape, and position of the steering tool in the wellbore can be measured in real time while drilling and steering.', 'Moreover, the measurements are made very close to the bit (e.g., within a few feet) and are therefore more representative of the performance of the drilling tool prior to washout and/or other factors that degrade wellbore quality.\n \nFIG.', '7\n depicts a flow chart of a method \n130\n for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on \nFIGS.', '1\n and \n2\n or including a steerable drilling bit as depicted on \nFIG.', '3\n) is rotated in the wellbore at \n132\n to drill the well.', 'The bottom hole assembly includes a plurality of axially spaced pads deployed close to the drill bit (e.g., as described above with respect to \nFIGS.', '2\n and \n3\n).', 'Pad extension measurements are made at first and second axially spaced pads while drilling (i.e., while rotating the bottom hole assembly in the wellbore) at \n134\n and are then processed at \n136\n to compute the rate of penetration of drilling in \n132\n.', 'The pad extension or displacement measurements may be processed to compute the rate of penetration at \n136\n, for example, by (i) determining the maximum displacements of each of the pads during each revolution of the tool, (ii) optionally low pass filtering (e.g., averaging) the maximum displacements over a predetermined number of revolutions to reduce noise, (iii) searching for maxima and minima in the maximum displacement measurements (or filtered maximum displacement measurements), (iv) matching the maxima and minima for the uphole and downhole pads to obtain a corresponding time delay Δt between the two sets of displacement measurements, and (v) computing the rate of penetration according to Equation 1: \n ROP=\nD/Δt\n\u2003\u2003Eq. 1 \n where ROP represents the rate of penetration, D represents the axial spacing (distance) between the first and second axially spaced pads on the steering tool (or steerable bit), and Δt represents the time delay obtained in (iv).', 'It will be understood that the time delay may also be obtained using cross correlation techniques by measuring similarities in the two pad displacement data sets.', 'FIG.', '8\n depicts a plot of rate of penetration versus drilling time and compares method \n130\n with surface measured ROP.', 'Conventional surface measured ROP is depicted at \n142\n, while the values measured using downhole method \n130\n are depicted at \n144\n.', 'As depicted, the ROP values obtained using downhole method \n130\n are in excellent agreement with the surface measured ROP (with most of the ROP measurements falling within a 25 percent error band).', 'In some embodiments, the method \n130\n enables the rate of penetration while drilling to be measured downhole while drilling.', 'As stated above, the ROP values are obtained by processing steering pad displacement measurements made very close to the drill bit.', 'Moreover, the displacement measurements are made on pads that are deployed very close to one another (i.e., that have a small axial spacing).', 'The resulting ROP measurements can therefore be made with a high temporal resolution since the time delay between the two sets of displacement measurements is short for serviceable drilling rates.', 'The use of closely spaced pads also tends to provide good correlation of the pad displacement measurements since the displacement measurements are made prior to washout or other wellbore degradation and therefore may improve the accuracy and reliability of the ROP measurements.\n \nFIG.', '9\n depicts a flow chart of a method \n160\n for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on \nFIGS.', '1\n and \n2\n or including a steerable drilling bit as depicted on \nFIG.', '3\n) is rotated in the wellbore at \n162\n to drill the well.', 'The bottom hole assembly includes a plurality of axially spaced pads deployed close to the drill bit (e.g., as described above with respect to \nFIGS.', '2\n and \n3\n).', 'Pad extension measurements are made at first and second axially spaced pads while drilling (i.e., while rotating the bottom hole assembly in the wellbore) at \n164\n and are then processed at \n166\n to compute a formation index that is indicative of a strength or hardness of the formation through which the wellbore penetrates.', 'The formation index may be estimated based on the force in the pad, which may be represented mathematically, for example, as follows:\n \n \n \n \n \n \n \n \nF\n \n=\n \n \nϵ\n \n·\n \nd\n \n·\n \n \n \nR\n \n\u2062\n \nO\n \n\u2062\n \nP\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \n \n \n \n \n \n \nEq\n \n.', '2\n \n \n \n \n \n \n \n where F represents the pad force', ', E represents the formation index, d represents the pad displacement, and RPM and ROP represents the rotation rate and rate of penetration while drilling in \n162\n.', 'Rearranging and solving for E yields the following: \n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \n \nP\n \n\u2062\n \nA\n \n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \n \nR\n \n\u2062\n \nO\n \n\u2062\n \nP\n \n \n \n \n \n \n \n \nEq\n \n.', '3\n \n \n \n \n \n \n \n where P represents drilling fluid pressure in the pad and A represents the contact area of the pad.', 'Since the contact area A is believed to remain substantially constant while drilling, the formation index may also be represented mathematically, for example, as follows: \n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \nP\n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \n \nR\n \n\u2062\n \nO\n \n\u2062\n \nP\n \n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n4\n \n \n \n \n \n \n \n With continued reference to \nFIG.', '9\n, the pad displacement measurements may be processed in combination with other downhole measurements to compute the formation index.', 'The pressure P may be obtained using conventional pressure measurements either in the through bore of the bottom hole assembly or in the piston cavity \n87\n or may be derived from any suitable measurements.', 'The rotation rate RPM may be measured using conventional techniques, for example, via accelerometers and/or magnetometers deployed in the bottom hole assembly.', 'The rate of penetration ROP may be obtained, for example, as described above with respect to \nFIG.', '7\n.', 'ROP may also be received via downlink from the surface or simply assumed based on known drilling parameters.', 'For example, a constant valued ROP may be assumed such that the formation index may alternatively be represented mathematically as follows: \n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \nP\n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \nk\n \n \n \n \n \n \n \nEq\n \n.', '5\n \n \n \n \n \n \n \n where k represents a constant valued rate of penetration or is simply unity to remove the influence of ROP.', 'As described above with respect to method \n130\n, the pad displacement d may be obtained by processing the pad displacement measurements made while rotating.', 'For example, by computing the maximum displacement the pad during each revolution of the tool and low pass filtering (e.g., averaging) the maximum displacements over a predetermined number of revolutions to reduce noise and obtain an average pad displacement d.\n \nFIG.', '10\n depicts plots of raw displacement for one of the pads at \n172\n, surface measured ROP at \n174\n, rotation rate RPM at \n176\n, pressure at \n178\n, and formation index at \n180\n as a function of time while drilling in \n162\n.', 'The plots extend over 18 minutes (0.3 hours) of drilling.', 'A change in formation index is readily observable at about 20.95 hours.', 'Note that the raw displacement of the pad increases from about 7 to about 10 mm at \n182\n while ROP, RPM, and pressure remain approximately constant indicating a transition from a harder to a softer formation.', 'The corresponding change in formation index is from about 100 (or more) to about 70 at \n183\n.', 'With further reference to \nFIGS.', '5\n-\n10\n, it will be understood that the parameters computed in methods \n100\n, \n130\n, and \n160\n (e.g., wellbore diameter, rate of penetration, and formation index) may be stored in downhole memory and/or transmitted to the surface, for example, via mud pulse telemetry, electromagnetic telemetry (or other telemetry techniques).', 'With still further reference to \nFIGS.', '5\n-\n10\n, the computed parameters may be further used in controlling the drilling process.', 'For example, the weight on bit and/or rotation rate of the drill string may be changed to increase or decrease the rate of penetration.', 'Likewise, the drilling fluid flow rate may be changed in response to wellbore caliper measurements and/or formation index.', 'For example, the drilling fluid flow rate/pressure may be reduced in response to caliper measurements showing increased wellbore diameter and/or a reduced formation index.', 'In some embodiments, the computed parameters may be used by components of the BHA to modify drilling parameters downhole.', 'For example, in some embodiments, a steering control scheme of the rotary steerable system may use the ROP measurements to compute depth to modify a drilling trajectory to more accurately follow a planned trajectory.', 'In some embodiments, a steering control scheme of the rotary steerable system may use the formation index to modify steering parameters after identifying a formation change to modify a drilling trajectory continue drilling according to the planned trajectory, e.g., by adjusting the steering ratio.', 'It will be appreciated that the methods described herein may be implemented individually or in combination during a drilling operation.', 'Moreover, the disclosed methods may be configured for implementation via one or more controllers deployed downhole (e.g., in a rotary steerable tool).', 'A suitable controller may include, for example, a programmable processor, such as a digital signal processor or other microprocessor or microcontroller and processor-readable or computer-readable program code embodying logic.', 'A suitable processor may be utilized, for example, to execute the method embodiments (or various steps in the method embodiments) described above with respect to \nFIGS.', '5\n-\n10\n.', 'A suitable controller may also optionally include other controllable components, such as sensors (e.g., a temperature sensor), data storage devices, power supplies, timers, and the like.', 'The controller may also be disposed to be in electronic communication with the accelerometers and magnetometers.', 'A suitable controller may also optionally communicate with other instruments in the drill string, such as, for example, telemetry systems that communicate with the surface.', 'A suitable controller may further optionally include volatile or non-volatile memory or a data storage device.', 'It will be understood that this disclosure may include numerous embodiments.', 'These embodiments include, but are not limited to, the following embodiments.', 'A first embodiment may be a method for drilling a subterranean wellbore.', 'The method may include: (a) rotating a drill string in the subterranean wellbore to drill, the drill string including a rotary steerable tool or a steerable drill bit including at least first and second axially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer a drilling direction; (b) measuring radial displacements of each of the first and second axially spaced pads while rotating in (a); and (c) computing a rate of penetration of drilling in (a) by processing the radial displacements measured in (b).', 'A second embodiment may include the first embodiment and further include: (d) changing a weight on bit or a rotation rate of the drill string in (a) in response to the rate of penetration of drilling computed in (c).', 'A third embodiment may include any one of the first two embodiments, where the rate of penetration is computed in (c) using the following mathematical equation: ROP=D/Δt; where ROP represents the rate of penetration, D represents an axial spacing between the first and second axially spaced pads, and Δt represents a time delay between when a feature is observed in the radial displacement measurements made with the first pad in (b) and when an analogous feature is observed in the radial displacement measurements made with the second pad in (b).', 'A fourth embodiment may include the third embodiment, where (c) includes: (i) determining maximum radial displacements for each of the first and second pads during each revolution while rotating in (a) by processing the radial displacement measurements made in (b); (ii) searching for maxima and minima in the maximum radial displacements; (iii) correlating the maxima and minima for the first and second pads to obtain the corresponding time delay Δt; and (iv) computing the rate of penetration by processing the time delay.', 'A fifth embodiment may include the fourth embodiment, where (i) further includes filtering the maximum radial displacements over a predetermined number of revolutions to reduce noise; and (ii) includes searching for maxima and minima in the filtered maximum radial displacements.', 'A sixth embodiment may include any one of the first through fifth embodiments where the first and second pads have an axial spacing of less than about 30 cm.', 'A seventh embodiment may include any one of the first through sixth embodiments where the first and second pads have an axial spacing of less than about twice a diameter of a gauge surface of the rotary steerable tool or the steerable drill bit.', 'An eighth embodiment may include any one of the first through seventh embodiments where the pads are deployed in a rotary steerable tool that is threadably connected with a drill bit and where at least one of the pads is deployed less than 1.5 meters above a lower cutting surface of the drill bit.', 'A ninth embodiment may include any one of the first through seventh embodiments where the pads are deployed in a steerable drill bit and where at least one of the pads is deployed less than 60 cm above a lower cutting surface of the drill bit.', 'A tenth embodiment may include any one of the first through ninth embodiments where the method further includes: (d) computing at least one of (i) an eccentering distance between a center of the tool body and a center of the wellbore or (ii) a diameter of the wellbore by processing the radial displacements measured in (b) of at least one of the first or second pads.', 'An eleventh embodiment may include the tenth embodiment where the rotary steerable tool or the steerable drill bit includes at least three circumferentially spaced pairs of first and second axially spaced pads; the radial displacements are measured in at least one pad in each of the three pairs of first and second axially spaced pads in (b); and the radial displacements measured in (b) in the at least one pad in each of the three pairs of first and second axially spaced pads are processed in (d) to compute the eccentering distance and the diameter of the wellbore.', 'A twelfth embodiment may be a method for drilling a subterranean wellbore.', 'The method may include: (a) rotating a drill string in the subterranean wellbore to drill, the drill string including a rotary steerable tool or a steerable drill bit including a plurality circumferentially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer a drilling direction; (b) measuring radial displacements of at least one of the plurality of circumferentially spaced pads while rotating in (a); (c) computing at least one of (i) an eccentering distance between a center of the tool body and a center of the wellbore or (ii) a diameter of the wellbore by processing the radial displacements measured in (b).', 'A thirteenth embodiment may include the twelfth embodiment and may further include: (d) changing a weight on bit or a rotation rate of the drill string in (a) in response to the eccentering distance or the diameter of the wellbore computed in (c).', 'A fourteenth embodiment may include the twelfth or thirteenth embodiment where: (b) includes measuring radial displacements of each of the plurality of circumferentially spaced pads while rotating in (a); and (c) includes computing the eccentering distance and the diameter of the wellbore by processing the radial displacements measured at each of the plurality of circumferentially spaced pads.', 'A fifteenth embodiment may include the fourteenth embodiment, where (c) further includes: (c1) computing a center location of the wellbore by processing the radial displacements measured at each of the plurality of circumferentially spaced pads; (c2) computing the eccentering distance by processing the center location of the wellbore and a center location of the rotary steerable tool or the steerable drill bit; or (c3) computing the diameter of the wellbore by processing the radial displacements measured at at least one of the plurality of circumferentially spaced pads.', 'A sixteenth embodiment may include the fifteenth embodiment, where (c) further includes: (c4) repeating (c1) while rotating in (a) and reconstructing a cross-sectional shape of the wellbore by processing the radial displacements measured at each of the plurality of circumferentially spaced pads.', 'A seventeenth embodiment may include any one of the twelfth through sixteenth embodiments, where the pads are deployed in a rotary steerable tool that is threadably connected with a drill bit and where at least one of the pads is deployed less than 1.5 meters above a lower cutting surface of the drill bit.', 'An eighteenth embodiment may include any one of the twelfth through seventeenth embodiments, where the pads are deployed in a steerable drill bit and where at least one of the pads is deployed less than 60 cm above a lower cutting surface of the drill bit.', 'A nineteenth embodiment may be a system for drilling a subterranean wellbore.', 'The system may include: a rotary steerable tool or a steerable drill bit including at least first and second axially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer a drilling direction; and a downhole controller deployed in the rotary steerable tool or a steerable drill bit, the controller including instructions to (i) measure radial displacements of each of the first and second axially spaced pads while the system rotates in the wellbore and (ii) process the radial displacements measured in (i) to compute a rate of penetration of drilling.', 'A twentieth embodiment may include the nineteenth embodiment, where the controller is configured to compute the rate of penetration via (iia) determining maximum radial displacements for each of the first and second pads during each revolution while rotating by processing the measured radial displacements, (iib) filtering the maximum radial displacements over a predetermined number of revolutions to reduce noise; (iic) searching for maxima and minima in the filtered maximum radial displacements, (iid) correlating the maxima and minima for the first and second pads to obtain a corresponding time delay Δt; and (iie) computing the rate of penetration ROP, where ROP=D/Δt, by processing the time delay and an axial distance D between the first and second pads.', 'A twenty-first embodiment may be a method for drilling a wellbore through a subterranean formation.', 'The method may include: (a) rotating a drill string in the subterranean wellbore to drill, the drill string including a rotary steerable tool or a steerable drill bit including a plurality of pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer a drilling direction; (b) measuring radial displacements of at least one of the pads while rotating in (a); and (c) computing a formation index while drilling in (a), where the formation index is indicative of a strength or hardness of the formation, by processing the radial displacements measured in (b).', 'A twenty-second embodiment may include the twenty-first embodiment and may further include: (d) changing a weight on bit or a rotation rate of the drill string in (a) in response to the formation index computed in (c).', 'A twenty-third embodiment may include any one of the twenty-first through the twenty-second embodiments, where the formation index is inversely proportional to the radial displacements measured in (b).', 'A twenty-fourth embodiment may include any one of the twenty-first through the twenty-third embodiments, where (b) further includes measuring a drilling fluid pressure in the pad while rotating in (a).', 'A twenty-fifth embodiment may include any one of the twenty-first through the twenty-fourth embodiments, where (b) further includes measuring a drill string rotation rate while rotating in (a).', 'A twenty-sixth embodiment may include any one of the twenty-first through the twenty-fifth embodiments, where (b) further includes measuring a rate of penetration while drilling while rotating in (a).', 'A twenty-seventh embodiment may include any one of the twenty-first through the twenty-sixth embodiments, where the formation index is computed using one of the following mathematical equations 6-8:\n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \n \nP\n \n\u2062\n \nA\n \n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \n \nR\n \n\u2062\n \nO\n \n\u2062\n \nP\n \n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n6\n \n \n \n \n \n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \nP\n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \n \nR\n \n\u2062\n \nO\n \n\u2062\n \nP\n \n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n7\n \n \n \n \n \n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \nP\n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \nk\n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n8\n \n \n \n \n \n \n \n where ϵ represents the formation index, d represents the pad displacement, P represents drilling fluid pressure in the pad, A represents a contact area of the pad, RPM and ROP represents a rotation rate and a rate of penetration while drilling in (a), and α represents a constant valued rate of penetration.', 'A twenty-eighth embodiment may include any one of the twenty-first through the twenty-seventh embodiments, where (c) includes: (i) determining maximum radial displacements for the at least one pad during each revolution while rotating in (a) by processing the radial displacement measurements made in (b); (ii) filtering the maximum radial displacements over a predetermined number of revolutions to reduce noise; and (iii) computing the formation index by processing the filtered maximum radial displacements.', 'A twenty-ninth embodiment may include any one of the twenty-first through the twenty-eighth embodiments, where the pads are deployed in a rotary steerable tool that is threadably connected with a drill bit and where at least one of the pads is deployed less than 1.5 meters above a lower cutting surface of the drill bit.', 'A thirtieth embodiment may include any one of the twenty-first through the twenty-eighth embodiments, where the pads are deployed in a steerable drill bit and where at least one of the pads is deployed less than 60 cm above a lower cutting surface of the drill bit.', 'A thirty-first embodiment may include any one of the twenty-first through the thirtieth embodiments, where: the rotary steerable tool or the steerable drill bit includes at least first and second axially spaced pads; (b) includes measuring the radial displacement of each of the first and second axially spaced pads; and (c) includes computing a rate of penetration of drilling by processing the radial displacements measured in (b) and further computing the formation index by processing the radial displacements and the rate of penetration of drilling.', 'A thirty-second embodiment may include the thirty-first embodiment, where (b) further includes measuring the drilling fluid pressure in the pad, and the rotation rate of the drill string while rotating in (a); and (c) further includes computing the formation index by processing the radial displacements, the drilling fluid pressure, and the rotation rate measured in (b) and the computed rate of penetration of drilling.', 'A thirty-third embodiment may include any one of the thirty-first through the thirty-second embodiments, where (c) includes: (i) determining maximum radial displacements for each of the first and second pads during each revolution while rotating in (a) by processing the radial displacement measurements made in (b); (ii) searching for maxima and minima in the maximum radial displacements; (iii) correlating the maxima and minima for the first and second pads to obtain the corresponding time delay Δt; (iv) computing the rate of penetration by processing the time delay; and (v) processing the computed rate of penetration and the maximum displacements for at least one of the pads to compute the formation index.', 'A thirty-fourth embodiment may include any one of the thirty-first through the thirty-third embodiments, where the first and second pads have an axial spacing of less than about 30 cm.', 'A thirty-fifth embodiment may include any one of the thirty-first through the thirty-fourth embodiments, where the first and second pads have an axial spacing of less than about twice a diameter of a gauge surface of the rotary steerable tool or the steerable drill bit.', 'A thirty-sixth embodiment may include any one of the thirty-first through the thirty-fifth embodiments, and may further include: (d) computing at least one of (i) an eccentering distance between a center of the tool body and a center of the wellbore or (ii) a diameter of the wellbore by processing the radial displacements measured in (b) of at least one of the first or second pads.', 'A thirty-seventh embodiment may include any one of the twenty-first through the thirty-fifth embodiments, and may further include: (d) computing at least one of (i) an eccentering distance between a center of the tool body and a center of the wellbore or (ii) a diameter of the wellbore by processing the radial displacements measured in (b) of at least one of the first and second pads.', 'A thirty-eighth embodiment may include a system for drilling a wellbore through a subterranean formation.', 'The system may include: a rotary steerable tool or a steerable drill bit including a plurality of axially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer a drilling direction; and a downhole controller deployed in the rotary steerable tool or a steerable drill bit, the controller including instructions to (i) measure radial displacements of at least one of the plurality of pads while the system rotates in the wellbore and (ii) process the radial displacements measured in (i) to compute a formation index, where the formation index is indicative of a strength or hardness of the formation.', 'A thirty-ninth embodiment may include the thirty-eighth embodiment, where the controller is configured to compute the formation index (iia) determining maximum radial displacements for each of the first and second pads during each revolution while rotating by processing the radial displacement measurements made in (b), (iib) filtering the maximum radial displacements over a predetermined number of revolutions to reduce noise, and (iic) computing the formation index by processing the filtered maximum radial displacements.', 'A fortieth embodiment may include the thirty-eighth or thirty-ninth embodiment, where the formation index is computed using one of the following mathematical equations 9-11:\n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \n \nP\n \n\u2062\n \nA\n \n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \n \nR\n \n\u2062\n \nO\n \n\u2062\n \nP\n \n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n9\n \n \n \n \n \n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \nP\n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \n \nR\n \n\u2062\n \nO\n \n\u2062\n \nP\n \n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n10\n \n \n \n \n \n \n \n \n \n \n \n \n \nϵ\n \n=\n \n \n \nP\n \nd\n \n \n·\n \n \n \nR\n \n\u2062\n \nP\n \n\u2062\n \nM\n \n \nk\n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n11\n \n \n \n \n \n \n \n where ϵ represents the formation index, d represents the radial displacement, P represents drilling fluid pressure in the pad, A represents a contact area of the pad, RPM and ROP represents a rotation rate and a rate of penetration while drilling, and k represents a constant valued rate of penetration.', 'Although at- or near-bit pad displacement measurements and certain advantages thereof have been described in detail, it should be understood that various changes, substitutions and alterations may be made herein without departing from the spirit and scope of the disclosure.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that is within standard manufacturing or process tolerances, or which still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.']

['1.', 'A method for drilling a subterranean wellbore, the method comprising:\n(a) rotating a drill string in the subterranean wellbore to drill, the drill string including a rotary steerable tool or a steerable drill bit including at least first and second axially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer the drill string a drilling direction;\n(b) measuring radial displacements of each of the first and second axially spaced pads while rotating in (a); and\n(c) computing a rate of penetration of drilling in (a) by processing the radial displacements measured in (b).', '2.', 'The method of claim 1, further comprising:\n(d) changing a weight on bit or a rotation rate of the drill string in (a) in response to the rate of penetration of drilling computed in (c).', '3.', 'The method of claim 1, wherein the rate of penetration is computed in (c) using the following mathematical equation:\nROP=D/Δt\nwhere ROP represents the rate of penetration, D represents an axial spacing between the first and second axially spaced pads, and Δt represents a time delay between when a feature is observed in the radial displacement measurements made with the first pad in (b) and when an analogous feature is observed in the radial displacement measurements made with the second pad in (b).', '4.', 'The method of claim 3, wherein (c) comprises:\n(i) determining maximum radial displacements for each of the first and second pads during each revolution while rotating in (a) by using the radial displacement measurements made in (b);\n(ii) searching for maxima and minima in the maximum radial displacements;\n(iii) obtaining the corresponding time delay Δt by correlating the maxima and minima for the first and second pads; and\n(iv) computing the rate of penetration using the time delay.', '5.', 'The method of claim 4, wherein:\ndetermining maximum radial displacements in (i) further comprises filtering the maximum radial displacements over a predetermined number of revolutions to reduce noise; and\nsearching for maxima and minima in (ii) comprises searching for maxima and minima in the filtered maximum radial displacements.', '6.', 'The method of claim 1, wherein the first and second pads have an axial spacing of less than about 30 cm.\n\n\n\n\n\n\n7.', 'The method of claim 1, wherein the first and second pads have an axial spacing of less than about twice a diameter of a gauge surface of the rotary steerable tool or the steerable drill bit.', '8.', 'The method of claim 1, wherein the pads are deployed in a rotary steerable tool that is threadably connected with a drill bit and wherein at least one of the pads is deployed less than 1.5 meters above a lower cutting surface of the drill bit.', '9.', 'The method of claim 1, wherein the pads are deployed in a steerable drill bit and wherein at least one of the pads is deployed less than 60 cm above a lower cutting surface of the drill bit.', '10.', 'The method of claim 1, further comprising:\n(d) computing at least one of (i) an eccentering distance between a center of the tool body and a center of the wellbore or (ii) a diameter of the wellbore by processing the radial displacements measured in (b) of at least one of the first and second pads.', '11.', 'The method of claim 10, wherein:\nthe rotary steerable tool or the steerable drill bit includes at least three circumferentially spaced pairs of first and second axially spaced pads;\nthe radial displacements are measured in at least one pad in each of the three pairs of first and second axially spaced pads in (b); and\ncomputing the eccentering distance or the diameter of the wellbore in (d) includes processing the radial displacements measured in (b) in the at least one pad in each of the three pairs of first and second axially spaced pads.', '12.', 'A method for drilling a subterranean wellbore, the method comprising:\n(a) rotating a drill string in the subterranean wellbore to drill, the drill string including a rotary steerable tool or a steerable drill bit including a plurality circumferentially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer the drill string in a drilling direction;\n(b) measuring radial displacements of at least one of the plurality of circumferentially spaced pads while rotating in (a); and\n(c) computing at least one of (i) an eccentering distance between a center of the tool body and a center of the wellbore or (ii) a diameter of the wellbore by processing the radial displacements measured in (b).', '13.', 'The method of claim 12, further comprising:\n(d) changing a weight on bit or a rotation rate of the drill string in (a) in response to the eccentering distance or the diameter of the wellbore computed in (c).', '14.', 'The method of claim 12, wherein:\nmeasuring radial displacements in (b) includes measuring radial displacements of each of the plurality of circumferentially spaced pads while rotating in (a); and\ncomputing in (c) includes computing the eccentering distance and the diameter of the wellbore by processing the radial displacements measured at each of the plurality of circumferentially spaced pads.', '15.', 'The method of claim 14, wherein computing in (c) further comprises:\n(c1) compute a center location of the wellbore by processing the radial displacements measured at each of the plurality of circumferentially spaced pads;\n(c2) computing the eccentering distance by processing the center location of the wellbore and a center location of the rotary steerable tool or the steerable drill bit; and\n(c3) computing the diameter of the wellbore by processing the radial displacements measured at at least one of the plurality of circumferentially spaced pads.', '16.', 'The method of claim 15, wherein (c) further comprises:\n(c4) repeating (c1) while rotating in (a) and reconstructing a cross-sectional shape of the wellbore by processing the radial displacements measured at each of the plurality of circumferentially spaced pads.', '17.', 'The method of claim 12, wherein the pads are deployed in a rotary steerable tool that is threadably connected with a drill bit and wherein at least one of the pads is deployed less than 1.5 meters above a lower cutting surface of the drill bit.', '18.', 'The method of claim 12, wherein the pads are deployed in a steerable drill bit and wherein at least one of the pads is deployed less than 60 cm above a lower cutting surface of the drill bit.', '19.', 'A system for drilling a subterranean wellbore, the system comprising:\na rotary steerable tool or a steerable drill bit including at least first and second axially spaced pads configured to extend radially outward from a tool body and engage a wall of the wellbore, the engagement operative to steer a drilling direction; and\na downhole controller deployed in the rotary steerable tool or a steerable drill bit, the controller including instructions to (i) measure radial displacements of each of the first and second axially spaced pads while the system rotates in the wellbore and (ii) compute a rate of penetration of drilling by processing the radial displacements measured in (i).', '20.', 'The system of claim 19, wherein the controller is configured to compute the rate of penetration via: (iia) processing the measured radial displacements to determine maximum radial displacements for each of the first and second pads during each revolution while rotating; (iib) filtering the maximum radial displacements over a predetermined number of revolutions to reduce noise; (iic) searching for maxima and minima in the filtered maximum radial displacements; (iid) correlating the maxima and minima for the first and second pads to obtain a corresponding time delay (Δt); and (iie) computing the rate of penetration (ROP) by processing the time delay and an axial distance (D) between the first and second pads, where ROP=D/Δt.']

['FIG.', '1 depicts an example drilling rig on which disclosed embodiments may be utilized.; FIG.', '2 depicts an example lower BHA portion of the drill string shown on FIG.', '1.; FIG.', '3 depicts an example steerable drill bit on which disclosed embodiments may be utilized.; FIGS.', '4A and 4B (collectively FIG.', '4) depict cross sectional views of an example piston shown on FIG.', '2 in extended (4A) and retracted (4B) positions.;', 'FIG. 5 depicts a flow chart of a method for drilling a subterranean wellbore.; FIG.', '6A depicts a cross sectional schematic of a steering tool or steerable drill bit deployed in a wellbore.; FIG.', '6B depicts plots of raw displacement, center offset, and wellbore diameter as a function of measured depth obtained using the method embodiments shown on FIG.', '5.; FIG. 7 depicts a flow chart of a method for drilling a subterranean wellbore.; FIG.', '8 depicts a plot of rate of penetration as a function of drilling time obtained using the method embodiments shown on FIG.', '7.; FIG.', '9 depicts a flow chart of a method for drilling a subterranean wellbore.; FIG.', '10 depicts plots of raw displacement, rate of penetration, rotation rate, drilling fluid pressure, and formation index at as a function of drilling time.', '; FIG.', '1 depicts a drilling rig 10 suitable for implementing various method embodiments disclosed herein.', 'A semisubmersible drilling platform 12 is positioned over an oil or gas formation disposed below the sea floor 16.', 'A subsea conduit 18 extends from deck 20 of platform 12 to a wellhead installation 22.', 'The platform may include a derrick and a hoisting apparatus for raising and lowering a drill string 30, which, as shown, extends into wellbore 40 and includes a drill bit 32 and a rotary steerable tool 50.', 'Drill string 30 may further include a downhole drilling motor, a downhole telemetry system, and one or more MWD or LWD tools including various sensors for sensing downhole characteristics of the wellbore and the surrounding formation.', 'The disclosed embodiments are not limited in these regards.; FIG.', '2 depicts the lower BHA portion of drill string 30 including drill bit 32 and rotary steerable tool 50.', 'The rotary steerable tool may include substantially any suitable steering tool in which the rotary steerable tool collar rotates with the drill string and in which the steering is actuated by the radial extension and retraction of pads (or blades), for example, outward and inward from the tool collar.', 'For example, the PowerDrive rotary steerable systems (available from Schlumberger) fully rotate with the drill string (i.e., the outer tool collar rotates with the drill string).', 'The PowerDrive X5, X6, and Orbit rotary steerable systems make use of mud actuated pads that contact the wellbore wall and thereby steer the direction of drilling (e.g., by forcing the drill bit to cut in a desired direction).', 'The extension of the pads is rapidly and continually adjusted as the system rotates in the wellbore.', 'Certain of the disclosed embodiments may also be implemented on the PowerDrive Archer rotary steerable system, which makes use of a lower steering section joined at a swivel with an upper section.', 'The swivel is actively tilted via displacing internal pistons so as to change the angle of the lower section with respect to the upper section and maintain a desired drilling direction as the bottom hole assembly rotates in the wellbore.; FIGS.', '4A and 4B (collectively FIG.', '4) depict cross sectional views of one of pads 60 shown in fully extended (4A) and fully retracted (4B) positions.', 'In the example embodiment shown, a piston 82 is deployed in a corresponding sleeve 83 in pad housing 85.', 'As noted above, the piston 82 is configured to extend outward (as shown on FIG.', '4A) from the housing 85, for example, via porting drilling fluid to cavity 87 (which is located radially behind the piston 82).', 'In some embodiments, the piston may be biased inwards, for example, via the use of a conventional spring mechanism such that the piston 82 retracts when drilling fluid is diverted away from the cavity 87 (shown fully retracted in FIG.', '4B).', 'In some embodiments, the force of the piston against the borehole wall without fluid flowing to the pad is sufficient to cause the piston 82 to retract.', '; FIG.', '5 depicts a flow chart of one example method embodiment 100 for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on FIGS.', '1 and 2 or including a steerable drilling bit as depicted on FIG.', '3) is rotated in the wellbore at 102 to drill the well.', 'The bottom hole assembly includes a plurality of pads deployed close to the drill bit (e.g., as described above with respect to FIGS.', '2 and 3).', 'Pad extension measurements are made at one or more of the pads while drilling (i.e., while rotating the bottom hole assembly in the wellbore) at 104 and are processed at 106 to compute a wellbore calliper.; FIG.', '6A depicts a cross sectional schematic of a steering tool 50 or steerable drill bit 70 deployed in wellbore 40.', 'In the depicted schematic, the center of the tool CT is offset from the center of the wellbore CH by eccentering vector {right arrow over (e)}.', 'The circumferentially offset pads are extended into contact with the wellbore wall as depicted at corresponding piston displacements of d1, d2, and d3.', 'The tool radius r may be defined for example as the distance from CT to the pad when the pad is fully retracted.', 'In the tool reference frame (in which the center of the tool CT is located at (0,0)), the extended pads are located distances r+d1, r+d2, and r+d3 from CT.', 'It will be understood that the extended pads represent three distinct points along the circumference of the wellbore.', 'Assuming that the wellbore has a circular cross section, these points may be processed to determine the center of the wellbore CH in the tool coordinate system (as three points can be used to define a circle).', 'The center of the wellbore may then be processed in combination with the center of the tool CT to determine the eccentering vector {right arrow over (e)} (including the center offset distance and center offset direction).', 'The distance between any one of the extended pads and CH defines the radius (and therefore the diameter) of the wellbore.', 'This process may be repeated as the tool rotates in the wellbore.', 'The extended pad positions trace out the cross sectional profile (shape) of the wellbore while rotating which enables the true cross-sectional shape of the wellbore to be reconstructed.', 'The shape of the wellbore may be compared with a circle to determine the degree of ellipticity of the wellbore or any other measure of circular deviation.', '; FIG.', '6B depicts plots of raw displacement for one of the pads at 112, center offset at 114, and the wellbore diameter at 116 as a function of drilling distance (measured depth along the wellbore).', 'In the depicted embodiment, the drilling tool was switched between neutral and active steering modes as indicated.', 'As described above, the pads are extended and retracted while the tool rotates in the wellbore.', 'During an active steering mode the pads extend and retract at predetermined toolface angles to cause the drill bit to drill in a predetermined direction.', 'For example, when building inclination, the pads are extended at the low side of the wellbore and retracted at the opposing high side of the wellbore such that the drill bit turns upward (builds inclination).', 'During a neutral mode, the toolface angle at which the pads extend and retract change with time as the tool rotates such that drilling tends to proceed straight ahead.', '; FIG.', '7 depicts a flow chart of a method 130 for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on FIGS.', '1 and 2 or including a steerable drilling bit as depicted on FIG.', '3) is rotated in the wellbore at 132 to drill the well.', 'The bottom hole assembly includes a plurality of axially spaced pads deployed close to the drill bit (e.g., as described above with respect to FIGS.', '2 and 3).', 'Pad extension measurements are made at first and second axially spaced pads while drilling (i.e., while rotating the bottom hole assembly in the wellbore) at 134 and are then processed at 136 to compute the rate of penetration of drilling in 132.; FIG.', '8 depicts a plot of rate of penetration versus drilling time and compares method 130 with surface measured ROP.', 'Conventional surface measured ROP is depicted at 142, while the values measured using downhole method 130 are depicted at 144.', 'As depicted, the ROP values obtained using downhole method 130 are in excellent agreement with the surface measured ROP (with most of the ROP measurements falling within a 25 percent error band).', '; FIG.', '9 depicts a flow chart of a method 160 for drilling a subterranean wellbore.', 'A bottom hole assembly (e.g., as depicted on FIGS.', '1 and 2 or including a steerable drilling bit as depicted on FIG.', '3) is rotated in the wellbore at 162 to drill the well.', 'The bottom hole assembly includes a plurality of axially spaced pads deployed close to the drill bit (e.g., as described above with respect to FIGS.', '2 and 3).', 'Pad extension measurements are made at first and second axially spaced pads while drilling (i.e., while rotating the bottom hole assembly in the wellbore) at 164 and are then processed at 166 to compute a formation index that is indicative of a strength or hardness of the formation through which the wellbore penetrates.; FIG.', '10 depicts plots of raw displacement for one of the pads at 172, surface measured ROP at 174, rotation rate RPM at 176, pressure at 178, and formation index at 180 as a function of time while drilling in 162.', 'The plots extend over 18 minutes (0.3 hours) of drilling.', 'A change in formation index is readily observable at about 20.95 hours.', 'Note that the raw displacement of the pad increases from about 7 to about 10 mm at 182 while ROP, RPM, and pressure remain approximately constant indicating a transition from a harder to a softer formation.', 'The corresponding change in formation index is from about 100 (or more) to about 70 at 183.']

US11694095

Integrating geoscience data to predict formation properties

May 7, 2018

Ridvan Akkurt, David Psaila

Schlumberger Technology Corporation

International Preliminary Report on Patentability for the counterpart International patent application PCT/US2018/031295 dated Nov. 21, 2019.; Breiman, “Random forests,” Machine Learning, 2001, vol. 45, Issue 1, pp. 5-32.; Duda, et al., “Pattern Classification,” 2001, 2nd Edition, John Wiley & Sons, Inc.; Gareth, et al., “An Introduction to Statistical Learning,” Springer, Texts in Statistics, 2016.; Hastie, et al., “The Elements o fStatistical Learning: Data Mining, Inference, and Prediction,” 2nd Edition, Springer Series in Statistics, 2016 (Front cover—p. 190).; Hastie, et al., “The Elements o fStatistical Learning: Data Mining, Inference, and Prediction,” 2nd Edition, Springer Series in Statistics, 2016 (pp. 191-484).; Hastie, et al., “The Elements o fStatistical Learning: Data Mining, Inference, and Prediction,” 2nd Edition, Springer Series in Statistics, 2016 (pp. 485-745).; Kullback, et al., “On Information and Sufficiency,” Annals of Mathematical Statistics, 1951, 22, pp. 79-86.; Meinshausen, “Quantile Regression Forests,” Journal of Machine Learning Research, 2006, 7, pp. 983-999.; Tax, et al., “Support vector domain description,” Pattern Recognition Letters, 1999, 20 pp. 1191-1199.; Vapnik, “The Nature of Statistical Learning Theory,” Springer, New York, 1995.; International Search Report and Written Opinion for the equivalent International patent application PCT/US2018/031295 dated Aug. 31, 2018.; Extended Search Report and Written Opinion for the counterpart European Patent Application No. 18797875.4 dated Jan. 20, 2021, 7 pages.; Communication Pursuant to Article 94(3) issued in the counterpart European Patent Application No. 18797875.4 dated May 12, 2023, 6 pages.

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2009129083; October 2009; WO; 2011075280; June 2011; WO

['A method includes receiving well log data for a plurality of wells.', 'A flag is generated based at least partially on the well log data.', 'The wells are sorted into groups based at least partially on the well log data, the flag, or both.', 'A model is built for each of the wells based at least partially on the well log data, the flag, and the groups.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis application claims priority to U.S. Provisional Patent Application No. 62/503,249, filed on May 8, 2017, the entirety of which is hereby incorporated by reference herein.\n \nBACKGROUND\n \nMud logs and drilling data are used to determine total water saturation (Sw), total porosity (PHIT), and permeability in a subterranean formation.', 'More particularly, a manual process is used that utilizes crossplots of data computed from drilling data and mud gas logs.', 'Lines or segments of lines are then selected, which define “baselines” for further computation of either interim or final formation properties.', 'The process is manual, subjective, non-repeatable, and deploys analytical formulas to obtain Sw and PHIT.', 'SUMMARY\n \nA method for determining a formation property includes receiving well log data for a plurality of wells.', 'A flag is generated based at least partially on the well log data.', 'The wells are sorted into groups based at least partially on the well log data, the flag, or both.', 'A model is built for each of the wells based at least partially on the well log data, the flag, and the groups.', 'A computing system includes a processor and a memory system.', 'The memory system includes a non-transitory computer-readable medium storing instructions that, when executed by the processor, cause the computing system to perform operations.', 'The operations include receiving well log data for a plurality of wells.', 'The operations also include generating a flag based at least partially on the well log data.', 'The operations also include sorting the wells into groups based at least partially on the well log data, the flag, or both.', 'The operations also include building a model for each of the wells based at least partially on the well log data, the flag, and the groups.', 'The operations also include predicting a formation property based at least partially upon the well log data and the models.', 'The operations also include determining an uncertainty of the formation property using one or more prediction intervals from a quantile regression forest algorithm.', 'The operations also include identifying a physical action to be performed in response to the formation property, the uncertainty of the formation property, or both.', 'A non-transitory computer-readable medium is also disclosed.', 'The medium stores instructions that, when executed by a processor of a computing system, cause the computing system to perform operations.', 'The operations include receiving well log data for a plurality of wells.', 'The well log data is selected from the group consisting of gamma ray measurements, density measurements, neutron logs, and core data.', 'The operations also include generating a flag based at least partially on the well log data.', 'The flag includes an outlier flag that is generated using a one-class unsupervised support vector machine model.', 'The one-class unsupervised support vector machine model is generated on a well-by-well basis, a global basis, or both using an outlier fraction that is user-supplied or automated.', 'The operations also include sorting the wells into groups based at least partially on the well log data, the flag, or both.', 'The operations also include building a model for each of the wells based at least partially on the well log data, the flag, and the groups.', 'The operations also include adding the models to a library after the models are built.', 'The operations also include updating the models in the library when additional ground truth becomes available.', 'The operations also include predicting a formation property based at least partially upon the well log data and the models.', 'The formation property is selected from the group consisting of water saturation, porosity, permeability, and compressional slowness.', 'The operations also include determining an uncertainty of the formation property using one or more prediction intervals from a quantile regression forest algorithm.', 'The operations also include identifying a physical action to be performed in response to the formation property, the uncertainty of the formation property, or both.', 'The physical action is selected from the group consisting of selecting an additional well to be interpreted manually, changing a trajectory of one of the wells, and varying a property of a fluid being pumped into one of the wells.', 'It will be appreciated that this summary is intended merely to introduce some aspects of the present methods, systems, and media, which are more fully described and/or claimed below.', 'Accordingly, this summary is not intended to be limiting.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings.', 'In the figures:\n \nFIG.', '1\n illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.\n \nFIG.', '2\n illustrates a schematic view of an interpretation workflow, according to an embodiment.\n \nFIG.', '3\nA\n illustrates a schematic view of model building and prediction, according to an embodiment.\n \nFIG.', '3\nB\n illustrates graphs showing water saturation (Sw) prediction, according to an embodiment.\n \nFIG.', '3\nC\n illustrates graphs showing total porosity (PHIT) prediction, according to an embodiment.\n \nFIG.', '4\n illustrates a graph showing the prediction of compressional acoustic slowness, from a set of MGL+DD+GR, according to an embodiment.\n \nFIG.', '5\n illustrates graphs showing the impact of inaccurate interpretation in establishing the ground truth, according to an embodiment.\n \nFIG.', '6\nA\n illustrates graphs showing the assessment of uncertainty of a first well with higher uncertainty, according to an embodiment.\n \nFIG.', '6\nB\n illustrates graphs showing the assessment of uncertainty of a second well with lower uncertainty, according to an embodiment.\n \nFIG.', '7\nA\n illustrates a graph showing an inaccurate interpretation for ground truth, according to an embodiment.\n \nFIG.', '7\nB\n illustrates a graph showing an accurate interpretation for ground truth, according to an embodiment.\n \nFIG.', '8\nA\n illustrates a graph showing petrophysical detection using raw data, according to an embodiment.\n \nFIG.', '8\nB\n illustrates a graph showing petrophysical detection using footprints, support vectors, and outliers, according to an embodiment.\n \nFIG.', '9\nA\n illustrates a graph showing a strong footprint overlap, according to an embodiment.\n \nFIG.', '9\nB\n illustrates a graph showing a partial footprint overlap, according to an embodiment.\n \nFIG.', '9\nC\n illustrates a graph showing no footprint overlap, according to an embodiment.\n \nFIG.', '10\nA\n illustrates a graph showing well 1 data, footprints, and outliers, according to an embodiment.\n \nFIG.', '10\nB\n illustrates a graph showing well 2 data, footprints, and outliers, according to an embodiment.\n \nFIG.', '10\nC\n illustrates a graph showing the well 1 footprint versus the well 2 data, according to an embodiment.\n \nFIG.', '10\nD\n illustrates a graph showing the well 2 footprint versus the well 1 data, according to an embodiment.\n \nFIG.', '11\nA\n illustrates a graph showing an inter-well distance matrix, according to an embodiment.\n \nFIG.', '11\nB\n illustrates a graph showing scaled eigenvalues of inter-well distances, according to an embodiment.\n \nFIG.', '11\nC\n illustrates a graph showing a 2D reconstruction of inter-well distances, according to an embodiment.\n \nFIG.', '12\n illustrates a flowchart of a method for predicting a formation property, according to an embodiment.\n \nFIG.', '13\n illustrates a schematic view of a computing system, according to an embodiment.', 'DETAILED DESCRIPTION\n \nReference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures.', 'In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention.', 'However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details.', 'In other instances, well-known methods, procedures, components, circuits and networks have not been described in detail so as not to obscure aspects of the embodiments.', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms are used to distinguish one element from another.', 'For example, a first object could be termed a second object, and, similarly, a second object could be termed a first object, without departing from the scope of the invention.', 'The first object and the second object are both objects, respectively, but they are not to be considered the same object.', 'The terminology used in the description of the invention herein is for the purpose of describing particular embodiments and is not intended to be limiting of the invention.', 'As used in the description of the invention and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will also be understood that the term “and/or” as used herein refers to and encompasses any possible combinations of one or more of the associated listed items.', 'It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.', 'Attention is now directed to processing procedures, methods, techniques and workflows that are in accordance with some embodiments.', 'Some operations in the processing procedures, methods, techniques and workflows disclosed herein may be combined and/or the order of some operations may be changed.\n \nFIG.', '1\n illustrates an example of a system \n100\n that includes various management components \n110\n to manage various aspects of a geologic environment \n150\n (e.g., an environment that includes a sedimentary basin, a reservoir \n151\n, one or more faults \n153\n-\n1\n, one or more geobodies \n153\n-\n2\n, etc.).', 'For example, the management components \n110\n may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment \n150\n.', 'In turn, further information about the geologic environment \n150\n may become available as feedback \n160\n (e.g., optionally as input to one or more of the management components \n110\n).', 'In the example of \nFIG.', '1\n, the management components \n110\n include a seismic data component \n112\n, an additional information component \n114\n (e.g., well/logging data), a processing component \n116\n, a simulation component \n120\n, an attribute component \n130\n, an analysis/visualization component \n142\n and a workflow component \n144\n.', 'In operation, seismic data and other information provided per the components \n112\n and \n114\n may be input to the simulation component \n120\n.', 'In an example embodiment, the simulation component \n120\n may rely on entities \n122\n.', 'Entities \n122\n may include earth entities or geological objects such as wells, surfaces, bodies, reservoirs, etc.', 'In the system \n100\n, the entities \n122\n can include virtual representations of actual physical entities that are reconstructed for purposes of simulation.', 'The entities \n122\n may include entities based on data acquired via sensing, observation, etc. (e.g., the seismic data \n112\n and other information \n114\n).', 'An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property).', 'Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.', 'In an example embodiment, the simulation component \n120\n may operate in conjunction with a software framework such as an object-based framework.', 'In such a framework, entities may include entities based on pre-defined classes to facilitate modeling and simulation.', 'A commercially available example of an object-based framework is the MICROSOFT® .NET® framework (Redmond, Wash.), which provides a set of extensible object classes.', 'In the .NET® framework, an object class encapsulates a module of reusable code and associated data structures.', 'Object classes can be used to instantiate object instances for use in by a program, script, etc.', 'For example, borehole classes may define objects for representing boreholes based on well data.', 'In the example of \nFIG.', '1\n, the simulation component \n120\n may process information to conform to one or more attributes specified by the attribute component \n130\n, which may include a library of attributes.', 'Such processing may occur prior to input to the simulation component \n120\n (e.g., consider the processing component \n116\n).', 'As an example, the simulation component \n120\n may perform operations on input information based on one or more attributes specified by the attribute component \n130\n.', 'In an example embodiment, the simulation component \n120\n may construct one or more models of the geologic environment \n150\n, which may be relied on to simulate behavior of the geologic environment \n150\n (e.g., responsive to one or more acts, whether natural or artificial).', 'In the example of \nFIG. \n1\n, the analysis/visualization component \n142\n may allow for interaction with a model or model-based results (e.g., simulation results, etc.).', 'As an example, output from the simulation component \n120\n may be input to one or more other workflows, as indicated by a workflow component \n144\n.', 'As an example, the simulation component \n120\n may include one or more features of a simulator such as the ECLIPSE™ reservoir simulator (Schlumberger Limited, Houston Tex.), the INTERSECT™ reservoir simulator (Schlumberger Limited, Houston Tex.), etc.', 'As an example, a simulation component, a simulator, etc. may include features to implement one or more meshless techniques (e.g., to solve one or more equations, etc.).', 'As an example, a reservoir or reservoirs may be simulated with respect to one or more enhanced recovery techniques (e.g., consider a thermal process such as SAGD, etc.).', 'In an example embodiment, the management components \n110\n may include features of a commercially available framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Tex.).', 'The PETREL® framework provides components that allow for optimization of exploration and development operations.', 'The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).', 'In an example embodiment, various aspects of the management components \n110\n may include add-ons or plug-ins that operate according to specifications of a framework environment.', 'For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Tex.) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow.', 'The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Wash.) and offers stable, user-friendly interfaces for efficient development.', 'In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'FIG.', '1\n also shows an example of a framework \n170\n that includes a model simulation layer \n180\n along with a framework services layer \n190\n, a framework core layer \n195\n and a modules layer \n175\n.', 'The framework \n170\n may include the commercially available OCEAN® framework where the model simulation layer \n180\n is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.', 'As an example, a framework may include features for implementing one or more mesh generation techniques.', 'For example, a framework may include an input component for receipt of information from interpretation of seismic data, one or more attributes based at least in part on seismic data, log data, image data, etc.', 'Such a framework may include a mesh generation component that processes input information, optionally in conjunction with other information, to generate a mesh.', 'In the example of \nFIG.', '1\n, the model simulation layer \n180\n may provide domain objects \n182\n, act as a data source \n184\n, provide for rendering \n186\n and provide for various user interfaces \n188\n.', 'Rendering \n186\n may provide a graphical environment in which applications can display their data while the user interfaces \n188\n may provide a common look and feel for application user interface components.', 'As an example, the domain objects \n182\n can include entity objects, property objects and optionally other objects.', 'Entity objects may be used to geometrically represent wells, surfaces, bodies, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters.', 'For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).', 'In the example of \nFIG.', '1\n, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks.', 'The model simulation layer \n180\n may be configured to model projects.', 'As such, a particular project may be stored where stored project information may include inputs, models, results and cases.', 'Thus, upon completion of a modeling session, a user may store a project.', 'At a later time, the project can be accessed and restored using the model simulation layer \n180\n, which can recreate instances of the relevant domain objects.', 'In the example of \nFIG.', '1\n, the geologic environment \n150\n may include layers (e.g., stratification) that include a reservoir \n151\n and one or more other features such as the fault \n153\n-\n1\n, the geobody \n153\n-\n2\n, etc.', 'As an example, the geologic environment \n150\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n152\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n155\n.', 'Such information may include information associated with downhole equipment \n154\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n156\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n155\n that may be configured for communications, noting that the satellite may additionally or instead include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n150\n as optionally including equipment \n157\n and \n158\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n159\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n157\n and/or \n158\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As mentioned, the system \n100\n may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable in the PETREL® software, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, a workflow may be a process implementable in the OCEAN® framework.', 'As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).', 'The systems and methods disclosed herein may predict formation properties that are normally interpreted or measured directly, using Machine Learning (ML) Algorithms.', 'The systems and methods disclosed herein use of Mud Gas Logs (MGL) and Drilling Data (DD), rather than Wireline (WL) or Logging-While-Drilling (LWD) logs, in the prediction of formation properties such as water saturation or total porosity.', 'The systems and methods disclosed herein may also use of two classes of ML algorithms, called Random Forest (RF) and Support Vector Machines (SVM).', 'RF algorithms combine multiple decision trees to yield a more accurate result with less bias and variance.', 'RF is an ensemble method because it utilizes the output of many decision trees.', 'SVM algorithms use a small number of data samples to capture complex decision boundaries in classification applications.', 'In addition to prediction with a measure of uncertainty, the systems and methods disclosed herein may use additional ideas that result in the creation of a complete automated system, which enables a non-expert to also build, select, and update ML models.', 'The systems and methods disclosed herein use available cloud technologies for storage and quick access to massive amounts of data, the inherent HPC environment for quick number crunching of large amounts of data, and internet technologies for quick transmission of data and results.', 'While the ideas are illustrated using well logs, the concepts are applicable to many other data types encountered in the oil industry.', 'Prediction of Formation Properties\n \nThe systems and methods disclosed herein use ML to predict a formation property where the ground truth does not exist.', 'As used herein, the “ground truth” refers to information provided by direct measurement (i.e. empirical evidence) as opposed to information that is provided by inference.', 'With reference to ML, the term “ground truth” is the standard that the ML algorithm needs to learn from.', 'This is used in statistical models to prove or disprove hypotheses.', 'The formation property can be one of the two types: interpreted or measured directly.', 'An interpreted formation property is one that is computed from available direct measurements using a formula or a chart, and some a-priori information.', 'One example is the determination of water saturation from Mud Gas Logs and Drilling Data.', "There is no direct measurement for water saturation, as it may be computed from triple-combo logs (e.g., density, neutron, deep resistivity), using, for example, Archie's formula, which, in addition to logs, uses a-priori information for water salinity, cementation, and saturation exponents (R\nw\n, m, n).", 'The systems and methods disclosed herein may also be used to predict formation properties that can be directly measured, by using combining data from different sources as inputs.', 'One example would be the prediction of compressional slowness log, either from the triple-combo logs, or from the MGL+DD combination, or a mix of the two.\n \nAssessment of Uncertainty in a Predicted Property\n \nAn ML prediction may be accompanied by uncertainty information to help guide the end-user to determine whether the answer is robust and consistent for making business decisions.', 'The assessment may be provided automatically, with metrics that are clear and easily understood by the non-expert.', 'Model Building\n \nOne example includes a large data set for N wells, with logs, core, MGLs, DD, etc. for each well, covering a specific formation in this particular field.', 'A new well is going to be drilled in the field and water saturation may be predicted from MGL+DD during the drilling of the well, prior to running WL logs.', 'The user may determine which of the N wells should be used in the model building.', 'The question of which wells to include in the model creation phase (also called “training”) cannot be answered solely on basis of proximity, because the wrong choice of wells may result in an ML model that will make inconsistent predictions.', 'The systems and methods disclosed herein include ML-based algorithms that aid the model building in an automated fashion.', 'Model Search\n \nOne example includes the case where an ML model has already been built for a specific formation/field, and appropriate data from a new well in the proximity of the field (e.g., without ground truth) becomes available and is to be used in predicting a desired formation property.', 'The first question to be answered at this point is whether the existing model is the right one for the new well.', 'Another example includes the more general case where a large number of models, built for specific formations in specific fields, have been catalogued in the form of a global library.', 'Given a well from a formation and field that is not anywhere near any of the fields covered in the global library, a matching model may be identified in the library, and the model-building may be skipped, which would save time and cost.', 'The systems and methods disclosed herein may offer an ML-based automated solution that can be used to achieve this.', 'The case of a global library uses additional considerations, which are discussed separately.', 'Model Update\n \nIf ground truth for a test well becomes available at a later time, the information from this particular well may be used to update an existing model.', 'An automated solution for this purpose is included herein.', 'A Global Library of ML Models\n \nAs the art is practiced in different formations/fields, the models built over time can be stored in a global library for later use.', 'If the models are catalogued, such that a search can be executed efficiently and quickly, it can prevent the building of new models, resulting in savings of cost, time, and storage.', 'Each model may be catalogued with attributes that carry a small foot print, so that search algorithms can run quickly.', 'Random-Forest Algorithms\n \nThe systems and methods disclosed herein use tree-based ensemble methods called Random Forest (RF) which are relatively new compared to other forms of machine learning techniques such as neural networks (NN).', 'A flavor of the original RF algorithm, called Quantile Regression Forest (QRF), may be used to assess uncertainty.', 'Support Vector Machines\n \nA modern classification algorithm called Support Vector Machines may be used.', 'High Computing Power\n \nRF algorithms use high computing power (HPC) for industrial applications, and such platforms have recently become reliable and economically feasible, encouraging the use of tree-based decision systems.', 'Internet and the Cloud\n \nBig data algorithms, as the name implies, process large amounts of data, and the cloud offers an environment where large amounts of data can be stored and accessed, economically and quickly.', 'The Internet is also used in this setup, as models or results can be sent to the user almost simultaneously.', 'Automation\n \nAutomation is used to reduce human involvement/intervention to increase efficiencies and turnaround times.', 'If a process is manual, where petrophysicists are replaced by data scientists/software engineers, then the gains are minimal.', 'Automation may result in using fewer people.', 'ML combined with automation allows lower levels of expertise/experience on the part of the user since the expertise is captured during the training phase and automation does not use the presence of data scientists/engineers.', 'Simultaneous Use of Mud Gas Logs and Drilling Data for Quantitative Interpretation\n \nMud Gas Logs (MGL) or Drilling Data (DD), alone, may be used in the qualitative prediction of formation properties.', 'In another embodiment, they may be used together (i.e., simultaneously) for quantitative prediction of formation properties.', 'Quantitative here implies results that have comparable uncertainty to those obtained from traditional methods, such as wireline logs and/or core.', 'A Complete and Automated Workflow Implementation\n \nHigh-quality predictions may be made using automated systems that are used to select training wells, match existing ML models to new test wells, and quality control the ground truth and input data.', 'Input Data\n \nThe inputs to the systems and methods disclosed herein are unlimited.', 'Any type of data can be used, either from MGL, or DD, or other sources.', 'For example, C1, C2, to C5, and their various linear and non-linear combinations (C1/C3, C1/C1+C2+C3 . . . )', 'may be used as inputs.', 'Cuttings shows, or any classifiers such as sand, shale, carbonate, etc. may be added.', 'Routine in the process is the use of GR, either from a WL or LWD/MWD run.', 'GR can also be obtained from cuttings.', 'Another idea is to use an LWD/MWD resistivity log, which is quite common on land wells.', 'Use of Other WL or LWD Logs\n \nGR may be used, which helps in clastic environments.', 'GR may not be used in conventional methods because their quasi-deterministic approach use formulas to relate the outputs to the inputs.', 'Quantitative Interpretation\n \nThe results of the methods disclosed herein are quantitative, where uncertainty is comparable to those of WL or LWD logs.', 'Conventional results are qualitative, based on first-hand experience, and change depending on how the use picks the lines.', 'Uncertainty\n \nThe method disclosed herein offers a metric for uncertainty, whereas conventional methods create no such information.', 'Automation', 'The method disclosed herein is automatic, whereas conventional methods are heavily manual and subject to user experience level.', 'Recursive Prediction\n \nThe method disclosed herein can predict a certain property, and use it as an input in the prediction of another quantity.', 'Repeated Use of Models\n \nConventional methods pick the trend lines from scratch for each well.', 'The characteristics of a trend picked for one well has no value for another.', 'Each one is picked individually.', 'The method disclosed herein is based on models, which can be used again and again, when certain criteria is satisfied, by removing the “begin-from-scratch” concept.', 'The systems and methods disclosed herein can be executed in real-time (e.g., while drilling a well, or logging a well), or offline (e.g., when the well has been drilled and completed, and no more operations are possible).', 'In either case, the systems and methods disclosed herein may be offered as a cloud-based service, where the combinations of answers are computed and delivered over the Internet, very quickly, and at low cost.', 'The service may be fully automated, not using experts or specialists to run.', 'In one example, water saturation may be predicted for a new well that is just being drilled, and MGL+DD+GR may be made available in near real-time (e.g., with a short delay of a few hours): \n \n \n \n1.', 'Knowing the location of the new well, the system may search for existing ML models that are already built.', 'If zero exist, it then looks for candidate wells in the proximity of the new well.', 'A candidate well is defined as one that has the appropriate input and ground data that can be used in building an ML model.', 'If there are candidate wells, the system may automatically determine which ones can be used to build a model.', 'If zero exist, the user is informed.', 'Otherwise, the system starts predicting Sw, as soon as data is transmitted from the rig, and sends results immediately.', '2.', 'Searching for existing ML models (e.g., above) may be skipped if the system finds a model that is already built for the field/area, designed for the appropriate input data and property to be predicted.', 'However, the model may not be used blindly.', 'The system may ensure that the model to be used is consistent with the formation/field.', 'The consistency test starts as soon as data becomes available from the new well.', 'If consistency is found, predictions are sent to the rig.', 'If the model is not deemed consistent, the user is informed, and the process terminates.', '3.', 'If an answer is provided in (2), an uncertainty metric is also provided to the user to aid the business decision making process.', 'The user is urged not to depend on the ML answers if the predictions are considered to have high uncertainty.', 'Automated Quality Control\n \nThe systems and methods disclosed herein can be used to cross-check input data, ground truth, or interpreted results, automatically.', 'The systems and methods disclosed herein can be used to find poorly interpreted logs (e.g., wrong choice of input parameters such as Rw, m, n), logs affected by deep invasion, washouts, whole mud invasion, in addition to bad data due to tool malfunctions or calibrations.', 'Availability of Invasion-Free Formation Properties\n \nAs MGL+DD are available at the time of the cutting of the formation (e.g., as soon as the drill bit churns up the rock), they represent the earliest information in the record and are free of invasion effects.', 'These two measurements may be less affected by invasion than some of the LWD measurements, because, depending on the position of a sensor, a certain measurement may be made under some invasion conditions due to slow drilling speeds.', 'An invasion-free measurement opens the way to a number of applications.', 'For example, acoustic impedance computed from invasion-free logs may render superfluous doing fluid substitution, which is often the case when using WL logs.', 'Or, acoustic impedance computed from MGL+DD can be used to validate the assumptions made in a fluid substitution application.', 'Having a real-time invasion-free acoustic impedance log opens the door to many applications, such as real-time seismic-ties, overpressure detection, geo-steering, etc.', 'Better Operational Decisions\n \nConsider the following scenarios: \n \n \n \n1.', 'Unexpected pay.', 'If the prediction indicates hydrocarbons in a zone that is not known to contain hydrocarbons, additional formation evaluation runs (e.g., logs, cores, well tests) can be planned ahead of time, resulting in improved logistics and operational efficiencies.', '2.', 'No pay.', 'If the predictions hint that the zone of interest has no indications of hydrocarbons, advanced logging runs can be added to the program (such as MDT, SWC . . . )', ', to ensure that the ML answers are validated.', 'A user can also cancel the planned logging operations, if the confidence level in the ML answer is high.', 'Finding Laminated Pay\n \nWhile the WL or LWD logs may not have the resolution to detect laminated pay, MGL+DD, in combination with cuttings shows and other non-traditional data can be used to flag zones containing hydrocarbons.', 'Early knowledge of such a zone may then lead to the collection of additional petrophysical information (e.g., cores or MDT tests) to validate the predictions.', 'Automated Quick Look Answers\n \nA prediction may be applied to WL or LWD logs (or a combination thereof) to predict petrophysical quantities such as Sw and PHIT.', 'While trivial at first sight, this approach removes the involvement of experts for providing almost real-time answers at the well site.', 'Consider a field where an ML model has been built, using WL or LWD logs, for Sw and other properties.', 'In a new well, data in real-time can be sent over the Internet to obtain answers without involving petrophysicists.', 'One can also download the ML model to a field computer before the job, and produce answers at the wellsite in real-time, without involving petrophysicists or experienced personnel.', 'A Solution for Missing/Bad Logs\n \nConsider a case where one of the logs on the WL run is bad, for example, the density log.', 'Either the problem is discovered too late to repeat the measurement, or a rerun is not considered for operational reasons.', 'A replacement “density” log can be created in a number of ways: (i) using from MGL+DD alone from adjacent wells, (ii) using WL or LWD logs from adjacent wells, (iii) using a combination of (i) and (ii).', 'The caveat in the third case is that invasion physics may be taken into account when combining data acquired at different times during the drilling of a well.', 'Answers for Wells without Open Hole Logs\n \nAnother variation is a well where there is no log data, due to well collapse, stuck pipe, instability, etc.', 'Replacement logs can be computed from MGL+DD, as they would be acquired as soon as the bit penetrated the formation.', 'Answers for Wells without Open Hole Logs but with Cased Hole Logs\n \nIn the absence of Open Hole (OH logs), Cased Hole (CH) logs can be used in the evaluation of petrophysical properties, assuming that the CH logs are run after sufficient time is allowed for the dispersion of invasion effects in the flushed zone probed by the CH tools.', 'CH interpretation may use a-priori information, such as total porosity, VShale, which are computed from OH logs.', 'In the absence of OH logs, MGL+DD can be used to predict the inputs, further to be used in CH interpretation.', 'Wells with Limited LWD Sensors in the BHA\n \nConsider a case where the LWD string includes GR+Resistivity, which is quite popular in onshore wells for cost considerations.', 'This combination may not allow the computation of either porosity of water saturation, in the absence of porosity tools, and the systems and methods disclosed herein can be used to combine MGL+DD+Limited LWD data to compute Sw or PHIT (or other properties).', 'Train-While-Drilling Application\n \nIt is possible to build a specific model for a specific well, during an LWD operation, even if there is no other data available from other wells.', 'This particular application may work in those cases where the formation is thicker than the distance between lower most and upper most LWD sensor to be used in supplying the ground truth data.', 'Once the LWD string is sufficiently deep into the reservoir to provide the ground truth, say for Sw, the user can build a model on the fly, most likely in the surface, and start predicting Sw from MGL+DD, ahead of the LWD data.', 'This option may be particularly attractive in horizontal/high angle wells, where the thickness vs sensor length criterion is easily satisfied.', 'Prediction Operation', 'The following equation represents an ML-based prediction process, executed by the predict algorithm, which takes two inputs: \n \nY\n=predict(\nM,X\n), \n where Y is the response matrix, M is the ML model, and X is the predictor matrix.', 'The type of the model is denoted by a subscript, for example, M\nRF \nrepresents a random-forest model.', 'Model Creation\n \nThe function that creates an ML model is given by the operation: \n \nM\ntype\n=createModel(\nX,Y\n,‘type’) \n Where the type can be RF, SVM or QRF; standing for Random-Forest, Support Vector Machine or Quantile Regression Forest, respectively.', 'Response Matrix', 'In general, Y is a column vector, as formation properties are predicted one at a time.', 'Furthermore, Y\np \nand Y\nt \nare used to distinguish a response that is predicted from ML vs. a response that is used as ground truth, respectively.\n \nPredictor Matrix\n \nThe predictor matrix X is multidimensional.', 'X\nij\n, a row of X, corresponds to the predictor vector for the depth index i. Each column, subscripted by j, represents a specific type of measurement.', 'For example, consider a data set that has C1, C2, C3, ROP, RPM, WOB and GR measurements for each depth, and assume that the measurements are ordered as listed.', 'Then, the first column X\ni1 \nwould represent the C1 values; the fourth column X\ni4 \nwould contain the ROP values.', 'Rows are ordered by depth, and a higher i value indicates a deeper depth.', 'In addition, subscripts MGL, DD, WL, etc. are also used to identify the type of data contained in the predictor matrix.', 'For example, X\nMGL+DD \nindicates that the predictor matrix has data from Mud Gas Logs and Drilling Data.', 'Well Specification/Domain\n \nA superscript for X or Y indicates a specific well.', 'For example, Y\np\n2 \nrepresents the predicted response, for the chosen property from well 2, whereas X\nij\n1 \nrepresents the predictor matrix used in the case of well 1.', 'A superscript in capital letters indicates a domain of wells, for example, given W={1,2,3,4,5} and T={1,3,5}; X\nW \ncorresponds to the predictor matrix for wells 1 to 5, whereas X\nT \ncorresponds to the predictor matrix for wells 1, 3 and 5.', 'T=W−{2,4}, using set notation.', 'Concatenation of Matrices\n \nThe two operators vertcat and horzcat represent the vertical or horizontal concatenation of matrices.', 'For example, given X\n1 \nand X\n2\n, \n \nX\n=vertcat(\nX\n1\n,X\n2\n), \n corresponds to the following using matrix notation: \n \n \n \n \n \nX\n \n=\n \n \n \n(\n \n \n \n \n \nX\n \n1\n \n \n \n \n \n \n \nX\n \n2\n \n \n \n \n \n)\n \n \n.', 'Similarly, X=horzcat(X\n1\n, X\n2\n), is equivalent to: \n \nX\n=(\nX\n1\nX\n2\n).', '(1) Prediction of Formation Properties\n \nPrediction of formation properties using ML is the main task in this section.', 'There are three subtasks, discussed in detail:\n \n1.', 'Prediction of Interpreted Formation Properties,\n \n2.', 'Prediction of Directly Measured formation properties,\n \n3.', 'Prediction of Formation Properties for Quality Control.', 'The systems and methods disclosed herein use MGL+DD+GR, for Sw, PHIT and other properties.', 'Prediction of Interpreted Formation Properties\n \nIn this subtask, an already existing Random-Forest model MRF is used to predict an interpreted formation property such as Sw or PHIT: \n \nY\np\n=predict(\nM\nRF\n,X\n).', 'The application is not limited to just Sw or PHIT.', "A user can duplicate the process for any interpreted formation property, such as Volume of Shale (VSH), Volume of Clay (VCLY), Acoustic Impedance (AIMP), Absolute Permeability (KABS), Young's Modulus (YM), Poisson's Ratio (PR), amongst many others.", 'An interpreted formation property (as opposed to a directly measured property) is one that is computed from WL or LWD logs (e.g., such as resistivity, neutron, density, sonic, etc.), using analytic formulas or cross-plots techniques, implemented in the form of computer algorithms.', "One example is using Archie's formula to calculate Sw in clean formations from WL logs.", 'In addition to logs, the process uses a-priori information, such as formation water salinity; cementation, and saturation exponents (m,n); knowledge of lithology (e.g., quartz, calcite, kaolinite), formation temperature/pressure profiles; and fluid properties.', 'An experienced petrophysicst executes the workflow, by picking/selecting various parameters used by the modules contained in the workflow. \nFIG.', '2\n illustrates the interpretation workflow.', 'In an ML model built to predict an interpreted property, the ground truth Y\nt \nused to train the model M can be wrong if the interpreter fails to properly quality control the data used to compute Y\nt\n, or selects in accurate input parameters.', 'An improperly built model may lead to inconsistent predictions.', 'This is the reason for the emphasis and distinction on interpreted, vs. measured.', 'The systems and methods disclosed herein offer ML-based automated workflows to ensure the consistency of the ground truth, through the use of a number of ML based automated algorithms, as outlined in the section entitled Model Building.', 'The systems and methods disclosed herein may use non-traditional logs, such as Mud Gas Logs (MGL) and Drilling Data (DD), with the addition of a GR log obtained from cuttings or an MWD/LWD run, to predict interpreted formation properties, that may also be determined from WL or LWD logs.', 'Specifically, given \n \nY\np\n=predict(\nM\nRF\n,X\n), \n this translates to the following equations: \n \nY\np\n=S\nW\n, or \nY\np\n=Ø\nT\n, \n and \n \nX≡X\nMGL+DD+GR\n≡horzcat(\nX\nMGL\n,X\nDD\n,X\nGR\n).', 'The two predictor matrices X\nMGL \nand X\nDD \nare formed by the horizontal concatenation logs, where each log is represented by a column vector: \n \nX\nMGL\n=horzcat(\nC\n1norm\n,C\n2norm\n,C\n3norm\n,C\n4norm\n,C\n5norm\n), \n \nX\nDD\n=horzcat(ROP,RPM,WOB,flowRate).', 'A different model is used in Sw prediction vs. PHIT, since the ground truth used in each case is different.', 'In other words, by defining the model building as: \n \nM\nRF\n=createModel(\nX\ntrain\n,Y\nt\n,‘RF’\n), \n the ground truth used differs: \n \nY\nt\n=S\nw \nfor water saturation modeling,\n \nY\nt\n=Ø\nT \nfor total porosity modeling,\n \neven though the predictor matrix is identical for both (X\nMGL+DD+GR\n).', 'The ground truth may be obtained from a workflow built around the quantiELAN module of Techlog:', '[\nSw\n,PHIT]=quantiELAN(\nX\nWL\n,parameters).', 'ELAN (short for quantiELAN) is a multi-component petrophysical interpretation module that takes in logs and a set of parameters.', 'ELAN uses careful quality control of input logs and selection of input parameters.', 'Results from an ELAN, or any other petrophysical package, may be validated against core measurements.', 'FIG.', '3\nA\n illustrates the model building and prediction.', 'The top row is for training, and the bottom row is for prediction.', 'In this specific example, the input data are MGL+DD+GR, and the ground truth is either Sw or PHIT.', 'While training, the machine learns (or the Random-Forest Algorithm, top row, middle) \n306\n to predict Sw or PHIT, given as the ground truth coming from ELAN (top row, right) \n304\n and the predictor matrix containing MGL+DD+GR (top row, left) \n302\n.', 'The learning is saved in the model M\nRF\n, which is an ensemble of hundreds of decision trees (bottom row, middle) \n310\n.', 'The wells used in the training or Model Building are called the training wells.', 'A well in the training-set has the corresponding data for both the predictor and the ground truth (MGL+DD+GR, and Sw or PHIT, respectively).', 'Given an ML model, the user then uses it to predict the formation properties, for the test wells, as shown in the bottom row.', 'Unlike the training-wells, test-wells do not have the ground truth.', 'Given the ML model (bottom row, middle) \n310\n, predictor data from any test-well (bottom row, left) \n308\n is fed into the model, and formation properties (Sw and PHIT in this case) are predicted (bottom row, right)', '312\n.', 'The model may be built once, for a given formation in a given field.', 'The model building process may have to be built for a different field, starting from scratch, using a new set of training-wells.', 'An example for Sw prediction is shown in \nFIG.', '3\nB\n, which shows three tracks \n320\n, \n322\n, \n324\n.', 'Given a set of 6 wells, with MGL, DD, WL and core data, a RF model for Sw may be built from two wells, and applied to the remaining four wells.', 'The comparison of the ground truth vs. the prediction, from one of the wells is shown in the middle track \n322\n of \nFIG.', '3\nB\n.', 'The agreement between the predicted Sw and ELAN based SW is strong, supporting the case that the predictions are quantitative and have the accuracy/precision expected from logs.\n \nFIG.', '3\nC\n shows the case for PHIT.', 'The curves in the left track \n332\n of \nFIG.', '3\nC\n correspond to GR (shown for reference).', 'The curves in the right track \n334\n of \nFIG.', '3\nC\n correspond to the ground truth and predicted properties (e.g., total porosity).', 'The Random Forest model was trained from two wells, where the ground truth was obtained from ELAN.', 'The agreement between the two curves is strong, indicating WL quality.', 'Prediction of Directly Measured Formation Properties\n \nThe workflow is identical to what is described in the previous subsection and as illustrated in \nFIG.', '3\nA\n, with the difference that the ground truth (top row, right) \n304\n is a specific WL or LWD log.', 'One example is the prediction of a thermal neutron log acquired in bad-hole conditions, again from MGL+DD+GR.', 'Since the input data (MGL+DD+GR) is acquired at the time of drilling and before borehole deterioration, it can be used to predict a thermal neutron log free of washout effects (often in the form of excessive porosity).', 'There is no interpretation involving a petrophysicist for the ground truth in this case.', 'The predicted quantity is a measurement that is normally acquired directly by a logging tool.\n \nFIG.', '4\n shows a graph \n400\n characterizing the prediction of compressional acoustic slowness, from a set of MGL+DD+GR.', 'One curve is the ground truth for the test well.', 'The other curve is the ML prediction.', 'The predicted log mimics the ground truth quite well, with low bias and variance.', 'In case of a bad sonic log, the ML prediction may be used for further interpretation, such as the computation of acoustic impedance for seismic-log ties.', 'In another embodiment, the user can predict sonic logs in near real-time from MGL+DD+GR, and use it for the assessment of geomechanical properties, before WL logs are run.', 'In the case of LWD logging, the compressional slowness may be provided by the ML process, in case an acoustic LWD log were not available.', 'The user may ask why this sub task is different from the previous one.', 'The reason for separation is to emphasize the time-zero nature of MGL+DD, and exploit it in different embodiments to obtain formation properties prior to invasion.', 'Even in the case of LWD logging, given the fact that most sensors are distanced from the bit, MGL+DD are the earliest information collected on the rocks penetrated.', 'The differences between the curves in \nFIG.', '4\n may have other explanations.', 'Perhaps, the differences are due to invasion, for example, gas being invaded by liquid mud filtrate.', 'Borehole enlargement because of lack of geomechanical integrity may be another reason, since the MGL+DD would be acquired before any washouts.', 'Prediction of Formation Properties for Quality Control\n \nWhile the quality control (QC) of directly measured or interpreted formation properties may sound trivial, doing this in an automated fashion, using ML algorithms in a cloud environment, over thousands of logs with very short turn-around-times (TAT) is very appealing and economically enticing. \nFIG.', '5\n can be used to illustrate the idea, even though it is actually intended for the Model Building.', 'FIG.', '5\n includes four tracks: \n502\n, \n504\n, \n506\n, \n508\n.', 'The first track \n502\n includes caliper vs. bit size.', 'The shading indicates washouts, which are severe in this example.', 'The second track \n504\n includes GR.', 'The shading indicates reservoir.', 'The third track \n506\n includes water saturation, ground truth vs. prediction.', 'One curve is the ground truth for Sw obtained from logs.', 'Another curve is the prediction, from the ML algorithm.', 'The results shown in the third track \n506\n were created from a training well set that included a well with bad interpretation (i.e., the porosity was calculated using inaccurate hydrocarbon properties).', 'Because the ML model is contaminated due to the inclusion of a bad interpretation, the predictions are also inaccurate.', 'The fourth track \n508\n includes the same features at the third track \n506\n, except that the ML model has been re-trained with properly interpreted logs form the training wells.', 'Because the machine has learned from accurate data, the resulting predicted Sw shows improvement.', 'The curves in the third and fourth tracks \n506\n, \n508\n in \nFIG.', '5\n correspond to two Sw computations from the set same set of logs in the same well (from a set of 6 wells).', 'Track 3 shows the ML result based on inaccurate ground truth provided by an inexperienced petrophysicist.', 'Track 4 shows the ML result, for the same well.', 'The ML model was based on ground truth originating from two of the original set of six wells, interpreted by an experienced petrophysicist, using accurate inputs and parameters.', 'The difference between the two curves may be seen, and can easily be picked by an automated process.', 'In fact, any of the algorithms: ALG2, ALG3, ALG8, ALG9 or ALG10, can be used to identify the inaccurate interpretations, or direct measurements that are bad.', 'The point here is the automated nature of the implementation, where guidance is given to the algorithm to clearly label the properties that are not representative.', '(2) Assessment of Uncertainty in a Predicted Property\n \nTo decide whether the predictions made by the ML model are reliable enough for decision-making, the end-user may use some metric to assess the quality of the answers provided.', 'Such metrics are referred to as measures of “uncertainty,” and there are many different approaches and algorithms to produce them.', 'Regardless of the specific metric chosen, the information provided may be quantitative and definitive for the non-specialist for practical use.', 'This is the way to realize the efficiency gains, as the involvement of specialists would slow down the process and increase operational costs.', 'The underlying concept for assessing uncertainty is that of Conditional Probability Density Function (CPDF), available from a variation of the original Random Forest Algorithm, called Quantile Regression Forest (QRF).', 'Prediction Interval (PI), obtained from the application of QRF may be used to assess uncertainty.', 'FIGS.', '6\nA and \n6\nB\n illustrate graphs showing the uncertainty, in the form of PI.', 'FIG.', '6\nA\n includes four tracks \n610\n, \n620\n, \n630\n, \n640\n, and \nFIG.', '6\nB\n includes four tracks \n660\n, \n670\n, \n680\n, \n690\n.', 'The first tracks \n610\n, \n660\n represent caliper vs. bit size.', 'The shading indicates washouts, which are severe in this example.', 'The second tracks \n620\n, \n670\n represent GR.', 'Shading indicates reservoir.', 'The third tracks \n630\n, \n680\n represent water saturation and ground truth vs. prediction.', 'One curve is the ground truth for Sw obtained from logs.', 'Another curve is the prediction from the ML algorithm.', 'The fourth tracks \n640\n, \n690\n represent uncertainty for Sw.', 'The curve is the same predicted Sw curve from ML.', 'The left and right boundaries correspond to +/−25% confidence bands around the predicted value.', 'Two wells with different levels of uncertainty are compared.', 'The PI for Sw in the case of well 1 is much wider than that of Well 2.', 'The increased level is due to the washouts (e.g., enlarged borehole conditions) affecting the measurements.', 'Comparison of the predicted Sw vs. the ground truth, shown in the third track \n630\n, \n680\n for both wells, is also consistent with the uncertainty assessment: while the predicted answer in the case of well 2 closely tracks the ground truth, variations of larger magnitude are observed in the case of well 1.', '(3) Model Building\n \nA model may be built using a given a number of candidate training wells.', 'The candidate wells have both the input data to be used in the prediction (e.g., MGL+DD+GR) and the ground truth to be used in the training (Sw, PHIT).', 'The candidate wells may also have the WL or LWD logs that are used in the determination of the ground truth.', 'The question to be asked at this stage revolves around the selection of the training wells, starting with a domain of wells contained in W. In other words, given: X\nW\n, Y\nt\nW\n, where W={1, . .', '.', ', N}, what is the domain S for model building, such that S⊆W?', 'The systems and methods disclosed herein include several automated ML solutions, that can be deployed to define S, given W.\n \nGiven a group of wells clustered based on physical proximity, a well that meets any of the following conditions may be excluded from the training set: \n \n \n \na.', 'The data from the well, both X and Y, despite its proximity, covers a different formation compared to the rest of the wells,\n \nb.', 'The data used to determine the ground truth Y\nt \nis bad,\n \nc.', 'The data in the predictor matrix X is corrupted,\n \nd. Inaccurate interpretation model or parameters have been used in the determination of Y\nt\n.', 'Each one of these cases is discussed in more detail below, with a set of algorithms recommended as solutions.', 'Table 1 shows a summary case-solution pairs.', 'Case a\n \nThe zone of interest is from a different field/formation.', 'Given that models are most likely to be specific for a given formation in a given field, wells from different formations in different fields may not be mixed.', 'This is due to the fact that inherent formation properties such as mineralogy (e.g., clastic vs carbonate), water salinity, hydrocarbon type (e.g., gas vs oil), formation temperature and pressure, porosity range, wettability, and others will result in log responses that are different.', 'While proximity of the wells may appear as the most practical selection criterion, there may be others because of the possibility of differing formation properties.', 'Algorithms ALG2, ALG8, and ALG12 can be used to determine if a well should be kept in the training set.', 'ALG2, called LOOWCVRF (for Leave-Out One-Well Cross-Validation Random-Forest) is analogous to the LOOCV (Leave-One-Out Cross-Validation) method used in Statistical Learning.', 'In ALG2, in each iteration includes:\n \n1.', 'a well is selected for testing,\n \n2.', 'M\nRF\n, an Random-Forest model is built from the wells but the well selected for testing,\n \n3.', 'Y\np \nis computed using MRF from 2 above\n \n4.', 'An error vector is computed from (Y\np\n-Y\nt\n).', 'At the end of the loop, a plot of the chosen error type vs. well number is made, and the wells with error levels above the threshold are removed from the training set.', 'FIG.', '7\nA\n is a graph \n700\n showing an example of an inaccurate interpretation of the ground truth for ALG2, and \nFIG.', '7\nB\n is a graph \n750\n showing an example of an accurate interpretation of the ground truth for ALG2.', 'Wells 1 and 6 have error levels above the threshold and would be kept out of the training set for building a model.', 'ALG8, LOOWCVSVM is the SVM counterpart of ALG2.', 'Case b\n \nBad input data is used in the determination of ground truth.', 'Consider a case of wells with quad combo data, where one has a severe washouts, or has a bad log (e.g., density) due to a tool malfunction.', 'If formation parameters, such as Sw or PHIT, are computed from such a set of logs, the results may be inconsistent with the ground truth obtained from wells where such anomalies were not present.', 'Furthermore, bad results included in the training set may contaminate the ML model and lead to low quality results.', 'Several algorithms are included to deal with this problem: ALG2, ALG3, ALG4, ALG6, ALG8, ALG9 and ALG10.', 'An example of ALG3 can be seen in \nFIG.', '7\nB\n.', 'The error for well 5 is higher compared to others, because the GR reading in well 5 was highly impacted by large washouts.', 'After the identification of the problem, a borehole modification was applied to GR log, which in turn led to lower errors for Sw prediction.', 'Case c\n \nBad input data, for example, MGL from a faulty or uncalibrated sensor, may lead to the creation of an unstable ML model, since the ML algorithm will learn from bad data.', 'Depending on the severity of the problem, either a number of variables or the entire data from that well may be excluded from the training process.', 'The solutions offered for Case b also apply to Case c. Cases b and c are handled separately to point out where the ground truth is actually questioned in Case b.\n \nCase d\n \nConsider an example where quad combo logs are used in the determination of Sw.', 'Also consider that the salinity of the formation is 30 kppm, while a petrophysicist improperly uses 300 kppm.', 'The Sw computed in this case will be quite different from Sw computed in wells with the accurate water salinity.', 'Hence, even if the input logs used in the determination of the ground truth are deemed of good quality, the ground truth may be validated before the well can be included in the training set.', 'An example is shown in \nFIG.', '5\n.', 'Porosity in one of the wells included in the training set was computed inaccurately due to using wrong hydrocarbon density.', 'This led to an inaccurate porosity calculation, which in turn impacted the calculated Sw.', 'The inclusion of the bad well in the training resulted in an ML model that was trained on bad data, resulting in the prediction shown in the third track \n506\n, which is completely off the ground truth.', 'After detecting the problem using one of the approaches, the calculations were repeated with accurate input parameters.', 'When training was repeated using the same training-wells, but with the accurate interpretation, the improved Sw for the same test well can be seen in the fourth track \n508\n of \nFIG.', '5\n.', 'The algorithms used for this case are ALG2 and ALG8.', 'TABLE 1\n \n \n \n \n \n \n \n \n \n \nAlgorithm\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nTask\n \nALG1\n \nALG2\n \nALG3\n \nALG4\n \nALG5\n \nALG6\n \nALG7\n \nALG8\n \nALG9\n \nALG10\n \nALG11\n \nALG12\n \n \n \n \n \n \nQC of interpreted\n \n \nX\n \nX\n \n \n \n \n \nX\n \nX\n \nX\n \n \n \n \n \nProperties\n \n \n \nQC of Directly Measured\n \n \nX\n \nX\n \n \n \n \n \nX\n \nX\n \nX\n \n \n \nProperties\n \n \n \nModel Building, Case a\n \n \nX\n \n \n \n \n \n \nX\n \n \n \n \nX\n \n \n \nModel Building, Case b\n \n \nX\n \nX\n \nX\n \n \nX\n \n \nX\n \nX\n \nX\n \n \n \nModel Building, Case c\n \n \nX\n \nX\n \nX\n \n \nX\n \n \nX\n \nX\n \nX\n \n \n \nModel Building, Case d\n \n \nX\n \n \n \n \n \n \nX\n \n \n \nModel Search\n \n \n \n \n \n \n \n \n \n \n \nX\n \n \n \nModel Update\n \nX\n \n \n \n \n \n \n \n \n \n \n(4) Model Search\n \nConsider the case of the initiation of an exploration campaign where the first well is being drilled.', 'Consider further that some MGL and DD data become available, and the exploration team wants to predict Sw and PHIT, to test their play concept as well as assessing potential changes to the logging program.', 'An ML model for the formation in this new play cannot be built in the absence of ground truth, but could one of the models stored in the global library of ML models be a match?', 'The task described in this thought experiment, defined as Model Search, is the focus of this section.', 'Consider the case where a few wells have already been drilled, but ground truth has not been made available due to ongoing core work.', 'The Model Search workflow has use even in the case of drilling programs where an ML has already been built.', 'For example, as new wells are drilled towards the fringes of the field, where the interwell distances between the new wells vs. the original wells the model was built from increase, can a user still use the existing model to make predictions in the new wells?', 'Given the background that a global library of petrophysical machine learning models is available, and that the models represent varied basins, formation types (e.g., clastics, carbonates) and fluid contents, the basic idea in Model Search is to efficiently scan the global petrophysical library, and return one or more models that can be applied to the data from the new well.', 'One criterion for matching the new well data against the library of stored models is to minimize the amount of extrapolation that occurs when applying a model to the new well data.', 'It is known that predictive models tend towards poor performance in extrapolation situations: those where the predictor variables for the new well fall outside the range of the training set for which the model was designed.', 'Whereas it may seem trivial to detect extrapolation situations in the case of one or two predictors, in higher dimensions it may be difficult.', 'Even in two dimensions, measurements which fall inside the range of each training predictor taken individually can still be outside the joint distribution of the predictors in the training set.', 'To address this problem, the application of the footprint computed from a one-class support vector machine may be extended as follows: \n \n \n \n1.', 'A library of petrophysical models is a collection of machine learning models (e.g., random forest models) trained on a number of input wells using a particular set of input log curves.', '2.', 'Associated with each library model is a footprint trained on its input data using a one-class support vector machine.', '3.', 'When a new well is available, select the same input logs from a new well and train a one-class support vector machine which defines the footprint of the new well.', '4. Compute the similarity between the new well data footprint and the footprint of each model in the library using the Jaccard (e.g., sample wise intersection over union) or other similarity metrics.', '5. Return the model which provides the best match, or a list of models ranked by the strength of the match with the new well.\n \n6.', 'Apply the best matching model to make predictions for the new well\n \n \n \n \n \nALG11, named RankModels, is designed to aid the Model Search process by returning a ranked index of models from a global ML model library.', '(5) Model Update\n \nOne decision point arrives in the lifecycle of an ML model when the ground truth from a well becomes available.', 'Consider that a model M, built for a domain of wells W, already exists and has been used to make predictions for well {n} which at the time did not have the ground truth.', 'In other words, starting with: \n \nX\nW\n,Y\nW\n,M\nRF\n, where \nW={\n1, . . .', ',\nN}, \n \n \nX\nn\n,Y\np\nn\n, where \nn∩W=Ø, \n \n should the existing model for this formation/field be updated by adding well n into W, once Y\nt\nn \nbecomes available?', 'Another associated question is whether the predictions made for other wells in the field—which do not have ground truth—should be replaced with a new set of predictions made using the updated model?', 'The decision to replace can have serious consequences, for the effort and time that it would take, in addition to the possible changes in reserve estimates if the predicted properties were used in building static or dynamic models.', 'Assuming that Y\np\nn\n≈Y\nt\nn\n: \n \n \n \n1.', 'Obtain the base-case error vector, if it is not readily available in the global model library: \n \ne\nbasecase\n=ComputePredictionError(\nX\nW\n,Y\nt\nW\n,X\nW\n,Y\nt\nW\n).', '2. Create a new well domain by adding well n into W: V=union(W, n).', '3. Obtain the new error vector corresponding to the updated model: \n \ne\nnew\n=ComputePredictionError(\nX\nV\n,Y\nt\nV\n,X\nW\n,Y\nt\nW\n).', '4.', 'Given the error difference vector Δ\ne\n=e\nbasecase\n−e\nnew\n, if Δ\ne\n>0 and |Δ\ne\n|≤ε\nmin\n, then update model and repeat predictions for wells without ground truth.', 'An error threshold is used to decide if the model should be updated, to prevent updates originating from numerically minor values of Δ\ne\n.', 'Some threshold values for Sw and PHIT are 0.05 and 0.005, respectively.', '(6) Building a Global Library of ML Models', 'The idea of building a global library is straightforward and appealing.', 'As the art is practiced in different formations/fields, the models are stored in a global library, which one day may have an already built ML model for a majority of cases to be encountered.', 'While the concept of building a library part is trivial, it is populated with already computed components to enable an automated and efficient search workflow that can scan through hundreds of models quickly.', 'The mechanism for the search task has already been discussed in the Model Search Section, through the use of ALG11.', 'What remains is the definition of the data/model components to be stored in the library for an efficient search, in addition to the triplets of {X, Y, M\nRF\n} for each model.', 'Given that ALG11 uses the one-class SVM algorithm, storing each M\nSVM \ncompletes the solution.', 'Hence, each member of the library has the following data/model components and parameters: \n \n \n \n{X, Y, M\nRF\n, M\nSVM\n, outLierFraction}.', 'The systems and methods disclosed herein use Random-Forest techniques.', 'In other embodiments, similar applications may be built using other ML algorithms such as SVM (Support Vector Machines), Deep Learning (an advanced version of Neural Networks), GL (Genetic Algorithms), amongst some others.', 'The systems and methods disclosed herein use Mud Gas Logs (C1 to C5), Drilling Data (ROP, RPM, WOB and Flow Rate), and basic logs such as GR.', 'Other data types may also be used, such as Mud Weight, Mud composition, wellsite geology answers (e.g., cuttings descriptions, shows), new types of mud logs (C6, C7, C8, N\n2\nO C\n2\nO, H\n2\nO . . . )', 'and drilling data (e.g., torque, vibration, etc.).', 'In one embodiment, a limited suit of LWD measurements may be added.', 'For example, a user can combine MGL+DD with LWD, GR, Resistivity, and Density.', 'There are similar combinations like this for LWD and WL.', 'The systems and methods disclosed herein may use measurements made at the surface.', 'In other embodiments, drilling measurements made at the bit may be used (e.g., using a downhole tool/sensor).', 'It is also possible to use a downhole sensor to duplicate the mud log measurement (e.g., to obtain the measurement downhole, rather than at the surface).', 'Hence, a mud log measurement made downhole can be used as a differentiator.', 'In another embodiment, the prediction may be done downhole (e.g., the measurements and the ML prediction part).', 'The user can load the ML model to an LWD tool, process the data from mud-log and drilling sensors in real-time, downhole, and send the predicted quantities uphole using mud telemetry.', 'Although the methods have focused on Sw, PHIT, and some direct measurements other properties, such as anisotropy, stress, maturity, flow rates, relative perm, acoustic impedance, wettability, etc. may also be used.', 'The Random Forest Algorithm\n \nRandom forest is a machine learning algorithm that has been successfully applied to a variety of classification and regression problems.', 'The idea of random forests is to construct a large number of regression trees from bootstrap samples of the training data.', 'For each tree and each node, a random selection is made when choosing which variable to split on.', 'In addition, a random subset of the predictors is considered as candidates for splitting at each node.', 'The size of the random subset is one of the few tuning parameters of the algorithm, and the minimum number of samples in each node of the tree is another.', 'Random forests perform well without extensive tuning of these parameters.', 'Taken on their own, each tree is a noisy but unbiased predictor of the response.', 'In regression, a prediction from a random forest model is the average response across the trees.', 'Averaging the predicted response across the trees in a random forest reduces the variance of the predictions and provides a model that can capture complex relationships between the predictors and the response.', 'For each tree: \n \n \n \n1.1 Draw a bootstrap sample from the training data\n \n1.2 Grow a decision tree from the bootstrap sample by recursively repeating the following for each child node until the minimum node size is reached:', '1.2.1 Select at random the candidate variables for splitting out of the predictors.', '1.2.2 Select the best variable and split point\n \n1.2.3 Split the current node into two child nodes\n \n2.', 'Output a random forest model which comprises an ensemble of trees.', '3.', 'To make a regression prediction at a new point, take the arithmetic average of the response of each tree in the random forest.', 'The following equation summarizes the process described by 1 and 2 above: \n \nM\nRF\n=createModel(\nX,Y\nt\n,‘RF\n’), \n where subscript tin Y\nt \nhighlights that the response matrix corresponds to the ground-truth.', 'Given a model M\nRF\n, and data predictor matrix from the nth well, prediction of the desired formation property is given below (as described in 3 above): \n \nY\np\nn\n=predict(\nM\nRF\n,X\nn\n).', 'Both Y and X contain the same types of variables, in the model building and prediction portions.', 'Assessment of Uncertainty in Random-Forest Regression\n \nApplied to regression problems, a random forest based model can provide a good approximation to the conditional mean of the response variable from a number of input predictor variables.', 'However, on its own, the conditional mean does not provide any assessment of the uncertainty associated with the prediction or any information about how the response variable might be expected to fluctuate around the conditional mean prediction.', 'The Quantile Regression Forest (QRF) offers a solution.', 'QRF has shown that a random forest model can be used to go beyond prediction of the conditional mean by providing more complete information about the conditional distribution of the response variable.', 'The full conditional distribution of the response variable represents a description of the uncertainty on the response variable given the predictor variables and provides information on how the expected variability of the response variable given the measured values of the predictor variables.', 'The conditional distribution can be described in terms of the conditional probability density function (CPDF) or its integral, the conditional cumulative distribution function (CCDF).', 'The conditional mean is just the first moment of the CPDF.', 'The second moment or conditional variance may be taken as a measure of the uncertainty on the response variable but is not a useful description of uncertainty when the shape of the CPDF is not Gaussian.', 'Quantile regression techniques have been developed to address this problem by capturing the conditional distribution in a general way, without any assumptions on its shape.', 'The idea of quantile regression is to estimate the conditional quantiles of the distribution, and quantile regression can be performed in the context of random forests.', 'The idea is that whereas random forests store the mean of the observations that fall in each node of each tree, quantile regression forests store the values of each of the observations that fall in each node of each tree.', 'Storing this extra information enables the estimation of features of the conditional distribution, such as conditional quantiles, and thereby goes beyond prediction of the conditional mean alone to a full non-parametric estimation of the conditional distribution.', 'Conditional Distribution\n \nQuantile regression forests address the problem of uncertainty assessment by estimating conditional quantiles.', 'To describe the full conditional distribution, the systems and methods disclosed herein use a discretized approach by specifying a number of quantiles equally distributed across the range of probabilities between 0 to 100%.', 'For each new prediction of the response variable, the conditional quantiles are computed from the quantile regression forest resulting in a discretized CCDF where regularly sampled probability values map to their corresponding irregularly sampled quantile values.', 'Assuming a fine enough discretization, linear interpolation enables the rapid calculation of the CCDF at any value of the response variable.', 'For display purposes, it may be useful to resample the CCDF on to a regular grid of response values so that multiple CCDFs, each sharing the same sampling of response values and corresponding to predictions made at different measured depths in a well, can be displayed as an image in a well log display.', 'Such a display enables the petrophysicist to visualize the variations in the character of response variable conditional distribution along the well track.', 'A discretized CPDF can be easily computed from the CCDF by differencing.', 'The discretized CPDF can be used to quantify the reduction in uncertainty that occurs when predicting the response.', 'By way of illustration, consider the case of predicting water saturation—before the predictor measurements are accounted for, our knowledge of the water saturation may be represented by a uniform distribution between 0% and 100% saturation.', 'This uniform prior distribution expresses complete lack of knowledge of the true value of saturation since the values have equal probability.', 'After accounting for our predictor measurements, the conditional distribution from the quantile regression forest represents the posterior distribution of water saturation.', 'The change between the prior and posterior distribution can be summarized using a concept from information theory called Kullback-Leibler divergence, also called the information gain or relative entropy, which provides a measure of the distance between the uniform prior distribution and the posterior.', 'Using this approach to an uncertainty assessment may lead to results can be easily displayed in a standard well log display as a single log curve.', 'Prediction Intervals\n \nQuantile regression forests can also be used to compute prediction intervals that address the question of how reliable is a new prediction of the response variable.', 'Prediction intervals are closely related to the conditional distribution, for example, a 95% prediction interval is the interval between the 2.5% and 97.5% quantiles of the conditional distribution and defines an interval which should contain the response with high probability.', 'The width of the prediction interval may vary considerably as a function of the values of the predictor variables.', 'Wider prediction intervals indicate increase uncertainty on the response.', 'The definition of the prediction interval can be made by the user, another common choice is the 50% prediction between the 25% and 75% quartiles which is called the inter-quartile range (IQR).', 'The prediction interval approach may improve the uncertainty assessment because the results can be easily displayed in a standard well log display as an interval between two curves defining the upper and lower quantiles.', 'The width of the prediction interval can also be displayed as a single log curve that is simple summary of the uncertainty of the prediction since wider (narrower) prediction intervals correspond to more (less) uncertain predictions.', 'In contrast, the full conditional distribution is more difficult to display and also perhaps more difficult for the petrophysicist to interpret.', 'Uncertainty Assessment Algorithm\n \nA sample algorithm for the computation of variables used in uncertainty assessment is given below in pseudo-code: \n \n \n \n1.', 'The user selects a well on which to predict the response variable of interest.', '2.', 'A pre-existing Quantile Regression Forest (QRF) model is selected from a library or a new QRF model is created from a training dataset.', '3.', 'A regularly sampled vector of probability values (between 0 and 100%) is defined to provide the basis for calculating the discretized conditional distribution.', 'There is a reasonable default, for example intervals of 5% between 0% and 100%.', '4.', 'The user defines the prediction interval of interest by selecting the upper and lower quantiles.', 'For example, the 2.5% and 97.5% quantiles define the 95% prediction interval.', '5.', 'For each measured depth sample in the well of interest:\n \n5.1.', 'predict the quantiles for the discretized CCDF using the QRF model\n \n5.2.', 'interpolate the discretized CCDF to a regular sampling of the response variable\n \n5.3.', 'compute the CPDF by differencing the CCDF derived above\n \n5.4.', 'compute the Information Gain, a measure of the distance between the CPDF and a reference uniform prior distribution\n \n6.', 'For each measured depth sample in the well of interest:\n \n6.1. predict the quantiles for the prediction interval using the QRF model\n \n6.2.', 'compute the prediction interval width\n \n7.', 'Display the CPDF and CCDF as an image in a log track display\n \n8.', 'Display the Information Gain as a log curve in a log track display\n \n9.', 'Display the prediction interval and the prediction interval width as log curves in a log track display\n \n \n \n \n \nPetrophysical Novelty Detection', 'The process of petrophysical novelty detection includes two parts: (a) the description of a high-dimensional training set of well logs representing the normal or expected range of measurements and (b) the detection of anomalous measurements that are unexpected or novel with respect to the training set.', 'The measurements may be due to valid measurements of formation properties that are not represented in the training set, or they may be caused by errors due to tool failures or bad hole conditions.', 'Conversely, the absence of detections when testing measurements from a new well indicates that the measurements are consistent with formation properties already known.', 'One-Class Support Vector Machine\n \nA classification algorithm called the Support Vector Machine (SVM) may be used where the idea of the algorithm is to choose a small number of the training data samples (these are the so-called support vectors) to define a decision boundary which governs the classification process.', 'SVMs have proven to be popular due to their flexibility in capturing complex decision boundaries.', 'An extension to SVMs may allow the user to trace the boundary of a training data set, a problem they call domain description.', 'In this approach, the training data is treated as belonging to a single class, in contrast to normal classification problems where there may be several classes.', 'Therefore, it is known as a one-class support vector machine.', 'The parameters that control the algorithm are: \n \n \n \n1.', 'The outlier fraction, a small percentage (e.g., 5%) of the training samples can be treated as outside the decision boundary.', 'This parameter may be used to create a decision boundary that is tight around the remaining bulk of the training set.', '2.', 'A parameter that controls the number of support vectors and hence the amount of detail in the decision boundary.', 'This parameter may be used when the data distribution is not a simple cloud that can be modelled as a spheroid or ellipsoid but has a complex branches.', 'The outlier fraction is a parameter in training the one-class SVM model for outlier detection.', 'An automated procedure is used to pick the value of this parameter, as follows: \n \n \n \n1.', 'Select logs from one or more input wells;\n \n2.', 'Train a one-class support vector machine using a value of zero the outlier fraction;\n \n3.', 'Output trained model which defines the normal data footprint at zero percent outliers;\n \n4.', 'Test the entire training set against the footprint, compute the SVM score at each data point;\n \n5.', 'Compute the empirical cumulative distribution function of the SVM score at each data point;\n \n6.', 'Define a regular sampling of cumulative probability between 0 and 100% (e.g., 1%);', '7.', 'Resample the empirical cumulative distribution function of SVM scores to the regular sampling of cumulative probability defined in 6;\n \n8.', 'Compute the 2\nnd \nderivative of the resampled empirical cumulative distribution defined in 7;\n \n9.', 'Identify largest peak in the 2\nnd \nderivative subject to user specified limits on cumulative probability; and\n \n10.', 'Output the cumulative probability of the picked peak and the associated SVM score.', 'The output cumulative probability is the value for the outlier fraction parameter.', 'The term footprint is used to describe the decision boundary computed from a one-class support vector machine.', 'In practice, a well may have multiple footprints if partitioning the logs into related groups MDL, DD, WL etc.', 'A well can also have multiple footprints formed by splitting its logs by zone, facies or fluids.', 'FIGS.', '8\nA and \n8\nB\n illustrate footprints \n800\n, \n850\n computed for a single well using a one-class support vector machine on a dataset including two logs, X1 and X2.', 'The raw log measurements are plotted in \nFIG.', '8\nA\n and the footprint that describes the boundary of the data, is shown in \nFIG.', '8\nB\n as the filled region.', 'The footprint is defined by a small number of the raw data samples shown as open symbols that are called the support vectors since they effectively hold the boundary in place.', 'This particular footprint identifies a small fraction of the data samples as outlier points.', 'The outlier fraction is an input parameter to the algorithm that controls the position of the footprint.', 'Quality Control of Logs\n \nThis suggests the following workflow for log quality control with a statically trained footprint, also summarized in ALG6: \n \n \n \n1.', 'Select logs from one or more input wells\n \n2.', 'Train a one-class support vector machine\n \n3.', 'Output trained model which defines the normal data footprint\n \n4.', 'Test the entire training set against the footprint, label each sample as normal or outlier\n \n5.', 'Plot the training footprint labels in a log track display\n \n6.', 'For new test wells with the same logs available, label each sample as normal or outlier according to the previously trained footprint\n \n7.', 'Plot the test footprint labels in a log track display\n \n \n \n \n \nThe workflow above may be extended such that the number of input wells varies or the process is applied iteratively.', 'The main options are: \n \n \n \n(a) Global.', 'The wells in a project are selected in 1 above, and the label results are a global quality control where the data from each well is tested against the footprint derived from each of the wells.', '(b) Well-by-well.', 'The process is performed on a well-by-well basis with each well selected in turn in 1 above.', 'The label results are a well-by-well quality control where the data from each well is tested against the footprint derived from the same well.', '(c) Iterative (or Combined).', 'The global approach described in (a) is applied and any data labelled as outlier data is excluded from the original input to form a cleaned training dataset.', 'The cleaned training dataset is then input to the well-by-well approach described in (b) where further outliers are detected by testing the data from each well against the footprint derived from clean training data for the same well.', 'Petrophysical Similarity Analysis\n \nThe idea of the footprints computed from one-class support vector machines can be extended to analyzing the log data from multiple wells and identifying which wells are similar based on their log measurements.', 'The ability to automate this process may be used for data quality control and selecting which wells to include in a machine learning training data set.', 'Given a large number of wells, the footprint can be calculated by well using the same set of log curves.', 'In general, the amount of (multi-dimensional) overlap between two footprints is a measure of similarity between two wells.', 'FIGS.', '9\nA, \n9\nB, and \n9\nC\n illustrate the concept of comparing the amount of overlap between pairs of well footprints as a means to identify similar or dissimilar wells. \nFIG.', '9\nA\n shows that the footprints of wells 1 and 2 are very similar and almost completely overlap with some small mismatch; \nFIG.', '9\nB\n includes a comparison of wells 1 and 3 showing a degradation in similarity and less overlap; and \nFIG.', '9\nC\n shows that wells 1 and 4 have no footprint overlap.', 'As discussed in greater detail below, in order to quantify the similarity between two footprints, the user may consider the concept of Jaccard similarity, which is a measure of the similarity between two sets computed by measuring the set intersection over the set union.', 'Sets that are identical have a Jaccard similarity equal to one, whereas set that are disjoint have a similarity of zero.', 'The Jaccard similarity can be interpreted as a measure of the “petrophysical similarity” between two wells.', 'A closely related term is the Jaccard distance, which is simply one minus the Jaccard similarity.', 'This distance can be interpreted as a measure of “petrophysical distance” between two wells and is the quantity that is used to cluster groups of wells by their data footprint.', 'Rather than directly computing intersection and union of two multidimensional footprints like those shown in \nFIGS.', '', '9\nA-\n9\nC\n, the sample data themselves may be used as the basis of the calculation.', 'This avoids the problem of integrating the footprints in multi-dimensions.', 'Instead, the calculation is based on simply counting the number of samples from the first well that fall inside the footprint of the second well and vice versa.', 'Basing the distance calculation on the sample data automatically compensates for variations in the data density since mismatch between two footprints in regions where the data density is low has a smaller contribution to the overall Jaccard distance than mismatch in regions of high data density.', 'FIGS.', '10\nA and \n10\nB\n illustrate the data and footprints computed from two wells using the one-class support vector machine.', 'The footprints and data from wells 1 & 2 form the basis of the calculation of Jaccard distance.', 'The data from well 2 is tested against the footprint of well 1 by classifying (or labelling) the data samples as normal or outlier, and likewise well 1 is tested against the footprint of well 2, as illustrated in \nFIGS.', '10\nC and \n10\nD\n.', 'The data sample labelling from each case is used to calculate the Jaccard distance between wells 1 and 2 according to ALG 7.', 'Computing the distance between the pairs of wells defines a distance matrix that captures the structure of the multi well dataset.', 'The information in the distance matrix can be interpreted as a graph network where each well is a node and the elements in the matrix define the length of the edges between the nodes.', 'The distance matrix forms the basis of techniques for visualizing and clustering wells into groups that have a similar footprints.', 'Multi-dimensional scaling (MDS) of the inter-well distance matrix is a way to visualize its structure by projecting the wells into a low dimensional space, ideally two dimensional so that it can be easily visualized as a map.', 'The idea is to compute coordinates of each well such that the distances between the wells in this new coordinate system approximates the inter-well distances in the matrix.', 'There are several ways to cluster wells based on the distance matrix.', 'Hierarchical Agglomerative Clustering (HAC) produces a tree-like representation of the inter-well distances in which clusters at a given level in the hierarchy are formed by merging clusters at the next level down.', 'The clusters chosen for merging are the pair that are most similar.', 'At the lowest level, each cluster contains a single well.', 'At the highest, there is a single cluster containing each of the wells.', 'Spectral clustering (SC) is another method for clustering the distance matrix that splits the distance graph into clusters such that wells (or nodes) which are near are assigned to same cluster and those that are far are assigned to different clusters.', 'This suggests the following workflow for identifying groups of wells that share the same patterns of log measurements: \n \n \n \n1.', 'Input a number of wells and select the log curves to be used for analysis.', '2. Compute the footprint of each well in turn by training a one-class support vector machine on its input logs.', '3.', 'For each possible pair of wells, compute the sample-wise Jaccard distance (equal to one minus the Jaccard similarity) by testing the footprint of the first well with the sample data of the second and vice versa.\n \n4.', 'Store the Jaccard distance between each pair of wells in a distance matrix.', '5. Compute the Multi-Dimensional Scaling (MDS) of the inter-well distance matrix.', '6.', 'Compute a clustering of the inter-well distance matrix.', 'Various methods can be employed to perform the clustering, including Hierarchical Agglomerative Clustering (HAC) and Spectral Clustering (SC).', '7. Use the results from 5 & 6 to visualize the structure of the inter-well distance matrix: \n \na.', 'Two of the coordinates from the MDS can be used to create a pseudo map view where the plotted distances between the wells approximate the distances in the inter-well distance matrix.', 'Wells which plot close together have similar log footprints.\n \nb.', 'The clustering results from the HAC can be used to define a dendrogram view of the inter-well distance matrix where the branching structure defines multiple clusters of similar wells.', 'Setting a distance threshold defines a cluster label for each well.', 'Wells which are assigned the same label have similar log footprints.', 'c. Cluster labelling derived from methods such as HAC and SC can be displayed in a standard map form in order to visualize spatial relationships in the cluster assignments and to answer questions such as: “Do wells that belong to the same clusters also cluster together spatially?” or “Does the well clustering reveal any links to the underlying geology?”.', 'ALG12 is an abstraction of the workflow to compute the inter-well distance matrix as described in 1 to 4 above.', 'FIGS.', '11\nA, \n11\nB, and \n11\nC\n illustrates the complete workflow.', 'An inter-well distance matrix for 6 wells is shown in \nFIG.', '11\nA\n representing the petrophysical distances between pairs of wells based on their openhole logs.', 'A diagnostic plot for MDS in \nFIG.', '11\nB\n shows that the inter-well distances can be approximately reproduced using the first two MDS coordinates.', 'In \nFIG.', '11\nC\n, the wells are plotted according to the first two MDS coordinates giving a pseudo map display where similar wells plot close together and dissimilar wells plot far apart.', 'The arrangement of wells in \nFIG.', '11\nC\n shows that 3 wells which are very similar can be grouped together to form cluster 1.', 'A further 2 wells can be grouped to form cluster 2 whereas the remaining well is far from the others and is probably an outlier.', 'Algorithm Definitions\n \nIn this section, pseudo code is provided for the various algorithms.', 'A specific algorithm is referred to by its algorithm number (such as ALG1 for the ComputePredictionError algorithm), rather than its full name for ease of use.', 'ALG1: ComputePredictionErrorRF\n \n \n \n[bias, MAE, MSE, RMSE] = ComputePredictionErrorRF\n \n \n \n(X\ntrain\n, Y\ntrain\n, X\ntest\n, Y\ntest\n)\n \n \n \n\u2003M\nRF \n= createModel(X\ntrain\n, Y\ntrain\n, ‘RF’)', 'Y\np\ntest \n= predict(M\nRF\n, X\ntest\n)\n \n \n \n\u2003E = Y\np\ntest \n− Y\ntest\n \n \n \nbias = sum(E)/length(E)', 'MAE = sum(abs(E))/length(E)\n \n \n \nMSE = sum(trans(E) *', 'E)/length(E)\n \n \n \nRMSE = sqrt(sum(trans(E) * E))/length(E)\n \n \n \nALG2:', 'LOOWCVRF\n \n \n \n[errorSummary] = LOOWCVRF(X\nW \n, Y\nW\n)\n \n \n \nW = setOfWells(X\nW\n)\n \n \n \nfor each k in W\n \n \n \nS = W − {k}\n \n \n \nerrorSummary(k) = ComputePredictionErrorRF(X\nS\n, Y\nS\n, X\nk\n, Y\nk\n)\n \n \n \nALG3: LOOLCVRF\n \n \n \n[errorSummary] = LOOLCVRF(X\nW\n)\n \n \n \n\u2003J = setOfColumns(X\nW\n)\n \n \n \nfor each j in J\n \n \n \nS = J − {j}\n \n \n \nerrorSummary(j)', '= ComputePredictionErrorRF(X\nS\n, X\nj\n, X\nS\n, X\nj\n)', 'ALG4: LOOWOLCVRF\n \n \n \n[errorSummary] = LOOWOLCVRF(X\nW\n)\n \n \n \nW = setOfWells(X\nW\n)\n \n \n \n\u2003J = setOfColumns(X\nW\n)\n \n \n \nfor each k in W\n \n \n \nS = W − {k}\n \n \n \nfor each j in J\n \n \n \nL = J − {j}\n \n \n \nerrorSummary(k, j) = ComputerPredictionErrorRF(X\nL\nS\n, X\nj\nS\n, X\nL\nk\n, X\nj\nk\n).', 'ALG5: GetOutlierClassification\n \n \n \n[C\ntest\n] = GetOutlierClassification (X\ntrain\n, X\ntest\n, outLierFraction) {M\nSVM \n=\n \n \n \ncreateModel(X\ntrain\n, ‘SVM’, outLierFraction)\n \n \n \n\u2003Y\nd\ntest \n= predict(M\nSVM\n, X\ntest\n)\n \n \n \n\u2003C\ntest \n= classify(Y\nd\ntest\n)\n \n \n \nALG6: FindOutliers\n \n \n \n[fractionOut] = FindOutliers (X\nW\n, outlierFraction)\n \n \n \n\u2003C\nW \n= getOutlierClassification(X\nW\n, X\nW\n, outlierFraction)\n \n \n \n \n \n \n \n \n \n \n \nfractionIn\n \n=\n \n \n \nsum\n \n(\n \n \nC\n \nW\n \n \n)\n \n \n \nlength\n \n(\n \n \nC\n \nW\n \n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n\u2003fractionOut = 1 − fractionIn\n \n \n \nlogView(X\nW\n, C\nW\n).', 'ALG7: ComputeJaccardDistance\n \n \n \n[d] = ComputeJaccardDistance(X\n1\n, X\n2\n, outlierFraction)\n \n \n \n\u2003M\nSVM\n1 \n= createModel(X\n1\n, ‘SVM’, outlierFraction)\n \n \n \n\u2003M\nSVM\n2 \n= createModel(X\n2\n, ‘SVM’, outlierFraction)\n \n \n \n\u2003D\n21 \n= predict(M\nSVM\n2\n, X\n1\n)\n \n \n \n\u2003D\n12 \n= predict(M\nSVM\n1\n, X\n2\n)\n \n \n \n\u2003D\n22 \n= predict(M\nSVM\n2\n, X\n2\n)\n \n \n \n\u2003C\n21 \n= classify(D\n21\n)\n \n \n \n\u2003C\n12 \n= classify(D\n12\n)\n \n \n \n\u2003C\n22 \n= classify(D\n22\n)\n \n \n \n \n \n \n \n\u2003 \n \n \n \nd\n \n=\n \n \n1\n \n-\n \n \n(\n \n \n \n \nsum\n \n(\n \n \nC\n \n \n2\n \n\u2062\n \n1\n \n \n \n)\n \n \n+\n \n \nsum\n \n(\n \n \nC\n \n \n1\n \n\u2062\n \n2\n \n \n \n)\n \n \n \n \n \nsum\n \n(\n \n \nC\n \n \n2\n \n\u2062\n \n1\n \n \n \n)\n \n \n+\n \n \nsum\n \n(\n \n \nC\n \n \n1\n \n\u2062\n \n2\n \n \n \n)\n \n \n+\n \n \nsum\n \n(\n \n \nC\n \n \n2\n \n\u2062\n \n2\n \n \n \n)\n \n \n \n \n)', 'ALG8: LOOWCVSVM', '[fracOut] = LOOWCVSVM(X\nW\n, outLierFraction)\n \n \n \nW = setOfWells(X\nW\n)\n \n \n \nfor each k in W\n \n \n \nS = W − {k}\n \n \n \nC\nk \n= getOutlierClassification(X\nS\n, X\nk\n, outlierFraction)\n \n \n \n \n \n \n \n \n \n \n \n \nfracOut\n \n(\n \nk\n \n)\n \n \n=\n \n \n1\n \n-\n \n \n(\n \n \n \nsum\n \n(\n \n \nC\n \nk\n \n \n)\n \n \n \nlength\n \n(\n \n \nC\n \nk\n \n \n)\n \n \n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \nALG9: LOOLCVSVM\n \n \n \n[fracOut] = LOOLCVSVM(X\nW\n, outLierFraction)', 'J = setOfColumns(X\nW\n)\n \n \n \nfor each j in J\n \n \n \nS = J − {j}\n \n \n \nC\nj \n= getOutlierClassification(X\nS\n, X\nS\n, outlierFraction)\n \n \n \n \n \n \n \n \n \n \n \n \nfracOut\n \n(\n \nj\n \n)\n \n \n=\n \n \n1\n \n-\n \n \n(\n \n \n \nsum\n \n(\n \n \nC\n \nj\n \n \n)\n \n \n \nlength\n \n(\n \n \nC\n \nj\n \n \n)\n \n \n \n)', 'ALG10: LOOWOLCVSVM\n \n \n \n[fracOut] = LOOWOLCVSVM(X\nW\n, outLierFraction)', 'W = setOfWells(X\nW\n)\n \n \n \n\u2003J = setOfColumns(X\nW\n)\n \n \n \nfor each k in W {\n \n \n \nS = W − {k}\n \n \n \nfor each j in J\n \n \n \nL = J − {j}\n \n \n \nC = getOutlierClassification(X\nL\nS\n, X\nL\nk\n, outlierFraction)\n \n \n \n \n \n \n \n \n \n \n \n \nfracOut\n \n(\n \n \nk\n \n,\n \nj\n \n \n)\n \n \n=\n \n \n1\n \n-\n \n \n(\n \n \n \nsum\n \n(\n \nC\n \n)\n \n \n \nlength\n \n(\n \nC\n \n)\n \n \n \n)', 'ALG11: RankModels\n \n \n \n[sortedModelIndex] = RankModels(X\nM\n, X\nquery\n, outLierFraction)\n \n \n \nfor k in M\n \n \n \nd(k) = ComputeJaccardDistance(X\nk\n, X\nquery\n, outlierFraction)\n \n \n \n\u2003sortedModelIndex = sort(d)\n \n \n \nALG12. ComputeInterWellDistances\n \n \n \n[d] = ComputeInterWellDistances(X\nW\n, outLierFraction)\n \n \n \nfor k in W\n \n \n \nfor j in W\n \n \n \nd(k, j) = ComputeJaccardDistance(X\nk\n, X\nj\n, outlierFraction)\n \n \n \n \n \n \n \n \n \n \nPetrophysical Similarity Analysis\n \nDescription of Similarity Metrics—Jaccard Similarity\n \nJaccard similarity is a measure of the similarity between two sets computed as the size of the intersection over the size of the union.', 'Sets that are identical have a Jaccard similarity of one, whereas sets that are disjoint have a similarity of zero.', 'Rather than directly computing the intersection and union of two multi-dimensional footprints, the sample data is used as the basis of the calculation.', 'This avoids the problem of integrating the footprints in multiple dimensions.', 'Instead, the intersection calculation is based on counting the number of samples that fall inside both footprints, and the union calculation is based on counting the number of samples that fall inside either footprint.', 'Basing the similarity calculation on the sample data automatically compensates for variations in the data density because the mismatch between two footprints in regions where the data density is low has a smaller contribution to the overall Jaccard similarity than mismatch in regions of high data density.', 'Jaccard(\nA,B\n)=(size of \nA \nintersection \nB\n)/(size of \nA \nunion \nB\n) \n or: \n Jaccard(\nA,B\n)', '=(', 'number in footprint \nA \nand \nB\n)/(number', 'in footprint \nA\n+number in footprint \nB\n−number in footprint \nA \nand \nB\n)', 'By definition, Jaccard similarity is symmetric, i.e., Jaccard(A, B)=Jaccard(B,A) and has a value between one and zero.', 'Overlap Similarity\n \nJaccard similarity is not sensitive to situations where the footprint of', 'well', 'A is a subset of well B.', 'In these situations, Jaccard similarity will be less than one, even if the footprint of well', 'A is completely contained within the footprint of well B. A user may identify these situations because, in this case, well B would be a strong candidate to build a predictive model to reconstruct logs in well A. Overlap similarity provides a way to identify such overlaps.', 'Overlap(\nA,B\n)=(size of \nA \nintersection \nB\n)/min(size of \nA\n,size of \nB\n) \n or: \n Overlap(\nA,B\n)=(number in footprint \nA \nand \nB\n)/min(number', 'in footprint \nA\n,number in footprint \nB\n)', 'By definition, Overlap similarity is symmetric i.e., Overlap(A,B)=Overlap(B,A) and has a value between one and zero.', 'In contrast to Jaccard similarity, Overlap similarity is equal to one when footprint A is entirely a subset of footprint B or vice versa.', 'Overlap Indicator\n \nOn its own, the Overlap similarity does not tell a user which well footprint A or B is the subset, but it is trivial to obtain this information as the subset well is the one which is selected by the minimum in the denominator.', 'In the displays, this is shown as the subset/superset matrix.', 'To interpret this matrix, take the row of well A and read across the columns to tell if well A is a subset or a superset relative to well B in a particular column.', 'Overlap Similarity by Row\n \nIn the Overlap similarity calculation, the denominator is selected to be the smaller of A and B, and this choice identifies which footprint is the subset (smaller) and which is the superset (larger).', 'Overlap similarity by row is an extension of Overlap similarity designed to probe the degree to which footprint A is a subset of footprint B.', 'This is done by forcing the choice of footprint A in the denominator.', 'Overlap by Row(\nA,B\n)', '=(size of \nA \nintersection \nB\n)/(size of \nA\n) \n or: \n Overlap by Row(\nA,B\n)', '=(number in footprint \nA \nand \nB\n)/(number', 'in footprint \nA\n)', 'In the displays, this is shown as the Overlap by row matrix.', 'To interpret this matrix, a user may take the row of well A and read across the columns to tell the extent to which', 'well A overlaps relative to well B in a particular column.', 'Overlap by row takes a value between one and zero but is not symmetric i.e., Overlap by Row(A,B)!=Overlap by Row(B,A) and cannot be directly used in MDS etc.', 'without modifications such as averaging the lower and upper triangles.', 'One-Way Overlap Similarity by Row\n \nThe previous measures combine the data points from wells A and B into one set and use the combined set to probe the similarity between the two footprints.', 'This measure adopts a different approach of comparing the data points from well A to the footprint of well B.', 'The calculation gives the fraction of data points from', 'well', 'A that fall in the footprint of well B.\n \nOne-way Overlap by Row(A,B)=(number of well', 'A data points in footprint B)/(number of well', 'A data points).', 'In the displays, this is shown as the One-way Overlap by Row matrix.', 'To interpret this matrix, take the row of well A and read across the columns to tell the fraction of data from well A that falls in the footprint of well B in a particular column.', 'One-way Overlap by Row takes a value between one and zero but is not symmetric i.e., One-way Overlap by Row(A,B)!=One-way Overlap by Row(B,A).', 'Methods for Creating a Symmetric Similarity Matrix\n \nSimilarity metrics that are not symmetric cannot be directly used in MDS etc. without modification to force symmetry.', 'Two methods are used to do this:\n \n(a) Take the average of the elements in the lower and upper triangles, i.e., \n Average Overlap by Row(\nA,B\n)=0.5(Overlap by Row(\nA,B\n)', '+Overlap by Row(\nB,A\n)) \n \nor\n \n(b) Take the product of the elements in the lower and upper triangles, i.e., \n Product Overlap by Row(\nA,B\n)=Overlap by Row(\nA,B\n)*', 'Overlap by Row(\nB,A\n) \n \nExtending Similarity Metrics with Spatial Proximity', 'The similarity metrics described above represent the similarity of petrophysical responses between wells.', 'There is also information in the relative spatial location of the wells that may be used to weight the similarity of their petrophysical responses.', 'Two wells that are relatively close spatially should have their petrophysical similarity weighted more highly than two wells that are further apart.', 'A spatial proximity matrix is defined as a measure of proximity for each pairs of wells: \n Spatial Proximity(\nA,B\n)=\ne\n−∥x\nA\n−x\nB\n∥\n2\n/σ\n \n Where x\nA \nand x\nB \nare the spatial coordinates of wells A and B respectively, e.g., the position of the well head or the average position of the zone of interest in the subsurface when the well is deviated or is a lateral.', 'The proximity metric defined above is close to 1 when the wells are near, and close to 0 when the wells are far apart.', 'The range parameter σ controls the distance at which the proximity approaches zero.', 'There are other proximity functions that could be used in the function above, the one shown in a Gaussian function.', 'Modifications of spatial proximity are also possible to incorporate geological knowledge, e.g., proximity can be penalized when the separation vector between wells crosses a fault.', 'Spatial proximity can be combined with any of the petrophysical similarity metrics described in the previous section.', 'The combined similarity metric can be calculated by two methods as: \n \n \n \n(a) The product of the petrophysical similarity metric and spatial proximity: \n Combined Similarity(\nA,B\n)=Petrophysical Similarity(\nA,B\n)*Spatial Proximity(\nA,B\n) \n or \n \n(b) A weighted linear combination of the petrophysical similarity metric and spatial proximity, where W is the mixing weight which can be set between 0 and 1: \n Combined Similarity(\nA,B\n)=\nW\n*Petrophysical Similarity(\nA,B\n)', '+(1−\nW\n)*Spatial Proximity(\nA,B\n).', 'In case (b), the mixing weight controls the contribution of the petrophysical and spatial components in the output.', 'W=0 gives pure spatial proximity, W=1 give pure petrophysical similarity, 0<W<1 gives a blend.\n \nInterpretation of the Similarity Matrix Using the PageRank', 'Algorithm\n \nThe PageRank algorithm may be used to sort wells according their relevance in the similarity matrix, where the relevance of a well is a measure of the strength of its footprint similarity compared to the other wells.', 'The process produces a list of wells ranked by the relevance of their footprints in representing the petrophysical responses seen in the entire dataset.', 'The process includes: \n \n \n \n1.', 'Computing a symmetric similarity matrix for a number of wells using one of the metrics outlined above.', '2.', 'Running the PageRank algorithm on the similarity matrix.\n \n3.', 'Obtaining a list of the input wells ranked by relevance in the matrix.', '4.', 'Interpreting wells that are ranked at or near the top of the list as wells that exhibit the most representative petrophysical responses out of the entire dataset, and interpreting wells that are ranked near the bottom of the list as exhibiting anomalous petrophysical responses.\n \n \n \n \n \nFIG.', '12\n illustrates a flowchart of a method \n1200\n for predicting a formation property, according to an embodiment.', 'The method \n1200\n may include receiving well log data for one or more (e.g., a plurality of) wells, as at \n1202\n.', 'The well log data may be captured by a downhole tool (e.g., a wireline tool, a logging-while-drilling (LWD) tool, or a measurement-while-drilling (MWD) tool).', 'In another embodiment, the well log data may be captured at the surface by analyzing mud logs, drilling data, cuttings, and/or core data.', 'The well log data may include gamma ray measurements, density measurements, neutron logs, core data, and the like.', 'The well log data may be captured and/or received in real-time.', 'The method \n1200\n may also include generating a flag, as at \n1204\n.', 'The flag may be generated using the well log data.', 'The flag is a variable with a binary value (e.g., either 0 or 1).', 'The flag may be an outlier flag or an inlier flag.', 'If the flag is an outlier flag, a 1 represents an outlier, and a 0 represents an inlier.', 'If the flag is an inlier flag, a 1 represents an inlier, and a 0 represents an outlier.', 'An outlier flag indicates a valid measurement of formation properties that is not represented in a training set, or a measurement that is in error due to tool failures or bad wellbore conditions.', 'An inlier flag is the complement of the outlier flag.', 'The outlier flag may be generated using a one-class unsupervised support vector machine (SVM) model.', 'The SVM model may be generated using an outlier fraction that is user-supplied or automated.', 'The SVM model may be generated on a well-by-well basis, a global basis, or both, as described above.', 'The method \n200\n may also include sorting the wells into groups, as at \n1206\n.', 'The wells may be sorted based on the well log data and/or the flag.', 'The wells may be sorted into groups using a petrophysical similarity analysis.', 'The petrophysical similarity analysis may include computing a similarity matrix using the well log data and/or the flag.', 'The similarity metrics used in the similarity analysis may include Jaccard, overlap, etc., as described in greater detail above.', 'The results from the similarity analysis may be visualized.', 'The wells may be sorted into groups on a well-by-well basis (e.g., using one or more of the similarity metrics).', 'In another embodiment, the wells may be sorted into groups using dimension reduction via multi-dimensional scaling (MDS).', 'This may be done by applying clustering to the results of the MDS, and the results of the MDS (e.g., one or more matrices) may be visualized.', 'In yet another embodiment, the wells may be sorted into groups using a combined metric utilizing spatial well proximity.', 'The method \n1200\n may also include building a model for each of the wells, as at \n1208\n.', 'The model may be built using the well log data, the flag, and/or the groups.', 'Once built, the model(s) may be added to a library of models.', 'The model(s) may be updated when additional ground truth becomes available.', 'In at least one embodiment, the library may be searched for a model that corresponds to one or more of the wells, and, if the model is not found in the library, then the model may be built.', 'The method \n1200\n may also include predicting a formation property, as at \n1210\n.', 'The formation property may be predicted using the well log data and/or the model(s) (e.g., the built model, the models in the library, or both).', 'The formation property may be or include water saturation, porosity, permeability, compressional slowness, and the like.', 'In at least one embodiment, the well log data used to predict the formation property may be or include mud log data, drilling data, and gamma ray data.', 'The method \n1200\n may also include determining an uncertainty of the predicted formation property, as at \n1212\n.', 'The uncertainty may be predicted using one or more prediction intervals from the Quantile Regression Forest (QRF).', 'The method \n1200\n may also include performing a physical action, as at \n1214\n.', 'The physical action may be performed (e.g., automatically) in response to the formation property and/or the uncertainty.', 'The physical action may include identifying/selecting an additional well to be interpreted manually by a human, reviewing a logging program, changing a drilling plan for a well (e.g., steering to change the trajectory), varying properties of fluid (e.g., mud) being pumped into a well, actuating a valve, or the like.', 'In at least one embodiment, predicted formation property and/or the uncertainty may then result in a notification to a user that instructs the user to analyze one of the wells in more detail (e.g., manually).', 'FIG.', '13\n illustrates a schematic view of a computing system \n1300\n, according to an embodiment.', 'The computing system \n1300\n may include a computer or computer system \n1301\nA, which may be an individual computer system \n1301\nA or an arrangement of distributed computer systems.', 'The computer system \n1301\nA includes one or more analysis module(s) \n1302\n configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein.', 'To perform these various tasks, the analysis module \n1302\n executes independently, or in coordination with, one or more processors \n1304\n, which is (or are) connected to one or more storage media \n1306\n.', 'The processor(s) \n1304\n is (or are) also connected to a network interface \n1307\n to allow the computer system \n1301\nA to communicate over a data network \n1309\n with one or more additional computer systems and/or computing systems, such as \n1301\nB, \n1301\nC, and/or \n1301\nD (note that computer systems \n1301\nB, \n1301\nC and/or \n1301\nD may or may not share the same architecture as computer system \n1301\nA, and may be located in different physical locations, e.g., computer systems \n1301\nA and \n1301\nB may be located in a processing facility, while in communication with one or more computer systems such as \n1301\nC and/or \n1301\nD that are located in one or more data centers, and/or located in varying countries on different continents).', 'A processor can include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'The storage media \n1306\n can be implemented as one or more computer-readable or machine-readable storage media.', 'Note that while in the example embodiment of \nFIG.', '13\n storage media \n1306\n is depicted as within computer system \n1301\nA, in some embodiments, storage media \n1306\n may be distributed within and/or across multiple internal and/or external enclosures of computing system \n1301\nA and/or additional computing systems.', 'Storage media \n1306\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLU-RAY® disks, or other types of optical storage, or other types of storage devices.', 'Note that the instructions discussed above can be provided on one computer-readable or machine-readable storage medium, or can be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture).', 'An article or article of manufacture can refer to any manufactured single component or multiple components.', 'The storage medium or media can be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions can be downloaded over a network for execution.', 'In some embodiments, computing system \n1300\n contains one or more formation property prediction module(s) \n1308\n.', 'In some embodiments, a single formation property prediction module \n1308\n may be used to perform at least some aspects of one or more embodiments of the methods.', 'In other embodiments, a plurality of formation property prediction modules \n1308\n may be used to perform at least some aspects of the methods.', 'It should be appreciated that computing system \n1300\n is one example of a computing system, and that computing system \n1300\n may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of \nFIG.', '13\n, and/or computing system \n1300\n may have a different configuration or arrangement of the components depicted in \nFIG. \n13\n.', 'The various components shown in \nFIG.', '13\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices.', 'These modules, combinations of these modules, and/or their combination with general hardware are included within the scope of protection of the invention.', 'The foregoing description, for purpose of explanation, has been described with reference to specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or to limit the invention to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'Moreover, the order in which the elements of the methods are illustrated and described may be re-arranged, and/or two or more elements may occur simultaneously.', 'The embodiments were chosen and described in order to best explain the principals of the invention and its practical applications, to thereby enable others skilled in the art to best utilize the invention and various embodiments with various modifications as are suited to the particular use contemplated.']

['1.', 'A method, comprising:\nreceiving well log data for a first well;\ngenerating a first footprint defining a decision boundary for the first well using a support vector machine, at least some of the well log data is outside of the first footprint and at least some of the well log data is within the first footprint;\ncomparing the first footprint to a second footprint generated using a model representing one or more second wells, the model is configured to predict a formation property based at least in part on well log data for the one or more second wells;\ndetermining that the first well is similar to the one or more second wells based on the comparing;\npredicting the formation property of the first well using the model, based at least partially on the well log data; and\nupdating the model based at least partially on the well log data from the first well, in response to determining that the first well is similar to the one or more second wells.', '2.', 'The method of claim 1, further comprising capturing the well log data downhole using a downhole tool that is positioned in the first well.', '3.', 'The method of claim 1, further comprising capturing the well log data at the surface of the first well.', '4.', 'The method of claim 1, wherein the well log data comprises a gamma ray measurement, mud log data, and drilling data, and wherein the formation property comprises water saturation and total porosity.', '5.', 'The method of claim 1, further comprising determining an uncertainty of the formation property using one or more prediction intervals from a quantile regression forest algorithm.', '6.', 'The method of claim 5, further comprising performing a physical action in response to determining the formation property, the uncertainty of the formation property, or both.\n\n\n\n\n\n\n7.', 'The method of claim 6, wherein the physical action is selected from the group consisting of: selecting an additional well to be interpreted manually, changing a trajectory of one of the wells, and varying a property of a fluid being pumped into one of the wells.\n\n\n\n\n\n\n8.', 'The method of claim 1, further comprising generating a flag based at least partially on the well log data, wherein the flag comprises a binary value, wherein the flag indicates whether a sample in the well log data comprises an error.', '9.', 'The method of claim 1, wherein the support vector machine is a one-class support vector machine model, wherein the decision boundary is defined by a first portion of samples in the well log data.', '10.', 'The method of claim 9, wherein the decision boundary extends through the first portion of the samples and encompasses a second portion of the samples in the well log data, and wherein a third portion of the samples in the well log data are outside of the decision boundary.', '11.', 'The method of claim 10, wherein the third portion of the samples comprises an outlier fraction of the samples, and wherein the decision boundary is generated based at least partially upon the outlier fraction.', '12.', 'The method of claim 9, wherein the decision boundary comprises a plurality of decision boundaries corresponding to different zones, facies, fluids, or a combination thereof associated with the first well.', '13.', 'The method of claim 1, wherein comparing includes at least one of:\ndetermining an amount of overlap of the first and second footprints; or\ncounting a number of samples of the well log data associated with the first well that are within the second footprint and a number of samples of well log data associated with the second well that are within the first footprint.', '14.', 'The method of claim 1, further comprising:\nobtaining a base-base error vector for the model before updating the model;\ncreating a new well domain by adding the well log data for the first well to the model;\nobtaining a new error vector for the model based on the new well domain; and\ndetermining that the new error vector is below a threshold.', '15.', 'A computing system comprising:\none or more processors; and\na memory system comprising one or more non-transitory computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations, the operations comprising: receiving well log data for a plurality of wells; generating a flag based at least partially on the well log data, wherein the flag comprises a binary value; sorting the wells into groups based at least partially on the well log data, the flag, or both; building one or more models for the wells based at least partially on the well log data, the flag, and the groups, building the one or more models includes: generating a first footprint defining a decision boundary for a first well of the plurality of wells using a support vector machine model, at least some of the well log data associated with the first well is outside of the first footprint and at least some of the well log data associated with the first well is within the first footprint; comparing the first footprint to a second footprint generated using the model representing one or more second wells, the model is configured to predict one or more formation parameters based at least in part on well log data; determining that the first well is similar to the one or more second wells based on the comparing; and updating the model representing the one or more second wells based at least partially on the well log data from the first well, in response to determining that the first well is similar to the one or more second wells; predicting a formation property based at least partially upon the well log data and the one or more models; determining an uncertainty of the formation property using one or more prediction intervals from a quantile regression forest algorithm; and identifying a physical action to be performed in response to the formation property, the uncertainty of the formation property, or both.\n\n\n\n\n\n\n16.', 'The computing system of claim 15, wherein the flag comprises an outlier flag that is generated using the support vector machine model, the support vector machine model being a one-class unsupervised support vector machine model.', '17.', 'The computing system of claim 16, wherein the one-class unsupervised support vector machine model is generated using an outlier fraction that is user-supplied or automated.', '18.', 'The computing system of claim 16, wherein the one-class unsupervised support vector machine model is generated on a well-by-well basis, a global basis, or both.\n\n\n\n\n\n\n19.', 'The computing system of claim 15, wherein the wells are sorted into the groups using a petrophysical similarity analysis that includes determining a similarity matrix using the well log data, the flag, or both.\n\n\n\n\n\n\n20.', 'The computing system of claim 15, wherein the wells are sorted into the groups on a well-by-well basis using one or more similarity metrics selected from the group consisting of Jaccard similarity, overlap similarity, overlap indicator, overlap similarity by row, one-way similarity by row, and a symmetric similarity matrix.\n\n\n\n\n\n\n21.', 'The computing system of claim 15, wherein the wells are sorted into the groups using dimension reduction via multi-dimensional scaling, by applying clustering to results of the multi-dimensional scaling.', '22.', 'The computing system of claim 15, wherein the wells are sorted into the groups using a combined metric utilizing spatial well proximity.\n\n\n\n\n\n\n23.', 'The computing system of claim 15, further comprising:\nadding the one or more models to a library after the one or more models are built; and\nupdating the one or more models in the library when additional ground truth becomes available.', '24.', 'The computing system of claim 15, wherein the formation property is selected from the group consisting of water saturation, porosity, permeability, and compressional slowness.', '25.', 'The computing system of claim 15, further comprising searching a library of models for the one or more models, and if the one or more models are not present in the library, then building the one or more models for the wells based at least partially on the well log data, the flag, and the groups.', '26.', 'A non-transitory computer-readable medium storing instructions that, when executed by at least one processor of a computing system, cause the computing system to perform operations, the operations comprising:\nreceiving well log data for a plurality of wells, wherein the well log data is selected from the group consisting of gamma ray measurements, density measurements, neutron logs, and core data;\ngenerating a flag based at least partially on the well log data, wherein the flag comprises a binary value that identifies whether a sample in the well log data is an outlier or an inlier, wherein the flag is generated using a one-class unsupervised support vector machine model, and wherein the one-class unsupervised support vector machine model is generated on a well-by-well basis, a global basis, or both using an outlier fraction that is user-supplied or automated;\nsorting the wells into groups based at least partially on the well log data, the flag, or both;\nbuilding a model for each of the wells based at least partially on the well log data, the flag, and the groups;\nadding the models to a library after the models are built;\nupdating the models in the library when additional ground truth becomes available updating the models includes: generating a first footprint defining a decision boundary for a first well of the plurality of wells using a support vector machine model, at least some of the well log data associated with the first well is outside of the first footprint and at least some of the well log data associated with the first well is within the first footprint; comparing the first footprint to a second footprint generated using the model representing one or more second wells, the model is configured to predict one or more formation parameters based at least in part on well log data; determining that the first well is similar to the one or more second wells based on the comparing; and updating the model based at least partially on the well log data from the first well, in response to determining that the first well is similar to the one or more second wells;\npredicting a formation property based at least partially upon the well log data and the models, wherein the formation property is selected from the group consisting of water saturation, porosity, permeability, and compressional slowness;\ndetermining an uncertainty of the formation property using one or more prediction intervals from a quantile regression forest algorithm; and\nidentifying a physical action to be performed in response to the formation property, the uncertainty of the formation property, or both, wherein the physical action is selected from the group consisting of selecting an additional well to be interpreted manually, changing a trajectory of one of the wells, and varying a property of a fluid being pumped into one of the wells.']

['FIG. 1 illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.; FIG.', '2 illustrates a schematic view of an interpretation workflow, according to an embodiment.;', 'FIG.', '3A illustrates a schematic view of model building and prediction, according to an embodiment.;', 'FIG.', '3B illustrates graphs showing water saturation (Sw) prediction, according to an embodiment.; FIG.', '3C illustrates graphs showing total porosity (PHIT) prediction, according to an embodiment.; FIG.', '4 illustrates a graph showing the prediction of compressional acoustic slowness, from a set of MGL+DD+GR, according to an embodiment.; FIG.', '5 illustrates graphs showing the impact of inaccurate interpretation in establishing the ground truth, according to an embodiment.; FIG.', '6A illustrates graphs showing the assessment of uncertainty of a first well with higher uncertainty, according to an embodiment.;', 'FIG.', '6B illustrates graphs showing the assessment of uncertainty of a second well with lower uncertainty, according to an embodiment.;', 'FIG.', '7A illustrates a graph showing an inaccurate interpretation for ground truth, according to an embodiment.;', 'FIG.', '7B illustrates a graph showing an accurate interpretation for ground truth, according to an embodiment.;', 'FIG.', '8A illustrates a graph showing petrophysical detection using raw data, according to an embodiment.;', 'FIG.', '8B illustrates a graph showing petrophysical detection using footprints, support vectors, and outliers, according to an embodiment.;', 'FIG.', '9A illustrates a graph showing a strong footprint overlap, according to an embodiment.;', 'FIG.', '9B illustrates a graph showing a partial footprint overlap, according to an embodiment.;', 'FIG.', '9C illustrates a graph showing no footprint overlap, according to an embodiment.; FIG.', '10A illustrates a graph showing well 1 data, footprints, and outliers, according to an embodiment.; FIG.', '10B illustrates a graph showing well 2 data, footprints, and outliers, according to an embodiment.; FIG.', '10C illustrates a graph showing the well 1 footprint versus the well 2 data, according to an embodiment.; FIG.', '10D illustrates a graph showing the well 2 footprint versus the well 1 data, according to an embodiment.; FIG.', '11A illustrates a graph showing an inter-well distance matrix, according to an embodiment.; FIG.', '11B illustrates a graph showing scaled eigenvalues of inter-well distances, according to an embodiment.; FIG.', '11C illustrates a graph showing a 2D reconstruction of inter-well distances, according to an embodiment.; FIG.', '12 illustrates a flowchart of a method for predicting a formation property, according to an embodiment.; FIG.', '13 illustrates a schematic view of a computing system, according to an embodiment.; FIG.', '1 illustrates an example of a system 100 that includes various management components 110 to manage various aspects of a geologic environment 150 (e.g., an environment that includes a sedimentary basin, a reservoir 151, one or more faults 153-1, one or more geobodies 153-2, etc.).', 'For example, the management components 110 may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 150.', 'In turn, further information about the geologic environment 150 may become available as feedback 160 (e.g., optionally as input to one or more of the management components 110).; FIG.', '1 also shows an example of a framework 170 that includes a model simulation layer 180 along with a framework services layer 190, a framework core layer 195 and a modules layer 175.', 'The framework 170 may include the commercially available OCEAN® framework where the model simulation layer 180 is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.; FIG. 1 also shows the geologic environment 150 as optionally including equipment 157 and 158 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 159.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 157 and/or 158 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG.', '3A illustrates the model building and prediction.', 'The top row is for training, and the bottom row is for prediction.', 'In this specific example, the input data are MGL+DD+GR, and the ground truth is either Sw or PHIT.; FIG.', '3C shows the case for PHIT.', 'The curves in the left track 332 of FIG.', '3C correspond to GR (shown for reference).', 'The curves in the right track 334 of FIG.', '3C correspond to the ground truth and predicted properties (e.g., total porosity).', 'The Random Forest model was trained from two wells, where the ground truth was obtained from ELAN.', 'The agreement between the two curves is strong, indicating WL quality.; FIG.', '4 shows a graph 400 characterizing the prediction of compressional acoustic slowness, from a set of MGL+DD+GR.', 'One curve is the ground truth for the test well.', 'The other curve is the ML prediction.', 'The predicted log mimics the ground truth quite well, with low bias and variance.', 'In case of a bad sonic log, the ML prediction may be used for further interpretation, such as the computation of acoustic impedance for seismic-log ties.', 'In another embodiment, the user can predict sonic logs in near real-time from MGL+DD+GR, and use it for the assessment of geomechanical properties, before WL logs are run.', 'In the case of LWD logging, the compressional slowness may be provided by the ML process, in case an acoustic LWD log were not available.; FIGS.', '6A and 6B illustrate graphs showing the uncertainty, in the form of PI.', 'FIG.', '6A includes four tracks 610, 620, 630, 640, and FIG.', '6B includes four tracks 660, 670, 680, 690.', 'The first tracks 610, 660 represent caliper vs. bit size.', 'The shading indicates washouts, which are severe in this example.', 'The second tracks 620, 670 represent GR.', 'Shading indicates reservoir.', 'The third tracks 630, 680 represent water saturation and ground truth vs. prediction.', 'One curve is the ground truth for Sw obtained from logs.', 'Another curve is the prediction from the ML algorithm.', 'The fourth tracks 640, 690 represent uncertainty for Sw.', 'The curve is the same predicted Sw curve from ML.', 'The left and right boundaries correspond to +/−25% confidence bands around the predicted value.; FIG.', '12 illustrates a flowchart of a method 1200 for predicting a formation property, according to an embodiment.', 'The method 1200 may include receiving well log data for one or more (e.g., a plurality of) wells, as at 1202.', 'The well log data may be captured by a downhole tool (e.g., a wireline tool, a logging-while-drilling (LWD) tool, or a measurement-while-drilling (MWD) tool).', 'In another embodiment, the well log data may be captured at the surface by analyzing mud logs, drilling data, cuttings, and/or core data.', 'The well log data may include gamma ray measurements, density measurements, neutron logs, core data, and the like.', 'The well log data may be captured and/or received in real-time.', '; FIG.', '13 illustrates a schematic view of a computing system 1300, according to an embodiment.', 'The computing system 1300 may include a computer or computer system 1301A, which may be an individual computer system 1301A or an arrangement of distributed computer systems.', 'The computer system 1301A includes one or more analysis module(s) 1302 configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein.', 'To perform these various tasks, the analysis module 1302 executes independently, or in coordination with, one or more processors 1304, which is (or are) connected to one or more storage media 1306.', 'The processor(s) 1304 is (or are) also connected to a network interface 1307 to allow the computer system 1301A to communicate over a data network 1309 with one or more additional computer systems and/or computing systems, such as 1301B, 1301C, and/or 1301D (note that computer systems 1301B, 1301C and/or 1301D may or may not share the same architecture as computer system 1301A, and may be located in different physical locations, e.g., computer systems 1301A and 1301B may be located in a processing facility, while in communication with one or more computer systems such as 1301C and/or 1301D that are located in one or more data centers, and/or located in varying countries on different continents).']

US11733139

System and method for determining sag propensity

May 25, 2022

Andrew Clarke

SCHLUMBERGER TECHNOLOGY CORPORATION

Kamp et al., Universal behaviour in the mechanical properties of weakly aggregated colloidal particles, The Royal Society of Chemistry, Soft Matter, 2009, col. 5, pp. 2438-2447.; Van Den Ende, et al. Driven torsion pendulum for measuring the complex shear modulus in a steady shear flow, Rheologica Acta, vol. 31, No. 5, 1992, pp. 194-205.; Duvarci et al., The SAOS, MAOS and LAOS behavior of a concentrated suspension of tomato paste and its prediction using the Bird-Carreau (SAOS) and Giesekus models (MAOS-LAOS), Journal of Food Engineering, vol. 208, 2017, pp. 77-88.; Hydramotion Inc., Viscolite Portable Viscometer | Hand-held Viscometer, accessible at https://hydramotion.com/en/products/viscolite, 2022.

4524610; June 25, 1985; Fitzgerald et al.; 7845212; December 7, 2010; Bi; 8938380; January 20, 2015; Jamison et al.

2586649; March 2021; GB

['Sag propensity of a fluid can be determined by applying an oscillatory strain at an amplitude in excess of a linear region and below a yield strain of the drilling fluid.', 'This may include use of medium amplitude oscillatory shear (MAOS), from which an elastic modulus of the fluid is determined.', 'The elastic modulus may be determined over time, from which a time to reach maximum elastic modulus can be determined.', 'The time to reach maximum elastic modulus is then converted or correlated to a drilling fluid sag propensity for the drilling fluid either in absolute terms or in relation to base or comparison fluids.', 'Such an evaluation can be performed using a torsional resonance device in which the oscillatory strain is controllable so as to be maintained relatively constant during the measurement.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application claims the benefit of, and priority to, U.S. Patent Application No. 63/193,380, filed May 26, 2021 and titled “System and Method for Determining Sag Propensity”, which application is expressly incorporated herein by this reference in its entirety.', 'BACKGROUND\n \nWhen drilling a wellbore, drilling fluid (often referred to as “mud” or “drilling mud”) is pumped through the drill string and exits the drill bit via several small nozzles.', 'Cuttings generated at the dill bit are carried by the flow to surface via the annulus around the drill string.', 'The drilling fluid may include a combination of gases, liquids, and solids (e.g., foams, solid suspensions, emulsions, etc.), and may be used for a variety of purposes, including carrying drilled cuttings to the surface and providing hydrostatic stability within the wellbore.', 'For stability, the fluid pressure in an unlined wellbore is generally greater than that in the formation being drilled so that fluid does not flow into the wellbore from the formation.', 'However, the fluid pressure also should be less than that which would fracture the rock.', 'The hydrostatic pressure is adjusted by adding weighting agents to the fluid, which can include high-density minerals such as barite.', 'SUMMARY\n \nAn embodiment of the present disclosure relates to estimating or determining sag propensity of a fluid, and includes providing oscillatory strain to a fluid, and within a MAOS regime.', 'Using the oscillatory strain, an elastic modulus is determined as a function of time, and the elastic modulus or a time to reach peak elastic modulus is correlated with sag propensity.', 'Another example method for evaluating sag propensity includes shearing a drilling fluid and providing an oscillatory strain at an amplitude in excess of a linear region and below a yield strain of the drilling fluid.', 'An elastic modulus of the drilling fluid is determined as a function of time, and from the elastic modulus as a function of time, a time to reach maximum elastic modulus is determined.', 'The time to reach maximum elastic modulus is converted or correlated to a drilling fluid sag propensity for the drilling fluid.', 'An example measurement device in accordance with embodiments of the present disclosure includes a driven torsional pendulum.', 'The pendulum can include a shaft and a bob.', 'The bob is designed to be immersed in a fluid and is selectively controllable.', 'For instance, at least a displacement amplitude at a surface of the bob at resonance may be controlled.', 'An optional pre-shearing mechanism, that is independently controllable, is also included and can cause the fluid adjacent the torsional pendulum bob to be sheared at a high rate.', 'Using such a device, strain amplitude imposed on the fluid can be maintained a constant value.', 'From use of the device, a resonant frequency and Q factor of resonance can be measured, and from such measurements, a complex modulus determined.', 'This summary is intended to provide an illustrative description of some aspects of the present disclosure, but is not exhaustive, neither should it be interpreted as describing any features that are key, essential, or which form an essence of the disclosure.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein.', 'Further, unless drawings are indicated as being schematic in nature, they are to be considered to scale for certain embodiments, but the scale is not limiting as different scales may be used in other embodiments unless the appended claims require a certain scale.\n \nFIG. \n1\n is a schematic illustration of an example drilling system for use in drilling a wellbore, according to some embodiments of the present disclosure.\n \nFIG.', '2\n is flowchart of a method for assessing sag propensity, according to embodiments of the present disclosure.\n \nFIG.', '3\n is a chart from laboratory tests of sag within five fluid samples, over approximately a two-month period.\n \nFIG.', '4\n is a flow chart of a method to keep applied strain amplitude constant during a sag propensity measurement process, according to some embodiments of the present disclosure.', 'DETAILED DESCRIPTION\n \nEmbodiments of the present disclosure relate to determining the sag propensity particles in a fluid.', 'More particularly, some embodiments relate to determining the sag propensity for solid particles in a drilling fluid.', 'More particularly still, some embodiments relate to methods and systems for efficiently determining the sag propensity using non-linear oscillation measurements.', 'Over time, particles or solids suspended in a fluid tend to settle.', 'In a downhole environment using drilling fluid with suspended particles, this phenomenon can be referred to as “sag”, and relates to the tendency of the solid particles and suspended drilling cuttings to settle due to gravity and/or as a result of gel collapse/breakdown due to aging (e.g., poroelastic collapse or syneresis).', 'This may result in pressure gradients within the wellbore as the solid materials move to the bottom of a vertical wellbore or the bottom side of an inclined or horizontal wellbore.', 'As sag occurs and the rheological properties of the drilling fluid change, the drilling fluid becomes stratified, which can create a pressure imbalance along the length of the wellbore.', 'In some cases, increased density and mud weight in some strata can lead to damage in a well, or unexpected and potentially dangerous pressure gradients in some formation zones.', 'Additionally, stratified drilling fluids and pressure imbalances can accelerate further sag and lead to stuck pipe, lost circulation, or stick slip events, or can result in an errant drill path.', 'Dynamic and static sag both have been, and continue to be, a chronic challenge in the drilling industry, and complete solutions have not yet been produced.', 'For instance, during drilling operations, sag can be detected by measuring and comparing the weight of the fluid as it leaves the wellbore and the weight of the fluid entering the wellbore.', 'However, this includes long delays, which significantly affects the accuracy of the method, and may delay sag mitigation measures.', 'Further, once the drilling fluid is in the wellbore and sag occurs, the undesirable event has already happened.', 'Even if mitigation measures can be a partial remedy, the wellbore quality, tool efficiency, or operational safety may have already been compromised.', 'Instead of detecting and mitigating sag at the time of the event, controls may instead be put in place to determine the propensity of sag to occur.', 'Upon obtaining a better understanding of the likelihood that sag will occur, lower sag propensity fluids that still provide desired rheological properties may be used.', 'This may be done, for instance, by using a direct, phenomenological measurement.', 'For static sag, this can include filling a pressure cell, heating the pressure cell to a desired temperature, and then waiting a sufficient period of time (often seven days).', 'At the end of the time period, the pressure cell can be opened and the density change at the bottom of the pressure cell can be measured.', 'Instead of obtaining a direct measurement that relies on an extended waiting period, aspects of the present disclosure relate to a physics-based analysis of the drilling fluid.', 'Such an approach has the possibility of accelerating measurements and enabling a significantly quicker assessment of the sag propensity.', 'For instance, the determination may be made in less than a day, less than six hours, or even in less than one hour.', 'This offers the ability to obtain a sag propensity measurement potentially 100 times faster than a direct measurement with a sag period of seven days.', 'As a result, particular drilling fluid formulations for may be evaluated more rapidly, thus allowing more formulations to be tested for a particular application.', 'Moreover, the physics-based approach may even use equipment that can take measurements at temperatures and pressures that allow the equipment to be robust enough to be field deployable.', 'Referring generally to \nFIG.', '1\n, an example of a wellsite system \n100\n for which embodiments described herein may be employed is illustrated.', 'The wellsite may be onshore or offshore.', 'In this example, a wellbore \n102\n is formed in a subsurface formation \n101\n by drilling.', 'The method of drilling to form the wellbore \n102\n may include, but is not limited to, rotary and directional drilling.', 'A drill string \n104\n is suspended within the wellbore \n102\n and has a bottom hole assembly (“BHA”) \n106\n that includes a drill bit \n108\n at its lower end.', 'Some embodiments of a surface system include a platform, derrick, or rig \n103\n positioned over the wellbore \n102\n.', 'An example of assembly \n100\n includes a rotary table, a kelly, a hook, and a rotary swivel.', 'The drill string \n104\n is rotated by the rotary table or top drive and energized by a suitable system which engages the kelly at the upper end of the drill string \n104\n.', 'The drill string \n104\n is suspended from the top drive or a hook attached to a traveling block, and through the kelly and the rotary swivel which permits rotation of the drill string \n104\n relative to the surface system.', 'Some embodiments of the surface system also include a drilling fluid \n110\n, e.g., drilling mud, stored in a pit or tank at the wellsite.', 'A pump \n112\n delivers the drilling fluid \n110\n to the interior of the drill string \n104\n (e.g., via one or more ports in a swivel), causing the drilling fluid \n110\n to flow downwardly through the drill string \n104\n.', 'The drilling fluid exits the drill string \n104\n via one or more ports in the drill bit \n108\n, circulation sub, or other tool, and then circulates upwardly through the annulus region between the outside of the drill string \n104\n and the wall of the borehole \n102\n or casing \n114\n.', 'In this manner, the drilling fluid \n110\n lubricates the drill bit \n108\n and carries formation cuttings and particulate matter up to the surface as it is returned to the pit for recirculation.', 'The illustrated embodiment of bottom hole assembly \n106\n includes one or more logging-while-drilling (“LWD”) modules \n116\n, one or more measuring-while-drilling (“MWD”) modules \n118\n, one or more directional drilling modules \n120\n (including motors), other tools \n122\n, and the drill bit \n108\n.', 'These tools are optional and can include additional or fewer tools or modules.', 'For instance, a mill, reamer, or other tool may be used as, or in addition to, the drill bit \n108\n, or the MWD or LWD may be used without the directional drilling module \n120\n, or vice versa.', 'The LWD \n116\n may be housed in any type of drill collar, and includes capabilities for measuring, processing, and storing information, as well as for communicating with the surface equipment.', 'The LWD module \n116\n also may include pressure measuring device and one or more logging tools.', 'The MWD module \n118\n also may be housed in a type of drill collar, and includes one or more devices for measuring characteristics of the drill string \n104\n and drill bit \n108\n.', 'The MWD module \n118\n also may include one or more devices for generating electrical power for the downhole system.', 'In some embodiments, the power generating devices include a mud turbine generator powered by the flow of the drilling fluid \n110\n.', 'In other embodiments, battery or other power systems may be employed to generate power.', 'The MWD module \n118\n also may include one or more of the following types of measuring devices: a weight-on-bit measuring device; a torque measuring device; a vibration measuring device; a shock measuring device; a stick-slip measuring device; a direction measuring device; an inclination measuring device; a mud density measuring device; or a mud weight or mud composition measuring device.', 'These measuring devices may be used individually or in various combinations.', 'In an operational example, the wellsite system \n100\n of \nFIG.', '1\n is used in conjunction with surface equipment that may be used for various purposes, including steering the drill string \n104\n, connecting and disconnecting drill pipe segments as the drill string \n104\n is lowered or raised, measuring surface or downhole conditions, and the like.', 'This equipment may include the use of computing systems \n124\n located at the wellsite \n100\n or remote from the wellsite (e.g., connected by a communication link with the wellsite \n100\n).', 'In some embodiments, the computing systems \n124\n may include, or be connected to, mud testing equipment.', 'Such equipment may be used to evaluate the properties and composition of the drilling fluid \n110\n and may include interfaces to receive the results of manual or other tests performed on the drilling fluid \n110\n.', 'In response, to tests or evaluation of the drilling fluid \n110\n, additives or other materials may be added to the drilling fluid \n110\n, additional separation or remedial processes may be performed, or the like, in order to produce drilling fluid \n110\n with desired properties.', 'As discussed, one aspect of some embodiments of the present disclosure, is that a physics-based assessment of sag propensity of drilling fluid \n110\n may be determined quickly, and may therefore be used in a variety of environments.', "Thus, embodiments of methods, devices, and systems for determining sag propensity can be located at the wellsite (e.g., using evaluation equipment optionally connected to the computing system \n124\n), even where the extended period of time used to obtain a direct phenomenological test result may have limited use at the field location, and thus are replaced by time-density traces that indicate if sag has occurred, which is a potentially dangerous situation as it doesn't operate predictively to indicate if sag is likely to occur in the future to allow avoidance of the situation.", 'Nevertheless, embodiments of the present disclosure may also be used in a laboratory setting, or in other locations.', 'Moreover, such methods, devices, and systems are not limited to use exclusively with drilling fluid, and may be used in other environments or applications where it is desired to determine the sag or settling propensity of solids or particles within a fluid.', 'The fluid \n110\n may have a variety of formulations, and can generally be categorized as a water-based mud (“WBM”), an oil-based mud (“OBM”), or a synthetic-based mud (“SBM”).', 'Sag can occur differently in different types of fluids.', 'For instance, in an OBM, sag can occur within a gel or poroelastic collapse process in a stationary mud, with a time delay observed before appearance of free oil and a concomitant increase in the density of the mud at the bottom of a test cell.', 'In practice, a measurement that is sensitive to changes in gel properties occurring before the macroscopic collapse (e.g., before the time delay is completed) can be predictive of the possibility of future sag, rather than simply report that sag has occurred.', 'Thus, such a prediction can allow a mud engineer to take pre-emptive action before macroscopically observable changes occur.', 'Turning now to \nFIG.', '2\n, a method \n200\n is shown as a flow chart for assessing the propensity of static sag.', 'In the method \n200\n, the method begins, which may include pre-shearing the fluid.', 'For instance, fluid may be sheared at a shear rate (e.g., a high shear rate) for a period of time, and then stopped.', 'The pre-shear period may be any suitable period, and in some embodiments is between 10 seconds and 1 hour (e.g., 15 seconds, 1 minute, 5 minutes, 10 minutes, 30 minutes, 1 hour, or any period therebetween).', 'The pre-shear period may be fixed or variable.', 'For instance, in one embodiments, pre-shearing is performed for a period of time sufficient to reach a determined initial state of the fluid.', 'This may allow, for example, comparisons of different fluids which are pre-sheared to the same or similar initial state.', 'In some embodiments, pre-shear may be limited in time as extended pre-shear may cause detrimental effects to occur.', 'Before or after pre-shearing, an initial determination of the significance of sedimentation in the drilling fluid is made at 230.', 'In this particular embodiment, this determination can be made using a Y parameter, which can be dimensionless number representing a ratio of forces as shown in Equation 1:\n \n \n \n \n \n \n \n \nY\n \n=\n \n \n \n3\n \n\u2062\n \n \nσ\n \ny\n \n \n \n \n2\n \n\u2062\n \na\n \n\u2062\n \nΔρ\n \n\u2062\n \ng\n \n \n \n \n \n \n \n(\n \n1\n \n)\n \n \n \n \n \n \n \n \nwhere σ\ny \nis the yield stress of the drilling fluid, a is particle size (e.g., based on surface area or radius), Δp is a difference between particle and fluid density (e.g., the difference relative to the density of the continuous phase of the fluid), and g is gravity.', 'The yield stress may be measured for a particular fluid, and changes over time.', 'In one example, the yield stress may be a measurement of the amount of strength needed to break the gel, and can be the y-intercept on a flow curve that plots the shear rate of the fluid (x axis) against the stress (y axis).', 'The denominator in Equation 1 is reflective of the gravity force of the solid particle (e.g., barite).', 'The particle size and gravity values would be generally constant over time, although the Δp value may change, such as when the oil/water ratio of the continuous phase changes.', 'In practice, however, it may be that changes in the Δp value are quite small with observed changes to the yield stress value.', 'As a result, the changes to the Y parameter may largely be reflective of yield stress changes.', 'The Y parameter may be calculated and compared against a critical Y parameter (Y\nc\n) at \n238\n, in order to determine whether gravity or fluid yield stress is dominant on the particles in the fluid.', 'This can be a measure of how well gravity will move the particle in the fluid.', 'For instance, where gravity is the dominant force (e.g., Y Y\nc\n), it may be determined at \n234\n that the particles are expected to be suspended within the fluid.', 'Thus, a large Y parameter is indicative of a larger shear stress supporting the particle in the fluid, and a small Y parameter reflects gravity is larger.', 'For simplicity, the Y\nc \nvalue may be set to a value of 1, which provides a suitable ratio for measuring the relative scale of the forces acting on the particle in a fluid.', 'It will be appreciated, however, that this value may vary.', 'For instance, the gel microstructure within a fluid can have different forms and behave in different ways.', 'As a result, the Y\nc \nvalue can also vary to reflect how the microstructure supports the solid particles.', 'Thus, in some embodiments, Y\nc \nmay be less than 1 or greater than 1.', 'For instance, Y\nc \nmay be determined based on the fluid microstructure and may be a value having a lower value, an upper value, or lower and upper values including one of more of 0.4, 0.5, 0.6.', '0.7, 0.8, 0.9, 1.0, 1.1, 1.1, 1.2, 1.3, 1.4, 1.5, 1.6 or values therebetween.', 'For instance, Y\nc \nmay be between 0.5 and 1.5 in one non-limiting example of the present disclosure.', 'It will also be appreciated that Equation 1 is illustrative, and other equations may be used to evaluate whether gravity or suspension forces are dominant on a particle.', 'For instance, measurements of viscosity, modulus, gel strength, or yield point (e.g., low shear yield point) may be used.', 'When the solids are determined at \n232\n to be sedimenting rather than being suspended, the method \n200\n may be used to determine that sag is not the primary settling activity.', "For instance, Stokes settling (or Stokes' hindered settling) is occurring at \n236\n.", 'This determination may represent that the particle in the fluid is too heavy compared to the yield stress, which allows the particle to break the gel and settle.', 'Thus, when the value of the Y parameter is less than 1 (or another Y\nc \nvalue based on the microstructure), it may be determined settling occurs.', 'If, however, the Y parameter is greater than 1 or other Y\nc \nvalue, the particle cannot settle through the fluid and solids are determined at \n234\n to be suspended, a dynamic oscillatory shear test may be used at \n238\n to further investigate the gel strength and collapse (syneresis) of the fluid that leads to sag occurrence.', 'Dynamic oscillatory shear tests can be performed to measure the elastic modules of the gel as a function of time.', 'In such tests, the elastic modulus will exhibit a peak somewhat before the collapse starts.', 'This time can be proportional to, but significantly short than, the time delay until the collapse begins.', 'As a result, the peak position can be a predictive indicator measurement.', 'The dynamic oscillatory shear test can produce a linear viscoelastic response from the fluid, or can produce a non-linear material response.', 'Tests that produce linear responses can be referred to as small amplitude oscillatory shear (SAOS) tests, while tests that produce measurable non-linear responses can include large amplitude oscillatory shear (LAOS) tests.', 'A transition region also exists between SAOS and LAOS, which includes medium amplitude oscillatory shear (MAOS) tests.', 'In the MAOS regime, a particular scaling behavior can be observed for a third harmonic contribution.', 'For instance, the I\n3/1 \nmagnitude in the MAOS region may be between 3×10\n−4 \nand 1×10\n−2\n.', 'In the LAOS region, however, I\n3/1 \nmay be higher, including up to 10\n−1\n.', 'In the MAOS region, the strain amplitude also generally ranges from about 0.1 to 1, although this range can depend on other factors, including the excitation frequency and material characteristics.', 'The elastic modulus can be measured using SAOS tests, and although the small perturbations provide a suitable measurement at the time the peak occurs, the time to obtain the peak is impractically long.', 'Increasing the amplitude of the perturbation so that the deformation is weakly non-linear using MAOS tests can allow a peak to be found in much shorter time periods.', 'Thus, to determine the viscoelastic response of the fluid, a MAOS test may be performed on the fluid.', 'For instance, in such a test, the oscillatory shear can apply a strain under a stress in periodic manner (e.g., as a sinusoidal wave) for a period of time such as 30 minutes, 60 minutes, 90 minutes, or 120 minutes.', 'Shorter or longer tests could also be performed.', 'For the test, a modulus (G*) can be used to relate the stress to the strain, and may be determined either by ignoring harmonics after the first, or by considering all harmonics (or some subset of harmonics).', 'A phase shift of the oscillatory shear may have a produce a complex modulus (G*) including a real, elastic modulus portion (G′), and an imaginary portion (G″).', 'To provide a consistent measurement, the amplitude of the strain oscillation can exceed a linear region (and thus exceed about 1% strain for oil-based mud) and less than the strain required to break the gel (e.g., about 10% for oil-based mud).', 'In some cases, the strain is significantly less than the strain that would break the gel.', 'In an illustrative embodiment, the strain amplitude is between 1% and 7% strain for the gel.', 'In another embodiment, the strain amplitude is between 1% and 5% or between 2% and 4% of the strain for the gel.', 'For instance, the strain amplitude may be about 3%.', 'In other embodiments, higher or lower strain amplitudes may be used.', 'Whatever the strain amplitude that is used in the test at \n238\n, the MAOS test amplitude may be controlled to be constant so that measurements can be compared.', 'As the test is performed, the controlled strain oscillates at a frequency over a set of cycles, and the G′ value may increase to reach a peak.', 'Also at \n238\n, the time at which the G′ is a maximum (i.e., t(G′=max)) may be found.', 'In some aspects of the present disclosure, the maximum G′ value may also be determined.', 'The time to achieve the maximum G′ may be reflective of fluid aging and initiation of collapse (e.g., gel collapse or poroelastic collapse).', 'In some cases, however, the t(G′=max) value may not be found during a test.', "For instance, if the fluid/gel was not susceptible to collapse/aging or the collapse takes so long that the test length isn't sufficient, the time value and maximum G′ values may not be found.", 'In that case, the decision at \n240\n may indicate that time was not found and it can be determined at \n242\n that no collapse is starting to occur.', 'At this point, the process may stop or the test may be repeated (e.g., for a longer period of time).', 'If, however, the time and/or maximum G values are found at \n240\n, the method \n200\n optionally moves to determining the time to collapse at \n244\n.', 'In particular, the results of the MAOS test at \n240\n may be used to determine a sag time that would be observed under other conditions (e.g., under drilling conditions, in a seven-day pressure cell test, etc.).', 'By way of example, a series of tests may be performed to develop a relationship between the maximum G′ value and the sag time.', 'FIG.', '3\n, for instance, shows results of a laboratory test where the collapse of five samples was observed over a time period of approximately 2 months.', 'The results are plotted on a logarithmic scale, with the arrow reflecting the initial 7 days of the test.', 'For the test, the samples had similar chemistry except for the amount of barite, which varied from a control with no barite to a heavy sample with 120 grams per.', 'In this example, a lab barrel was used according to ISO 10416:2008 (API RP 13I) in which a lab barrel is 350 ml.', 'As seen, despite the differences in barite content, all the samples exhibit a similar pattern of collapse in which no collapse is observed for a period of time, after which collapse increases.', "In the heavy sample, no collapse was evident until about 5.5 days (130 hours) had lapsed, while the sample with no barite didn't start to collapse until after about 10.5 days (255 hours).", 'The other samples had intermediate delays until the onset of collapse of about 6.5 days (155 hours) for the sample with 90 grams barite per barrel, about 9.5 days (225 hours) for the sample with 60 grams barite per barrel, and about 10 days (240 hours) for the sample with 30 grams barite per barrel.', 'Notably, for a standard test over seven days, only two of the samples would have exhibited any amount of sag, with the 60 g/barrel sample only just starting to show signs of sag.', 'Significantly, although the samples have different delays until the onset of collapse, once collapse begins, the rate of collapse shown in the logarithmic scale of \nFIG.', '3\n is relatively constant, meaning the true rate of collapse is logarithmic.', 'This can be seen by the generally parallel trend lines in \nFIG.', '3\n.', 'In some embodiments, the shape of the trend line can also be indicative of a type of collapse.', 'For instance, a linear slope on a linear scale may be indicative of poroelastic collapse, while a slope that appears linear on a logarithmic scale may be indicative of gel collapse.', 'Through experimental results, the time delay to collapse (poroelastic or gel collapse) can be correlated with sag, and the peak observed as a function of time can be correlated with the delay time to collapse.', 'This may be observed in SAOS tests, although the use of non-linear oscillation using MAOS accelerates sag, and the non-linear amplitudes in oscillation may (for instance, in a rheometer) accelerate the appearance of the peak in the modulus.', 'Consequently, a determination of the time to peak in elastic modulus during a MAOS test allows defining a correlation to sag, and is inversely related thereto (i.e., longer time to peak indicates less sag).', 'A description of the underlying material science and MAOS data can be found in the attached appendix that is incorporated in and made part of this application.', 'In a field or laboratory environment, the MAOS measurements can be made using a suitable lab rheometer, although not all rheometers may have such capabilities.', 'Torsional oscillator viscometers can use a torsional resonance that is exploited to recover the viscosity of the surrounding fluid.', 'The physics of such instruments allows the measurement of viscoelastic modulus (G′ and G″), but is not generally available in commercial instruments rugged enough for field deployment.', 'In addition, torsional resonance for viscoelastic modulus measurement is not commercially available.', 'Although the torsional instruments commercially available could be re-interpreted for viscoelastic modulus, they generally do not control the perturbation amplitude and do not have mechanisms available to pre-shear the fluid to provide a reproducible initial state of the fluid.', 'A couette geometry together with the bob as a torsional resonator can be used provide such mechanisms, and an aspect of the present disclosure includes use of a rheometer or modified oilfield rheometer to allow application of perturbations and obtaining of measurements.', 'In an oilfield rheometer design, the bob may be mounted on a shaft that rotates against a spring in a desired direction that may be clockwise or counter-clockwise.', 'The angular deflection is used to measure the torque.', 'In the anticlockwise direction there may be a stop, and a mechanism can be added that clamps the shaft against the stop such that the shaft becomes the torsional spring for bob resonance.', 'Perturbations to the bob can then be applied to bring the bob into oscillation.', 'This could be via a magnet mounted inside the bob and external coils or any other suitable means such as perturbation of counterweight on extended shaft with the clamp point a nodal point of the system.', 'This latter design allows a pressure seal.', 'The perturbation amplitude could then be controlled so that the deflection amplitude of the bob is at a desired level.', 'This level is chosen by calculating the resulting strain in the sample being tested.', 'An example of a suitable method \n400\n for keeping constant strain amplitude during a measurement (e.g., a MAOS measurement) is shown in \nFIG.', '4\n.', 'In this method, a small amplitude perturbation (A\nθ\n) is set at \n450\n, and a measurement of the resonant frequency (f\nR\n) and sharpness (Q) of the resonance frequency can be made at \n452\n.', 'In some embodiments, the sharpness can be calculated or related to the resonance frequency over the width.', 'The complex modulus G* is calculated at \n454\n.', 'This may be calculated as: \n \nG*=iωη*\n\u2003\u2003(1) \n with G* including G′+G″, i being the imaginary number, ω representing an angular frequency (e.g., in radians/second) of oscillation in the resonance frequency, and', 'η* representing a complex viscosity of the fluid.', 'The complex viscosity may be determined in any suitable manner, including by using existing measurement equipment capable of this measurement.', 'The wavelength (λ\ns\n) of a shear wave created by an oscillation (e.g., an oscillating bob) in the fluid may be calculated at \n456\n.', 'An example equation for this calculation includes:\n \n \n \n \n \n \n \n \n \nλ\n \ns\n \n \n=\n \n \n \n \n \n(\n \n \n \n \n \nρ\n \n\u2062\n \nf\n \n \n \n2\n \n\u2062\n \nπ\n \n\u2062\n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \nη\n \n*\n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n \n \n\u2062\n \n \ncos\n \n\u2061\n \n(\n \n \nδ\n \n2\n \n \n)\n \n \n \n)\n \n \n \n-\n \n1\n \n \n \n\u2062\n \n \ntan\n \n\u2061\n \n(\n \nδ\n \n)\n \n \n \n=\n \n \n \n \nG\n \n″\n \n \n \nG\n \n′\n \n \n \n=\n \n \n \n \nη\n \n″\n \n \n \nη\n \n′\n \n \n \n.', '(\n \n2\n \n)\n \n \n \n \n \n \n \n \nFollowing calculation of the wavelength at \n456\n, the amplitude of the oscillation (A\nθ\n) for the strain (S) can be determined at \n458\n.', 'An example equation for such calculation that also allows determination of the strain using wavelength and amplitude is:\n \n \n \n \n \n \n \n \n \nA\n \nθ\n \n \n=\n \n \n \n1\n \nr\n \n \n\u2062\n \n \nS\n \n·\n \n \n \n \nλ\n \ns\n \n \n4\n \n \n.\n \n \n \n \n \n \n \n \n(\n \n3\n \n)\n \n \n \n \n \n \n \n \nIf the time (t) is then determined at \n460\n to be less than a set measurement time (t\nmeas\n), the method \n400\n can end.', 'Otherwise, the method \n400\n may return to the act of setting a small amplitude perturbation at \n450\n.', 'From a mechanical point of view, it may be desirable to have a resonant frequency as high as practical, in order to probe the fluid over a length-scale large enough that allows bulk properties to be measured while the wavelength should be as long as possible.', 'In some embodiments this is greater than 25 μm, 50 μm, 75 μm, 100 μm, 150 μm, or 250 μm.', 'For example fluid properties, a 100 μm wavelength suggests a potential maximum practical frequency of about 1 kHz.', 'Also, the lower the frequency, the larger the perturbation amplitude for a given strain, which may therefore more easily sensed.', 'In accordance with embodiments of the present disclosure using a torsional oscillator, drive power may be set so that the amplitude of the oscillation can be within a MAOS range (or alternatively in a LAOS or SAOS).', 'The resonant frequency (without damping) can be given by the equation:', 'f\n \n=\n \n \n \n1\n \n \n2\n \n\u2062\n \nπ\n \n \n \n\u2062\n \n \n \nk\n \nI\n \n \n \n \n \n,\n \n \n \n \n \n(\n \n4\n \n)\n \n \n \n \n \n \n \n \nwhere k is the torsional spring constant', 'and I is the moment of inertia of the torsional component (the bob in the case of the couette arrangement).', 'For an example oilfield rheometer (e.g., GRACE M3600 oilfield rheometer), the shaft and bob combination may resonate between 100 Hz and 150 Hz (e.g., about 130 Hz).', 'It should be noted that the spring constant, k, depends on the shaft as:\n \n \n \n \n \n \n \n \n \nk\n \n=\n \n \n \nπ\n \n\u2062\n \n \na\n \n4\n \n \n\u2062\n \nG\n \n \n \n2\n \n\u2062\n \nL\n \n \n \n \n,\n \n \n \n \n \n(\n \n5\n \n)\n \n \n \n \n \n \n \n where G is the shaft material shear modulus (e.g., about 75 to 80 GPa for steel), a is the shaft radius, and L the length of the shaft.', 'Since shaft radius is raised to the power 4, k and the resonant frequency are therefore highly sensitive to the radius of the shaft.', 'INDUSTRIAL APPLICABILITY\n \nEmbodiments of the present disclosure allow for the sag propensity in fluids to be determined.', 'For instance, by using non-linear oscillation measurements, the sag (gel or poroelastic collapse) nature of a fluid can be accelerated and the sag propensity can be determined in a more rapid fashion.', 'To perform such tests, torsional oscillation devices may be used, and can be controllable to allow a displacement amplitude to be selectively controlled, which optionally allows for a constant strain amplitude to be applied during the test.', 'Additionally, by pre-shearing a fluid before all or a portion of a test, the fluid can be prepared for the test and may be brought to a predetermined or other reproducible state.', 'Having fluid in a reproducible state allows for similar measurements to be made and comparisons to efficiently be drawn.', 'Thus, while sag propensity may be determined in an absolute or quantitative fashion, sag propensity may also allow comparisons in a qualitative fashion by comparing different fluids and fluid compositions.', 'In some embodiments estimating or determining sag propensity of a fluid, and includes providing oscillatory strain to a fluid, and within a MAOS regime.', 'Using the oscillatory strain, an elastic modulus is determined as a function of time, and the elastic modulus or a time to reach peak elastic modulus or a combination is correlated with sag propensity.', 'In some embodiments, a time to reach peak elastic or complex modulus is inversely correlated with sag, such that greater time is indicative of less sag.', 'In another embodiment, a method includes pre-shearing the fluid before providing the oscillatory strain.', 'Pre-shearing may include stopping pre-shearing of the drilling before providing the oscillatory strain.', 'Pre-shearing additionally, or alternatively, includes pre-shearing the fluid at a high-shear rate over a period of time.', 'In another embodiment, a method of estimating or determining sag propensity includes determining an elastic or complex modulus did not peak, repeating an evaluation method for a longer time period to obtain the peak elastic or complex modulus.', 'In some embodiments, correlating elastic or complex modulus, or time to reach a peak, includes one or more of determining sag of the fluid or that the fluid has a higher or lower sag propensity relative to a second fluid.', 'Where the fluid is a first fluid, the method may include designing or selecting a fluid composition by repeating the method for a second fluid with a differing composition.', 'Another example method for evaluating sag propensity includes shearing a drilling fluid and providing an oscillatory strain at an amplitude in excess of a linear region and below a yield strain of the drilling fluid.', 'An elastic modulus of the drilling fluid is determined as a function of time, and from the elastic modulus as a function of time, a time to reach maximum elastic modulus is determined.', 'The time to reach maximum elastic modulus is converted or correlated to a drilling fluid sag propensity for the drilling fluid.', 'In some embodiments, shearing drilling fluid includes applying a high shear rate for a period of time and stopping before providing the oscillatory strain and/or shearing the drilling fluid until a predetermined initial state of the drilling fluid is achieved.', 'In further example embodiments, the elastic modulus can include G′ of a viscoelastic modulus.', 'In some embodiments, the oscillatory strain the perturbation amplitude of the oscillatory strain is controlled.', 'The sag propensity that is determined can include one or more of poroelastic collapse or syneresis.', 'According to some embodiment, determining a sag propensity can include determining a Y parameter for a drilling fluid and providing an oscillatory strain after determining the Y parameter is greater than a critical Y parameter.', 'When the Y parameter is less than the critical Y parameter, the presence of settling may be detected rather than sag.', 'Additional embodiments include measuring torque during or after providing the oscillatory strain and using the measured torque to determine the elastic modulus.', 'An example measurement device in accordance with embodiments of the present disclosure includes a driven torsional pendulum.', 'The pendulum can include a shaft and a bob.', 'The bob is designed to be immersed in a fluid and is selectively controllable.', 'For instance, at least a displacement amplitude at a surface of the bob at resonance may be controlled.', 'An optional pre-shearing mechanism, that is independently controllable, is also included and can cause the fluid adjacent the torsional pendulum bob to be sheared at a high rate.', 'Using such a device, strain amplitude imposed on the fluid can be maintained a constant value.', 'From use of the device, a resonant frequency and Q factor of resonance can be measured, and from such measurements, a complex modulus determined.', 'Embodiments of the present disclosure can be implemented with a variety of different fluids and under various testing and operating conditions.', 'Some examples of suitable methods and fluids are discussed in connection with certain examples included in the appendix incorporated and made part of this application.', 'Other portions of the appendix include background information that may be useful in understanding certain aspects of the present disclosure.', 'While embodiments disclosed herein may be used in the oil, gas, hydrocarbon exploration or production environments, or in the production of other natural resources, such environments are merely illustrative.', 'Systems, tools, assemblies, methods, devices, and other components of the present disclosure, or which would be appreciated in view of the disclosure herein, may be used in other applications and environments.', 'For instance, creaming is another phenomenon that may be generally opposite sedimentation and is amenable to the same analysis, but considered a gravity-type effect in an upward direction rather than a downward direction.', 'In other embodiments, embodiments of the present disclosure may be used outside of a downhole environment, including in connection with the automotive, aquatic, aerospace, hydroelectric, pharmaceutical, agrochemical, personal care, cosmetics, or manufacturing industries.', 'Certain descriptions or designations of components as “first,” “second,” “third,” and the like are also used to differentiate between identical components or between components which are similar in use, structure, or operation.', 'Such language is not intended to limit a component to a singular designation or require multiple components.', 'As such, a component referenced in the specification as the “first” component may be the same or different than a component that is referenced in the claims as a “first” component, and a claim may include a “first” component without requiring the existence of a “second” component.', 'Furthermore, while the description or claims may refer to “an additional” or “other” element, feature, aspect, component, or the like, it does not preclude there being a single element, or more than one, of the additional element.', 'Where the claims or description refer to “a” or “an” element, such reference is not be construed that there is just one of that element, but is instead to be inclusive of other components and understood as “at least one” of the element.', 'It is to be understood that where the specification states that a component, feature, structure, function, or characteristic “may,” “might,” “can,” or “could” be included, that particular component, feature, structure, or characteristic is provided in certain embodiments, but is optional for other embodiments of the present disclosure.', 'The terms “couple,” “coupled,” “connect,” “connection,” “connected,” “in connection with,” and “connecting” refer to “in direct connection with,” or “in connection with via one or more intermediate elements or members.”', 'Components that are “integral” or “integrally” formed include components made from the same piece of material, or sets of materials, such as by being commonly molded or cast from the same material, in the same molding or casting process, or commonly machined from the same piece of material stock.', 'Components that are “integral” should also be understood to be “coupled” together.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that is within standard manufacturing or process tolerances, or which still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'Although various example embodiments have been described in detail herein, those skilled in the art will readily appreciate in view of the present disclosure that many modifications are possible in the example embodiments without materially departing from the present disclosure.', 'Accordingly, any such modifications are intended to be included in the scope of this disclosure.', 'Likewise, while the disclosure herein contains many specifics, these specifics should not be construed as limiting the scope of the disclosure or of any of the appended claims, but merely as providing information pertinent to one or more specific embodiments that may fall within the scope of the disclosure and the appended claims.', 'Any described features from the various embodiments disclosed may be employed in combination.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The Abstract at the end of this disclosure is provided to allow the reader to quickly ascertain the general nature of some embodiments of the present disclosure.', 'It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.']

['1.', 'A method for characterizing and evaluating a drilling fluid, comprising:\ni) using a rheometer to apply oscillatory strain to the drilling fluid and measure torque while the oscillatory strain is applied to the drilling fluid;\nii) determining an elastic modulus of the drilling fluid over time based on the torque measured by the rheometer in i);\niii) determining a time corresponding to a peak magnitude of the elastic modulus of the drilling fluid determined in ii);\niv) using a correlation to determine a parameter characterizing sag of the drilling fluid from the time corresponding to the peak magnitude of the elastic modulus as determined in iii); and\nv) evaluating the parameter characterizing sag of the drilling fluid as determined in iv) to determine suitability of the drilling fluid for drilling a wellbore.', '2.', 'The method of claim 1, further comprising shearing the drilling fluid before applying the oscillatory strain in i).', '3.', 'The method of claim 1, wherein the parameter characterizing sag of the drilling fluid represents a sag time.', '4.', 'The method of claim 1, further comprising repeating the operations of i) to v) for an additional drilling fluid.', '5.', 'The method of claim 4, wherein the additional drilling fluid has a composition different from a composition of the drilling fluid.', '6.', 'The method of claim 1, wherein the oscillatory strain is applied in i) by controlling perturbation amplitude.\n\n\n\n\n\n\n7.', 'The method of claim 1, wherein the sag of the drilling fluid relates to a tendency of solid particles to settle due to gravity and/or as a result of gel collapse or breakdown due to aging.', '8.', 'The method of claim 1, further comprising:\ndetermining a Y parameter for the drilling fluid; and\nselectively applying the oscillatory strain in i) after determining that the Y parameter is greater than a critical Y parameter.', '9.', 'The method of claim 1, wherein the time corresponding to a peak magnitude of the elastic modulus of the drilling fluid as determined in iii) represents a time to reach the peak magnitude of the elastic modulus of the drilling fluid.', '10.', 'The method of claim 1, wherein the elastic modulus of the drilling fluid as determined in ii) comprises a complex viscoelastic modulus of the drilling fluid.', '11.', 'The method of claim 10, wherein the complex viscoelastic modulus of the drilling fluid is based on angular frequency of oscillation in the oscillatory strain and measured viscosity of the drilling fluid.', '12.', 'The method of claim 1, wherein the oscillatory strain applied to the drilling fluid in i) is in a medium amplitude oscillatory shear (MAOS) regime that exists between a small amplitude oscillatory shear (SAOS) regime that produces a linear viscoelastic response and a large amplitude oscillatory shear (LAOS) regime that produces a non-linear viscoelastic response.', '13.', 'The method of claim 12, wherein the medium amplitude oscillatory shear (MAOS) regime produces a particular scaling factor for a third harmonic contribution.', '14.', 'The method of claim 1, wherein the correlation of iv) is determined from laboratory tests of collapse of a number of drilling fluid samples.', '15.', 'The method of claim 1, wherein the rheometer comprises a torsional oscillator configured to apply oscillatory strain to the drilling fluid in i).', '16.', 'The method of claim 1, wherein the rheometer comprises an oscillating bob configured to apply oscillatory strain to the drilling fluid in i).', '17.', 'The method of claim 1, wherein the rheometer is configured to apply oscillatory strain at a resonant frequency in i).']

['FIG.', '1 is a schematic illustration of an example drilling system for use in drilling a wellbore, according to some embodiments of the present disclosure.', '; FIG. 2 is flowchart of a method for assessing sag propensity, according to embodiments of the present disclosure.; FIG.', '3 is a chart from laboratory tests of sag within five fluid samples, over approximately a two-month period.; FIG.', '4 is a flow chart of a method to keep applied strain amplitude constant during a sag propensity measurement process, according to some embodiments of the present disclosure.']

US11828108

Angled chisel insert

Jan 11, 2017

Ronald B. Crockett, Dwain Norris, Aaron Madsen, Neil Cannon, John Daniel Belnap

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent application PCT/US2017/012895 dated May 18, 2017, 15 pages.; Office Action issued in U.S. Appl. No. 14/138,208 dated Dec. 29, 2016, 19 pages.; Office Action issued in U.S. Appl. No. 14/138,208 dated Jun. 17, 2016, 19 pages.; First Office Action and Search Report issued in Chinese patent application 2017800065760 dated Sep. 18, 2019, 20 pages.; International Preliminary Report on Patentability issued in International Patent application PCT/US2017/012895 dated Jul. 26, 2018, 12 pages.; Exam Report issued in Canadian Patent Application No. 3011347 dated Feb. 7, 2023, 5 pages.

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['A cutting element includes a substrate that is axially symmetric about a central axis.', 'The substrate has a radius perpendicular to the central axis and that extends from the central axis to an outer surface of the substrate.', 'A super-hard material is coupled to the substrate, and the central axis passes through the super-hard material.', 'The super-hard material has an external surface defining at least one ridge protruding from a remainder of the external surface.', 'A central point on the central axis is offset from the external surface of the super-hard material by a distance equal to the radius of the substrate.', 'A distance measured from the external surface of the super-hard material to the central point is greatest at a position between 25° and 45° from the central axis of the substrate.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application claims the benefit of, and priority to, U.S. Patent Application No. 62/278,116, filed Jan. 13, 2016 and to U.S. Patent Application No. 62/338,713, filed May 19, 2016, which applications are expressly incorporated herein by this reference in their entireties.', 'BACKGROUND', 'In various fields such as earth-boring, road milling, mining and trenching it is often desirable to engage and degrade tough materials such as rock, asphalt, or concrete.', 'To do so, cutting elements may be coupled to a movable body that may bring the cutting elements into contact with a material to be degraded as the body moves.', 'For example, when exploring for or extracting subterranean oil, gas, or geothermal energy deposits, a plurality of cutting elements can be secured to a drill bit attached to the end of a drill sting.', 'As the drill bit is rotated, the cutting elements may degrade a subterranean formation forming a wellbore, which allows the drill bit to advance through the formation.', 'In another example, when preparing an asphalt road for resurfacing, cutting elements can be coupled to tips of picks that may be connected to a rotatable drum.', 'As the drum is rotated, the cutting elements may degrade the asphalt leaving a surface ready for application of a fresh layer.', 'The cutting elements used in such applications often include super-hard materials, such as polycrystalline diamond, sintered to a substrate material in a high-pressure, high-temperature environment.', 'These cutting elements, like those described in U.S. Pat.', 'No. 7,726,420 to Shen et al., may include a cutting edge formed in the super-hard material designed to scrape against and shear away a surface.', 'While effective in cutting formation or other materials, such cutting elements may be susceptible to chipping, cracking, or partial fracturing when subjected to high forces.', 'BRIEF SUMMARY', 'In accordance with some embodiments, a cutting element includes a substrate that is axially symmetric about a central axis thereof.', 'The substrate has a radius perpendicular to the central axis and which extends from the central axis to an outer surface of the substrate.', 'A super-hard material is coupled to the substrate, and the central axis passes through the super-hard material.', 'The super-hard material has an external surface defining at least one ridge protruding from a remainder of the external surface.', 'A central point on the central axis is offset from the external surface of the super-hard material by a distance equal to the radius of the substrate.', 'A distance measured from the external surface of the super-hard material to the central point is greatest at a position between 25° and 45° from the central axis of the substrate.', 'According to some embodiments, a cutting element may include a substrate that is axially symmetric about its central axis.', 'A super-hard material may be bonded to a side of the substrate such that the central axis passes through the super-hard material.', "An external surface of the super-hard material may include a geometry designed to increase the cutting element's resistance to high forces.", 'Specifically, a distance, measured from the external surface of the super-hard material to a central point, may be greatest at an angle from the central axis of the substrate.', 'The central point may be located on the central axis and sit a length from the external surface along the central axis equal to a radius of the substrate.', 'In further example embodiments, an external surface of the super-hard material may include a ridge protruding from a remainder of the external surface.', 'In various embodiments, the ridge may intersect the central axis of the substrate, be generally perpendicular to the central axis of the substrate, or be generally convex over a maximum length thereof.', 'In some embodiments, a plurality of ridges may extend from a common center that may fall on the central axis of the substrate with the ridges equally spaced around the common center.', 'In some embodiments, the distance measured from the external surface of the super-hard material to the central point is greatest at more than one positions optionally between 25° and 45° from the central axis of the substrate.', "A thickness of the super-hard material may also be designed to increase the cutting element's resistance to high forces.", 'For instance, a thickness, measured from the external surface of the super-hard material to an interface between the super-hard material and the substrate along a line passing through the central point, may be greatest at a position between 25° and 45° from the central axis of the substrate.', 'Beyond this position between 25° and 45° from the central axis of the substrate, a portion of the external surface may take the form of part of a cone shape or ogive shape.', 'Additionally, a boundary between the ridge and the cone shape or ogive shape may include a chamfer.', 'In some embodiments, the substrate may have an elevated portion protruding into the super-hard material and extending radially to a position between 25° and 45° from the central axis of the substrate from the central point.', 'In some embodiments, a thickness of a transition region between the super-hard material and the substrate may have a substantially constant thickness regardless of thickness of the super-hard material.', 'A cutting element of the present disclosure may be coupled to a drill bit or pick.', 'When secured to a drill bit or pick, to control the aggressiveness of each cutting element, a ridge on each cutting element may be positioned between 0° and 70° relative to a formation.', 'Further, the ridge on each cutting element may be positioned parallel, non-parallel, or perpendicular to a direction of rotation.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a side view of a road milling machine performing a road milling operation, according to some embodiments of the present disclosure.\n \nFIG.', '2\n is a front view of a rotatable drum including a plurality of picks, according to some embodiments of the present disclosure.\n \nFIG.', '3\na \nis a longitudinal cross-sectional view of a pick with a cutting element on a tip thereof, according to some embodiments of the present disclosure.\n \nFIG.', '3\nb \nis an enlarged view of the cutting element of \nFIG.', '3\na. \n \nFIG.', '4\na \nis a longitudinal cross-sectional section view a pick with a cutting element on a tip thereof, according to additional embodiments of the present disclosure.\n \nFIG.', '4\nb \nis an enlarged view of the cutting element of \nFIG.', '4\na. \n \nFIG.', '5\na \nis a perspective view of cutting element having a generally constant height ridge on the outer surface thereof, according to some embodiments of the present disclosure.', 'FIG.', '5\nb \nis a perspective view of an embodiment of a cutting element having a convex ridge on the outer surface thereof, according to some embodiments of the present disclosure.', 'FIGS.', '6\na\n-\n6\nd \nare side views of cutting elements at various positions relative to a degradable material, according to some embodiments of the present disclosure.\n \nFIG.', '7\n is a perspective view of a cutting element including ridges extending from a common center, according to some embodiments of the present disclosure.\n \nFIG.', '8\n is a plan view of a cutting element including ridges extending from a common center, according to some embodiments of the present disclosure.\n \nFIG.', '9\n is a side view of the cutting element including ridges extending from a common center, according to some embodiments of the present disclosure.\n \nFIG.', '10\n is a side view of a mining machine performing a mining operation, according to some embodiments of the present disclosure.\n \nFIG.', '11\na \nis schematic view of a drilling system for use in performing an earth-boring operation, according to some embodiments of the present disclosure.', 'FIG.', '11\nb \nis a perspective view of an example drill bit having cutting elements thereon, and which can be used in the drilling system of \nFIG.', '11\na. \n \nFIG.', '12\na \nis a side view of a percussion hammer bit, according to some embodiments of the present disclosure.\n \nFIG.', '12\nb \nis a plan view of the percussion hammer bit of \nFIG.', '12\na\n, which shows the bit face thereof.\n \nFIGS.', '12\nc \nand \n12\nd \nare perspective side views of the bit face of the percussion hammer bit of \nFIGS.', '12\na \nand \n12\nb. \n \nFIG.', '13\n is a cross-sectional view of a pointed cutting element, according to some embodiments of the present disclosure.\n \nFIG.', '14\n is a cross-sectional view of a domed-type cutting insert, according to some embodiments of the present disclosure.', 'FIGS.', '15\na\n-\n15\nd \nare perspective views of a vaulted chisel-type cutting element, according to some embodiments of the present disclosure.\n \nFIG.', '16\n is a perspective view of a bow chisel-type cutting element having a ridge with flat and curved sections, according to some embodiments of the present disclosure.', 'DETAILED DESCRIPTION\n \nFIG.', '1\n shows an embodiment of a road milling machine \n100\n that may be used in a road milling operation that may be used when preparing a road \n103\n for resurfacing.', 'The road milling machine \n100\n may include a plurality of picks \n102\n connected to a rotatable drum \n101\n.', 'As the rotatable drum \n101\n is rotated, the picks \n102\n may engage and degrade the road \n103\n, thereby leaving a surface ready for application of a fresh layer of gravel, asphalt, or some other material.\n \nFIG.', '2\n shows an embodiment of a rotatable drum \n201\n with a plurality of picks \n202\n arranged in a helical pattern around a circumference or outer surface of the rotatable drum \n201\n.', 'Each of the picks \n202\n may include a shank \n205\n that is optionally be inserted into a bore of an individual block \n204\n and which may be retained therein by friction, mechanical fasteners, or some other fastening means.', 'Each of the plurality of picks \n202\n may include a hardened tip \n206\n opposite the shank \n205\n.', 'The hardened tip \n206\n may include materials, geometry, or other features such that the hardened tip \n206\n is arranged or otherwise configured to degrade a material engaged by the hardened tip \n206\n.', 'For instance, the rotatable drum \n201\n and the plurality of picks \n202\n may be used in the road milling machine \n100\n of \nFIG.', '1\n, and used to degrade a road (e.g., road \n103\n of \nFIG.', '1\n).', 'FIG.', '3\na \nis a cross-sectional view of an example pick \n302\n that is optionally used in connection with the rotatable drum \n101\n of \nFIG.', '1\n or rotatable drum \n201\n of \nFIG.', '2\n.', 'The pick \n302\n may include a generally frustoconical body \n321\n with a shank \n305\n extending from a base thereof.', 'A hardened tip \n306\n may also extend from an upper end portion of the frustoconical body \n321\n and in a direction that is generally opposite the shank \n305\n.', 'An uppermost portion of the hardened tip \n306\n of \nFIG.', '3\na \nis shown in the enlarged view of \nFIG.', '3\nb\n, which illustrates the hardened tip \n306\n as including a cutting element \n360\n secured to a distal end thereof.', 'The cutting element \n360\n may include a substrate \n361\n that is axially symmetrical about a central axis \n362\n thereof.', 'A super-hard material \n363\n (e.g., polycrystalline diamond, cubic boron nitride, etc.) may be bonded, adhered, or otherwise coupled to the substrate \n361\n, such that the axis \n362\n passes through the super-hard material \n363\n.', 'Optionally, the super-hard material \n363\n is coupled to the uppermost end or side of the substrate \n361\n, and thus opposite the shank \n305\n of the pick \n302\n (see \nFIG.', '3\na\n).', 'In some embodiments, an external surface of the super-hard material \n363\n may include or define a ridge \n370\n or other feature that is generally perpendicular to the axis \n362\n.', 'A central point \n364\n may be identified at a position along the axis \n362\n at a distance from an external surface of the super-hard material \n363\n that is equal to the distance between the axis \n362\n and the outer surface of the substrate \n361\n.', 'For instance, the central point \n364\n may be on the axis \n362\n and axially offset from the ridge \n370\n by a distance equal to the radius (or half-width) of the substrate \n361\n.', 'In some embodiments, a greatest distance \n365\n measured from an external surface of the super-hard material \n363\n to the central point \n364\n may be oriented at an angle \n366\n from the axis \n362\n.', 'In some embodiments, the angle \n366\n may be between 10° and 60°.', 'For instance, the angle \n366\n may be within a range having lower, upper, or both lower and upper limits including any of 10°, 20°, 25°, 30°, 40°, 45°, 50°, 60°, and values therebetween.', 'In particular examples, the angle \n366\n may be between 20° and 50°, between 25° and 45°, or between 30° and 40°.', 'In still other embodiments, the angle \n366\n may be less than 25° or greater than 45°.', 'As can be seen in the illustrated embodiment, the greatest distance \n365\n may optionally be found at more than one point around a perimeter of the super-hard material \n363\n.', 'In at least some embodiments, including multiple locations at which the greatest distance \n365\n is present may allow for the super-hard material \n363\n to have one, two, or more axes of symmetry, or otherwise be re-usable.', 'For instance, the cutting element \n360\n may be used to degrade a material with the cutting element \n360\n in an orientation that primarily uses a portion of the cutting element \n360\n associated with one point having the greatest distance \n365\n.', 'Thereafter, the cutting element \n360\n, hardened tip \n306\n, or pick \n302\n may be removed and rotated to expose a fresh section of the ridge \n370\n (e.g., in the event the first cutting portion chips, cracks, dulls, etc.).', 'The thickness of the super-hard material \n363\n may be measured from the external surface of the super-hard material \n363\n to an interface between the super-hard material \n363\n and the substrate \n361\n, along a line passing through the central point \n364\n.', 'In some embodiments, the thickness of the super-hard material \n363\n may be constant within the super-hard material \n363\n.', 'In other embodiments, the thickness may vary.', 'For instance, a thickness of the super-hard material \n363\n is optionally greatest along the line defining the greatest distance \n365\n.', 'In other embodiments, the thickness of the super-hard material \n363\n may be greatest along a line that is offset from the line defining the greatest distance \n365\n.', 'In at least some embodiments, the thickness of the super-hard material \n363\n is greatest along a line between 0° and 90° from the axis \n362\n.', 'For instance, the angle of the line associated with the greatest thickness may be within a range having lower, upper, or both lower and upper limits including any of 0°, 15°, 25°, 35°, 45°, 55°, 60°, 75°, 90°, and values therebetween.', 'In particular examples, such an angle may be between 15° and 75°, between 25° and 45°, or between 30° and 40°.', 'In some embodiments, the ridge \n370\n may have a generally constant height, such that the outer edge in the cross-sectional view in \nFIG.', '3\nb \nis generally linear.', 'In some embodiments, the ridge \n370\n may transition to one or more side surfaces extending toward the substrate \n361\n.', 'Optionally, the transition between the side surfaces and the ridge \n370\n may be abrupt/discontinuous (e.g., two linear portions meeting at an angle or corner), or continuous (e.g., a curved, gradual transition).', 'In some embodiments, the ridge \n370\n may have a variable height.', 'For instance, the ridge \n370\n may be convexly or concavely curved, or a linear edge may have a variable height.', 'As can also be seen in the embodiment shown in \nFIG.', '3\nb\n, a transition zone \n367\n may be present at the interface between the substrate \n361\n and the super-hard material \n363\n.', 'Optionally, the thickness of the transition zone \n367\n may be generally constant, regardless of the thickness of the super-hard material \n363\n.', 'In other embodiments, the transition zone \n367\n may have a variable thickness (e.g., thicker at a thicker portion of the super-hard material \n363\n).', 'In some embodiments, the substrate \n361\n may include an elevated portion \n368\n.', 'The elevated portion \n368\n may protrude into the super-hard material \n363\n, such that a radial line perpendicular to the axis \n362\n would extend through at least a portion of the super-hard material \n363\n.', 'In some embodiments, the elevated portion \n368\n extends radially to a position between 0° and 90° from the axis \n362\n of the substrate \n361\n as measured from the central point \n364\n.', 'For instance, the elevated portion \n368\n may extend radially to an angular position that is within a range having lower, upper, or both lower and upper limits including any of 0°, 15°, 25°, 35°, 45°, 55°, 60°, 75°, 90° and values therebetween, from the axis \n362\n of the substrate \n361\n, as measured from the central point \n364\n.', 'In particular examples, such an angle may be between 15° and 75°, between 25° and 45°, or between 30° and 40°.', 'FIGS.', '4\na \nand \n4\nb \nare cross-sectional views of another example embodiment of a pick \n402\n with a cutting element \n460\n, which may be used in connection with tools and devices of the present disclosure.', 'The cutting element \n460\n may include a super-hard material \n463\n bonded or otherwise coupled to a substrate \n461\n having a central axis \n462\n extending axially therethrough.', 'For instance, the cutting element \n460\n may be secured to a distal end side, surface, or portion of the substrate \n461\n.', 'In the illustrated embodiment, an external surface of the super-hard material \n463\n includes a ridge \n470\n that protrudes from the substrate \n461\n and which is optionally tapered or otherwise contoured over its length across a width of the cutting element \n460\n.', 'For instance, the ridge \n470\n may be generally convex over its maximum length.', 'As can be seen in \nFIG.', '4\nb\n, for example, a greatest distance \n465\n measured from the external surface of the super-hard material \n463\n to a central point \n464\n (identified at a position along the axis \n462\n at a distance from an external surface of the super-hard material \n463\n equal to a radius or half-width of the substrate \n461\n) may be disposed at an angle \n466\n relative to the axis \n462\n.', 'In some embodiments, the angle \n466\n may be between 10° and 60°.', 'For instance, the angle \n466\n may be within a range having lower, upper, or both lower and upper limits including any of 10°, 20°, 25°, 30°, 40°, 45°, 50°, 60°, and values therebetween.', 'In particular examples, the angle \n466\n may be between 20° and 50°, between 25° and 45°, or between 30° and 40°.', 'In still other embodiments, the angle \n466\n may be less than 25° or greater than 45°.', 'In the illustrated embodiment, the greatest distance \n465\n is found at a single point on the surface of the super-hard material \n463\n.', 'In other embodiments, as discussed herein, the greatest distance \n465\n may be found at multiple points on the super-hard material \n463\n.', 'Additionally, in the illustrated embodiment, the substrate \n461\n optionally includes an elevated portion \n468\n having a depression \n469\n therein.', 'The depression \n469\n may be centered along the axis \n462\n in some embodiments, and may be symmetrical such that the substrate \n461\n is symmetrical about the axis \n462\n.', 'In other embodiments, the depression \n469\n may be asymmetric.\n \nFIGS.', '5\na \nand \n5\nb \nshow embodiments of example cutting elements \n560\na\n, \n560\nb\n.', 'The geometry of cutting element \n560\na \nmay be comparable to those shown in \nFIGS.', '3\na \nand \n3\nb\n, while the geometry of cutting element \n560\nb \nmay be comparable to those shown in \nFIGS.', '4\na \nand \n4\nb\n.', 'As can be seen, both cutting elements \n560\na \nand \n560\nb \nmay include a super-hard material \n563\na\n, \n563\nb \nbonded or otherwise coupled to a side (e.g., a distal end surface) of a substrate \n561\na\n, \n561\nb\n.', 'An external surface of the super-hard material \n563\na\n, \n563\nb \nmay include a ridge \n570\na\n, \n570\nb \nprotruding from a remainder of the external surface.', 'The ridge \n570\na \nis shown as being of a generally constant height relative to the substrate \n561\na\n, while the ridge \n570\nb \nmay have a variable height relative to the substrate \n561\nb. \n \nFIGS.', '6\na\n-\n6\nd \nshow embodiments of cutting elements \n660\na\n-\n660\nd\n, respectively, at various positions relative to a formation, road surface, or other degradable material \n603\na\n-\n603\nd\n.', 'Each of the cutting elements \n660\na\n-\n660\nd \nmay include a super-hard material \n663\na\n-\n663\nd \ncoupled to a substrate \n661\na\n-\n661\nd\n.', 'Each super-hard material \n663\na\n-\n663\nd \nmay have a ridge \n670\na\n-\n670\nd \nprotruding from an external surface thereof.', 'FIG.', '6\na \nshows cutting element \n660\na \nwith a length of the ridge \n670\na \nextending in a direction oriented at 0° from, and substantially perpendicular to, a surface of the degradable material \n603\na\n.', 'Further, a length of the ridge \n670\nb \nin \nFIG.', '6\nb \nis shown as extending in a direction oriented at 35° relative to the surface of the degradable material \n603\nb\n, while a length of the ridge \n670\nc \nof \nFIG.', '6\nc \nis oriented at 50° from the surface of the degradable material \n603\nc\n, and a length of the ridge \n670\nd \nof \nFIG.', '6\nd \nis oriented at 70° from the surface of the degradable material \n603\nd\n.', 'The position of the cutting element \n660\na\n-\n660\nd \nrelative to the surface of a degradable material (e.g., road surface, formation, rock, etc.) may affect how much of each ridge is presented to the degradable material, and thus the aggressiveness of each cutting element.', 'For example, with hard degradable materials, a ridge may be positioned less aggressively (i.e., at a lower angle) such that the degradable material rides up the ridge upon engagement until a sharp enough radius is obtained to degrade the material.', 'This may prolong a useful life of such a cutting element.', 'Accordingly, cutting elements as described herein may be secured to drill bits, picks, mining tools, or other cutting instruments and strategically placed and oriented to customize cutting aggressiveness, durability, and the like for specific locations or situations.\n \nFIGS.', '7\n-\n9\n show embodiments of additional example embodiments of cutting elements \n760\n, \n860\n, and \n960\n, respectively, which include a substrate \n761\n, \n961\n with a super-hard material \n763\n, \n863\n, \n963\n coupled to one end thereof.', 'In some embodiments, the super-hard material \n763\n, \n863\n, \n963\n may include a geometry arranged, designed, or otherwise configured to withstand high forces.', 'The illustrated example geometry may include an external surface including multiple ridges \n770\n, \n870\n extending radially outward from a common center \n771\n, \n871\n.', 'In some embodiments, a depression \n772\n, \n872\n may be located between each of the ridges \n770\n, \n870\n and may extend axially toward the substrate \n761\n, \n961\n.', 'The substrate \n761\n, \n961\n may have a substantially cylindrical shape, such that the common center \n771\n, \n871\n lies on a central axis \n962\n of the cylindrical shape.', 'The ridges \n770\n, \n870\n may intersect the axis \n962\n and may be equally or unequally angularly spaced around the common center \n771\n, \n871\n.', 'In some embodiments, the ridges \n770\n, \n870\n may be generally perpendicular to the axis \n962\n, angled at a non-perpendicular angel relative to the axis \n962\n, or generally convex or concave over a maximum length thereof.', 'Each of the ridges \n770\n, \n870\n may have a radius of curvature \n951\n.', 'In some embodiments, the radius of curvature \n951\n may be between 0.02 inch (0.51 mm) to 0.35 inch (8.89 mm) when viewed along a length of the corresponding ridge (e.g., perpendicular to the axis \n962\n).', 'For instance, the radius or curvature \n951\n of a ridge may be within a range having a lower, upper, or both lower and upper limits including any of 0.02 inch (0.51 mm), 0.05 inch (1.27 mm), 0.10 inch (2.54 mm), 0.20 inch (5.08 mm), 0.25 inch (6.35 mm), 0.30 inch (7.62 mm), 0.35 inch (8.89 mm), or values therebetween.', 'For instance, in some embodiments, the radius of curvature \n951\n of a ridge may be less than 0.25 inch (6.35 mm), greater than 0.05 inch (1.27 mm), between 0.03 inch (0.76 mm) and 0.30 inch (7.72 mm), between 0.05 inch (1.27 mm) and 0.25 inch (6.35 mm), or may be 0.105 inch (2.67 mm).', 'In other embodiments, the radius or curvature \n951\n of a ridge may be less than 0.02 inch (0.51 mm) or greater than 0.35 inch (8.89 mm).', 'In some embodiments, one or more ridges \n770\n, \n870\n may further have an additional radius of curvature \n952\n when viewed perpendicular to the length of the ridge \n770\n, \n879\n, and perpendicular to the axis \n952\n.', 'The radius or curvature \n952\n may, in some embodiments, be convex or concave, and may be between 0 inch (0 mm) and 5 inches (127 mm).', 'For instance, For instance, the radius or curvature \n952\n of a ridge may be within a range having a lower, upper, or both lower and upper limits including any of 0.000 inch (0.00 mm), 0.025 inch (0.64 mm), 0.050 inch (1.27 mm), 0.075 inch (1.91 mm), 0.100 inch (2.54 mm), 0.200 inch (5.08 mm), 0.500 inch (12.7 mm), 1.000 inch (25.4 mm), 2.500 inches (63.5 mm), 5.000 inches (127 mm), or values therebetween.', 'For instance, in some embodiments, the radius of curvature \n952\n of a ridge may be less than 3.000 inches (76.2 mm), greater than 0.075 inch (1.91 mm), between 0.050 inch (1.27 mm) and 4.000 inches (101.6 mm), between 0.075 inch (1.91 mm) and 3.000 inches (76.2 mm), or may be 1.790 inches (45.47 mm).', 'In other embodiments, the radius or curvature \n952\n of a ridge may greater than 5 inches (127 mm).', 'In some embodiments, the super-hard material \n763\n, \n863\n, \n963\n may include a generally conical or ogive periphery \n748\n, \n848\n.', 'The periphery \n748\n, \n848\n may be positioned, for instance, radially beyond a position between 25° and 45° from the axis \n962\n, although the periphery \n748\n, \n848\n may be positioned less than 25° or greater than 45° from the axis \n962\n in other embodiments.', 'The periphery \n748\n, \n848\n may narrow in a direction extending from adjacent the interface between the substrate \n761\n, \n961\n and the super-hard material \n763\n, \n863\n, \n963\n toward a distal end of the super-hard material \n763\n, \n863\n, \n963\n.', 'A boundary between each of the ridges \n770\n, \n870\n and the periphery \n748\n, \n848\n may, in some embodiments, include a transition such as a fillet, round, or chamfer \n773\n, \n873\n.', 'One or more, and potentially each, of the ridges \n770\n, \n870\n may optionally include an arched exterior culminating at a generally planar surface or linear edge, and curving on either side of each ridge toward the substrate \n761\n, \n961\n.', 'Further, each arched exterior may include a similar radius of curvature relative to the radius of curvature of each other arched exterior.', 'The ridges \n770\n, \n870\n may extend from the common center \n771\n, \n871\n to the periphery \n748\n, \n848\n where a transition may connect each of the ridges \n770\n, \n879\n.', 'The transition between each of the ridges \n770\n, \n870\n and the periphery \n748\n, \n848\n may include a chamfer, although in some embodiments the transition may be curved.', 'For instance, a radius of curvature \n953\n between a ridge \n770\n, \n870\n and the periphery \n748\n, \n848\n may be between 0.020 inch (0.51 mm) and 0.150 inch (3.81 mm) when viewed perpendicular to a ridge and perpendicular to the axis \n962\n, as shown in \nFIG.', '9\n.', 'For instance, the radius or curvature \n953\n may be 0.050 inch (1.27 mm).', 'In other embodiments, the radius of curvature \n953\n may be less than 0.02 inch (0.51 mm) or greater than 0.15 inch (3.81 mm).', 'The periphery \n748\n, \n848\n itself may be linear, or may include a concave or convex radius of curvature \n954\n.', 'In some embodiments, the radius of curvature may be convex and may be between 0.075 inch (1.91 mm) to 3.000 inches (76.2 mm) when viewed perpendicular to a ridge and perpendicular to the axis \n962\n, as shown in \nFIG.', '9\n.', 'For instance, the radius of curvature \n954\n may be 1.890 inches (48.01 mm).', 'Such values are illustrative, as in other embodiments the radius of curvature \n954\n may be less than 0.075 inch (1.91 mm) or greater than 3.000 inches (76.2 mm).', 'Further, when viewed in cross-section or as a side view, the periphery \n748\n, \n848\n may extend at an angle \n955\n relative to the axis \n962\n, as seen in \nFIG.', '9\n in which the view is perpendicular to the length of the ridge and perpendicular to the axis \n962\n.', 'Where the periphery \n748\n, \n848\n has a linear taper, the angle \n955\n may be determined based on the angle of the linear edge relative to the axis \n962\n.', 'Where the periphery \n748\n, \n848\n has a curved taper, the angle \n955\n may be determined based on a line through the starting and end points of the curved taper relative to the axis \n962\n.', 'In some embodiments, the angle \n955\n may be between 2.5° and 60°.', 'For instance, the angle \n955\n may be within a range having lower, upper, or both lower and upper values that include any of 2.5°, 5°, 10°, 20°, 30°, 35°, 40°, 45°, 50°, 60°, or values therebetween.', 'In particular examples, the angle \n955\n may be between 2.5° and 45°, between 5° and 35°, or between 17° and 27°.', 'For instance, the angle \n955\n may be 22°.', 'In other embodiments, the angle \n955\n may be less than 2.5° or greater than 60°.', 'In the embodiments shown in \nFIGS.', '7\n-\n9\n, one or more, and potentially each, of the depressions \n772\n, \n872\n between ridges \n770\n, \n870\n may include a center furrow \n747\n, \n847\n that is optionally equidistant from adjacent ridges \n770\n, \n870\n.', 'The depressions \n772\n, \n872\n may be symmetrical about their respective furrow \n747\n, \n847\n, with surfaces \n749\n, \n849\n on either side of each furrow \n747\n, \n847\n extending toward adjacent ridges \n770\n, \n870\n.', 'Such surfaces \n749\n, \n849\n may retreat gradually from either side of each ridge until they meet the periphery \n748\n, \n848\n.', 'In other embodiments, the depressions \n772\n, \n872\n may be asymmetrical about their respective furrow \n747\n, \n847\n.', 'In some embodiments, the surfaces \n749\n, \n849\n leading up to each of the adjacent ridges \n770\n, \n870\n may define or have a radius of curvature \n956\n when viewed along a ridge perpendicular to the axis \n962\n.', 'According to at least some embodiments, the radius of curvature \n956\n may be between 0.050 inch (1.27 mm) and 3.000 inches (76.2 mm), or between 0.500 inch (12.7 mm) and 2.000 inches (50.8 mm).', 'For instance, the radius of curvature \n956\n may be 1.000 inch (25.4 mm).', 'In other embodiments, the radius of curvature \n956\n may be less than 0.05 inch (1.27 mm) or greater than 3.000 inches (76.2 mm).', 'In some further embodiments, the surfaces \n749\n, \n849\n on either side of a furrow \n747\n, \n847\n may form an angle \n957\n with a surface opposite each of the ridges \n770\n, \n870\n when viewed along the ridge and perpendicular to the axis \n962\n, as shown in \nFIG.', '9\n.', 'The angle \n957\n may, in some embodiments, be between 70° and 160°, or between 95° and 115°.', 'For instance, the angle \n957\n may be between 100° and 105°.', 'In other embodiments, the angle \n957\n may be less than 70° or greater than 160°.', 'As shown, each of the depressions \n772\n, \n872\n may diverge from adjacent ridges \n770\n, \n870\n and extend a similar depth toward the substrate \n761\n, \n961\n.', 'In addition, each of the furrows \n747\n, \n847\n may extend radially outwardly from the common center \n771\n, \n871\n and extend further toward the substrate \n761\n, \n961\n in a radially outward direction.', 'In other embodiments, one or more depressions \n772\n, \n872\n may have a different depth, or a furrow \n747\n, \n847\n may extend radially inwardly at one or more locations along a length thereof.\n \nFIG.', '10\n is a side view of a mining machine \n1000\n performing an example mining operation that may be used when extracting valuable materials, such as coal, from the earth.', 'The mining machine \n1000\n may include a plurality of picks \n1002\n coupled to a rotatable drum \n1001\n similar to that shown in \nFIG. \n2\n.', 'As the rotatable drum \n1001\n rotates, the picks \n1002\n may engage and degrade a potentially valuable material \n1003\n that forms aggregate \n1033\n.', 'The aggregate \n1033\n may be removed by a conveyor \n1009\n.', 'Each of the plurality of picks \n1002\n may include a cutting element such as those described herein, including a cutting element with one or more ridges protruding therefrom.', 'Such ridges may be aligned with the direction of rotation of the rotatable drum \n1001\n.', 'Such alignment may allow the cutting elements to withstand higher forces in various applications.\n \nFIG.', '11\na \nschematically illustrates an example drilling system used in an earth boring operation used to explore for or extract subterranean oil, gas, or geothermal energy deposits from the earth.', 'In such operations, a drill bit \n1110\n may be coupled to an end of a drill string \n1112\n suspended from a derrick \n1114\n.', 'The derrick \n1114\n may rotate the drill string \n1112\n causing the drill bit \n1110\n to advance into an earthen formation \n1103\n.\n \nFIG.', '11\nb \nshows an example PDC, or “drag” drill bit \n1110\n including a threaded pin \n1122\n for connection to the drill string \n1112\n.', 'The drill bit \n1110\n may further have a plurality of blades \n1124\n protruding from a distal end opposite the threaded pin \n1122\n.', 'The blades \n1124\n and the distal end of the drill bit \n1110\n may define a bit face, and a plurality of cutting elements \n1160\n may be secured to the blades \n1124\n on the bit face of the drill bit \n1110\n.', 'The cutting elements \n1160\n may be positioned such that as the drill bit \n1110\n rotates, the cutting elements \n1160\n degrade the earthen formation \n1103\n to form or extend a wellbore in the earthen formation \n1103\n.', 'Some or each of the cutting elements \n1160\n may include a ridge protruding therefrom.', 'Such ridges may be aligned with the direction of rotation of the drill bit \n1110\n, which may allow the cutting elements to withstand higher forces in many applications.', 'In other applications, the cutting elements \n1160\n may be secured to the drill bit \n1110\n such that the ridge is positioned parallel, non-parallel, or perpendicular to a direction of rotation of the drill bit.', 'For example, cutting element \n1181\n may be positioned relatively parallel to a direction of rotation, cutting element \n1183\n may be positioned relatively perpendicular to a direction of rotation, while cutting element \n1182\n may be positioned somewhere in between.', 'Such positioning may affect how much of each ridge is presented to a formation and thus the aggressiveness of each cutting element.', 'This may prolong a useful life of such cutting elements.', 'Accordingly, cutting elements as described herein may be secured to drill bits or picks strategically to customize operation, durability, use, or the like at specific locations or for specific situations.\n \nFIG. \n12\na \nis a side view of an example percussion drill bit \n1210\n including an attachment end \n1212\n for connection to a drill string such as drill string \n1112\n illustrated in \nFIG.', '11\na\n.', 'Opposite the attachment end \n1212\n, the percussion drill bit has a bit face \n1214\n for impacting and breaking up a formation.', 'A central bit axis \n1202\n runs from the attachment end \n1202\n to the bit face \n1214\n.', 'An example of the bit face \n1214\n is further illustrated in \nFIG.', '12\nb \nwhich depicts the bit face \n1214\n of the percussion hammer bit \n1210\n having a plurality of cutting elements or inserts \n1220\n, \n1230\n, and \n1240\n coupled thereto.', 'The bit face \n1214\n may include a center region \n1216\n and a gage region \n1218\n, according to some embodiments of the present disclosure.', 'In such embodiments, the gage region \n1218\n is located around the periphery of the bit face \n1214\n, and generally corresponds to the maximum size or diameter of the bit face \n1214\n.', 'In some embodiments, the gage region \n1218\n fully or partially surrounds the center region \n1216\n.', 'In some embodiments, the gage region \n1218\n includes a single row of inserts around the periphery of the bit face \n1214\n, while in other embodiments, the gage region \n1218\n may include multiple rows (e.g., a gage row, and an adjacent-to-gage row).', 'Any number of cutting elements or inserts \n1220\n, \n1230\n, and \n1240\n may be coupled to, or otherwise disposed on the bit face \n1214\n, and the elements \n1220\n, \n1230\n, and \n1240\n may be arranged in any number of manners, configurations, patterns, and the like.', 'Moreover, the inserts \n1220\n, \n1230\n, and \n1240\n themselves may have any number of different shapes, forms, constructions, or other characteristics.', 'In some embodiments, the inserts \n1220\n are chisel-type inserts.', 'Embodiments of chisel-type cutters \n1220\n are shown in and described with respect to \nFIGS.', '3\nb\n, \n4\nb\n, \n5\na\n, \n5\nb\n, \n6\na\n-\n6\nd\n, \n7\n-\n9\n, \n15\na\n-\n15\nd\n, and \n16\n.', 'FIGS.', '15\na\n-\n15\nd \nillustrate multiple perspective views of a vaulted chisel-type insert \n1520\n, according to one embodiments of the present disclosure.', 'A vaulted chisel-type insert \n1520\n may be similar to the insert shown in and described with respect to \nFIG.', '3\nb\n, and may include a convex curvature in the ridge portion \n1570\n. \nFIG.', '16\n illustrates a perspective view of a bow chisel-type insert \n1620\n, which is similar to the insert shown in and described with respect to \nFIG.', '3\nb\n, and may include a ridge portion \n1670\n that includes flat and curved sections, according to some embodiments of the present disclosure.', 'In some embodiments, inserts \n1230\n are pointed-type (e.g., conical) cutting elements.', 'FIG.', '13\n illustrates a cross-sectional view of a pointed cutting element \n1330\n, according to some embodiments of the present disclosure.', 'In at least some embodiments, pointed cutting elements \n1330\n may include an ultra-hard material \n1310\n on a substrate \n1320\n, and the ultra-hard portion \n1310\n may include at least one apex \n1340\n having a small radius of curvature Rr.', 'In some embodiments, inserts \n1240\n are domed inserts.', 'FIG.', '14\n is a cross-sectional view of a domed-type insert \n1440\n, according to some embodiments.', 'Insert \n1440\n may comprise an ultra-hard layer \n1410\n and a substrate \n1420\n, as illustrated, or it may contain more or fewer ultra-hard layers.', 'In some embodiments, domed inserts \n1440\n include an ultra-hard layer \n1410\n or other outer layer or surface having a large radius of curvature RR.', 'In some embodiments, the center region \n1220\n of the bit \n1210\n includes at least one pointed cutting element \n1230\n.', 'A pointed cutting element in the center region may bear on-axis impact on the small-radius cutting tip to crush and gouge the formation.', 'Domed-type inserts \n1240\n may be found within the center region, the gage region, both, or neither.', 'In some embodiments, gage region \n1218\n may include at least one chisel-type cutting element \n1220\n.', 'A chisel-type cutting element may have durability similar to domed inserts, but with increased crushing, penetration, and cutting efficiency.', 'A chisel-type insert may allow for a sharper radius to cut in the forward direction of the bit, and may further have a sharp radius to cut the gage or at the side of the bit.', 'In addition, a chisel-type cutting element may exhibit increased resistance to off-axis impact forces, such as those that may be experienced in the gage region, as compared to pointed-type cutting elements.', 'The cutting element(s) \n1220\n may be oriented within the gage region for maximum impact resistance and rock fragmentation.', 'For example, the cutting element \n1220\n may be rotated to orient the ridge or chisel feature perpendicular to the direction of rotation of the drill bit.', 'In other embodiments, the chisel/ridge may be oriented at an angle that is not perpendicular to the direction of rotation, such as at +/−45° relative to the direction of rotation and/or the formation hole wall.', 'Combinations of orientations of multiple chisel-type cutters in the gage region may help promote crack formation or cause larger chip to be removed by the cutters.', 'For example, chisel-type cutters may be oriented at alternating +θ degrees/−θ degrees, where 0<θ<90 (forming a “W” type pattern), which may facilitate more efficient crack formation and crack propagation with the crack tips intersecting to form large chips.', 'In the same or other embodiments, a ridge or chisel type insert \n1220\n may be tilted so that the axis of the insert is not parallel to the bit axis.', 'FIGS.', '12\nc \nand \n12\nd \nillustrate perspective side views of the bit face \n1214\n, according to some embodiments of the present disclosure.', 'In \nFIG. \n12\nc\n, ridge cutting element \n1220\n is located in the gage region \n1218\n, and pointed cutting element \n1230\n is located in the center region \n1216\n.', 'The surface of the gage region \n1218\n may be about perpendicular to a line \n1204\n parallel to the central axis \n1202\n of drill bit \n1210\n, so that an axis \n1206\n of cutting element \n1220\n is about parallel to a line \n1204\n, which is parallel to the bit axis \n1202\n.', 'In \nFIG. \n12\nd\n, the chisel/ridge cutting element \n1220\n is located in gage region \n1218\n, and a pointed cutting element \n1230\n is located in the center region \n1216\n.', 'In some embodiments, a full or partial portion of the surface of the gage region \n1218\n may be angled and non-parallel and non-perpendicular with respect to the line \n1204\n parallel to central axis \n1202\n.', 'For example, at least a portion of the surface of gage region \n1218\n may be angled less than 90° with respect to the central axis \n1202\n.', 'The angle of the surface of gage region \n1218\n allows an axis \n1206\n of insert \n1220\n to be tilted with respect to central bit axis \n1202\n.', 'The unique shape of chisel-type cutters create impact resistance to both top impact and side impact forces, increasing the operational life of the insert and thereby the drill bit.', 'In some embodiments, the center region of the bit face includes a plurality of pointed-type elements, and the gage region includes a plurality of chisel-type elements.', 'This configuration may provide increased rate of penetration (ROP) relative to using smaller-radius pointed inserts or larger-radius domed inserts, as crushing and penetration can be increased while durability can be maintained by including chisel cutters in regions where inserts may experience greater off-axis loads.', 'In some embodiments, pointed-type cutters are used in areas that experience primarily on-axis loads, while chisel-type cutters are used in areas that experience off-axis loads.', 'While embodiments of cutting elements and cutting tools have been primarily described with reference to drilling, road milling, and mining operations, the devices described herein may be used in applications other than the drilling, mining, or road milling.', 'In other embodiments, cutting elements and cutting tools according to the present disclosure may be used outside a wellbore, mining, or road milling environment.', 'For instance, tools and assemblies of the present disclosure may be used in a wellbore used for placement of utility lines, in a medical procedure (e.g., to clear blockages within an artery), in a manufacturing industry (e.g., to expand a diameter of a bore within a component), in other industries (e.g., aquatic, automotive, etc.), or in a wellbore enlargement application (e.g., with an underreamer).', 'The articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements in the preceding descriptions.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'Where a range of values includes various lower or upper limits, any two values may define the bounds of the range, or any single value may define an upper limit (e.g., up to 50%) or a lower limit (at least 50%).', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'It should be understood that “proximal,” “distal,” “uphole,” and “downhole” are relative directions.', 'As used herein, “proximal” and “uphole” should be understood to refer to a direction toward the surface, rig, operator, or the like.', '“Distal” or “downhole” should be understood to refer to a direction away from the surface, rig, operator, or the like.', 'When the word “may” is used herein, such term should be interpreted as meaning that the identified feature, function, characteristic, or the like is present in some embodiments, but is optional and not present in other embodiments.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'The scope of the disclosure is, therefore, indicated by the appended claims rather than by the foregoing description.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.', 'Features of various embodiments described herein may be used in combination, except to the extent such features are mutually exclusive.']

['1.', 'A cutting element, comprising:\na substrate that is axially symmetric about a central axis thereof, the substrate having a radius that is perpendicular to the central axis and which extends from the central axis to an outer surface of the substrate;\na super-hard material body coupled to the substrate such that the central axis passes through the super-hard material body, the super-hard material having an external surface defining at least one ridge protruding from a remainder of the external surface, the at least one ridge having an outer edge that is generally linear, wherein the super-hard material body is formed from polycrystalline diamond; and\na central point on the central axis, the central point on the central axis offset from the external surface of the super-hard material body by a first distance equal to the radius of the substrate, a second distance measured from the external surface of the super-hard material body to the central point being greatest at a position between 25° and 45° from the central axis of the substrate, the second distance being larger than the first distance, and the distance measured from the external surface of the super-hard material body to the central point being greatest at more than one position on the external surface of the super-hard material body.', '2.', 'The cutting element of claim 1, the at least one ridge being perpendicular to the central axis of the substrate.', '3.', 'The cutting element of claim 1, the at least one ridge being generally convex over a length thereof.', '4.', 'The cutting element of claim 1, the at least one ridge including a plurality of ridges extending from a common center of the external surface.', '5.', 'The cutting element of claim 4, the common center being on the central axis of the substrate and the plurality of ridges being equally spaced around the common center.', '6.', 'The cutting element of claim 1, at least a portion of the external surface of the super-hard material body radially beyond a position between 25° and 45° from the central axis of the substrate from the central point forming part of a cone or ogive shape.', '7.', 'The cutting element of claim 6, the portion of the external surface forming part of the cone shape forming an angle between 5° and 35° with the central axis of the substrate, when viewed perpendicular to a length of the at least one ridge and perpendicular to the central axis of the substrate.\n\n\n\n\n\n\n8.', 'The cutting element of claim 6, a boundary between the at least one ridge and the part of the cone shape or ogive shape including a chamfer.', '9.', 'The cutting element of claim 1, the external surface forming an angle between 70° and 160° as the external surface retreats on either side of the at least one ridge, when viewed along a length of the at least one ridge and perpendicular to the central axis of the substrate.\n\n\n\n\n\n\n10.', 'The cutting element of claim 1, a transition zone at an interface between the super-hard material body and the substrate having a substantially constant thickness regardless of the thickness of the super-hard material body.', '11.', 'The cutting element of claim 1, the at least one ridge including a radius of curvature between 0.050 inch and 0.250 inch, when viewed along the ridge and perpendicular to the central axis of the substrate.\n\n\n\n\n\n\n12.', 'The cutting element of claim 1, the substrate being coupled to a drill bit or pick.', '13.', 'The cutting element of claim 1, the central point being located in the substrate.\n\n\n\n\n\n\n14.', 'A cutting element, comprising:\na substrate including: a substrate radius, the substrate radius being measured from a longitudinal axis to an outer surface of the substrate, the substrate being formed from a carbide material; a distal surface; and an elevated portion extending from the distal surface; and\na ridge body protruding from and bonded to the distal surface to thereby form an interface, an external surface of the ridge body defining at least one ridge having an outer edge that is generally linear, the longitudinal axis extending through the at least one ridge of the ridge body, the ridge body being formed of polycrystalline diamond of a variable thickness relative to the interface, and the elevated portion protruding into the at least one ridge,\nwherein at a central point within the cutting element and offset from the external surface of the ridge body along the longitudinal axis by the substrate radius, a distance from the central point to the external surface of the ridge body on the at least one ridge increases from when aligned with the longitudinal axis to be greatest at an angle between 25° and 45° from the longitudinal axis, and\nwherein the variable thickness of the ridge body, measured from the external surface of the ridge body to the interface along a line passing through the central point, has a greatest value at the position between 25° and 45° from the longitudinal axis of the substrate.\n\n\n\n\n\n\n15.', 'The cutting element of claim 14, the elevated portion including a depression at the central axis of the substrate.', '16.', 'The cutting element of claim 14, the elevated portion extending radially to a position between 25° and 45° from the longitudinal axis of the substrate from the central point.', '17.', 'The cutting element of claim 14, wherein a radial line perpendicular to the longitudinal axis extends through at least a portion of the elevated portion and the ridge body.']

['FIG.', '1 is a side view of a road milling machine performing a road milling operation, according to some embodiments of the present disclosure.', '; FIG.', '2 is a front view of a rotatable drum including a plurality of picks, according to some embodiments of the present disclosure.', '; FIG.', '3a is a longitudinal cross-sectional view of a pick with a cutting element on a tip thereof, according to some embodiments of the present disclosure.', '; FIG.', '3b is an enlarged view of the cutting element of FIG.', '3a. ;', 'FIG.', '4a is a longitudinal cross-sectional section view a pick with a cutting element on a tip thereof, according to additional embodiments of the present disclosure.', '; FIG.', '4b is an enlarged view of the cutting element of FIG.', '4a.', '; FIG.', '5a is a perspective view of cutting element having a generally constant height ridge on the outer surface thereof, according to some embodiments of the present disclosure.', '; FIG.', '5b is a perspective view of an embodiment of a cutting element having a convex ridge on the outer surface thereof, according to some embodiments of the present disclosure.;', 'FIGS.', '6a-6d are side views of cutting elements at various positions relative to a degradable material, according to some embodiments of the present disclosure.', '; FIG. 7 is a perspective view of a cutting element including ridges extending from a common center, according to some embodiments of the present disclosure.; FIG. 8 is a plan view of a cutting element including ridges extending from a common center, according to some embodiments of the present disclosure.', '; FIG.', '9 is a side view of the cutting element including ridges extending from a common center, according to some embodiments of the present disclosure.; FIG.', '10 is a side view of a mining machine performing a mining operation, according to some embodiments of the present disclosure.', '; FIG. 11a is schematic view of a drilling system for use in performing an earth-boring operation, according to some embodiments of the present disclosure.', '; FIG.', '11b is a perspective view of an example drill bit having cutting elements thereon, and which can be used in the drilling system of FIG. 11a. ; FIG.', '12a is a side view of a percussion hammer bit, according to some embodiments of the present disclosure.', '; FIG. 12b is a plan view of the percussion hammer bit of FIG. 12a, which shows the bit face thereof.; FIGS. 12c and 12d are perspective side views of the bit face of the percussion hammer bit of FIGS. 12a and 12b. ; FIG.', '13 is a cross-sectional view of a pointed cutting element, according to some embodiments of the present disclosure.', '; FIG.', '14 is a cross-sectional view of a domed-type cutting insert, according to some embodiments of the present disclosure.;', 'FIGS.', '15a-15d are perspective views of a vaulted chisel-type cutting element, according to some embodiments of the present disclosure.', '; FIG.', '16 is a perspective view of a bow chisel-type cutting element having a ridge with flat and curved sections, according to some embodiments of the present disclosure.', '; FIG.', '1 shows an embodiment of a road milling machine 100 that may be used in a road milling operation that may be used when preparing a road 103 for resurfacing.', 'The road milling machine 100 may include a plurality of picks 102 connected to a rotatable drum 101.', 'As the rotatable drum 101 is rotated, the picks 102 may engage and degrade the road 103, thereby leaving a surface ready for application of a fresh layer of gravel, asphalt, or some other material.; FIG.', '2 shows an embodiment of a rotatable drum 201 with a plurality of picks 202 arranged in a helical pattern around a circumference or outer surface of the rotatable drum 201.', 'Each of the picks 202 may include a shank 205 that is optionally be inserted into a bore of an individual block 204 and which may be retained therein by friction, mechanical fasteners, or some other fastening means.', 'Each of the plurality of picks 202 may include a hardened tip 206 opposite the shank 205.', 'The hardened tip 206 may include materials, geometry, or other features such that the hardened tip 206 is arranged or otherwise configured to degrade a material engaged by the hardened tip 206.', 'For instance, the rotatable drum 201 and the plurality of picks 202 may be used in the road milling machine 100 of FIG.', '1, and used to degrade a road (e.g., road 103 of FIG.', '1).;', 'FIG.', '3a is a cross-sectional view of an example pick 302 that is optionally used in connection with the rotatable drum 101 of FIG.', '1 or rotatable drum 201 of FIG.', '2.', 'The pick 302 may include a generally frustoconical body 321 with a shank 305 extending from a base thereof.', 'A hardened tip 306 may also extend from an upper end portion of the frustoconical body 321 and in a direction that is generally opposite the shank 305.', 'An uppermost portion of the hardened tip 306 of FIG.', '3a is shown in the enlarged view of FIG.', '3b, which illustrates the hardened tip 306 as including a cutting element 360 secured to a distal end thereof.', 'The cutting element 360 may include a substrate 361 that is axially symmetrical about a central axis 362 thereof.', 'A super-hard material 363 (e.g., polycrystalline diamond, cubic boron nitride, etc.) may be bonded, adhered, or otherwise coupled to the substrate 361, such that the axis 362 passes through the super-hard material 363.', 'Optionally, the super-hard material 363 is coupled to the uppermost end or side of the substrate 361, and thus opposite the shank 305 of the pick 302 (see FIG.', '3a).;', 'FIGS. 4a and 4b are cross-sectional views of another example embodiment of a pick 402 with a cutting element 460, which may be used in connection with tools and devices of the present disclosure.', 'The cutting element 460 may include a super-hard material 463 bonded or otherwise coupled to a substrate 461 having a central axis 462 extending axially therethrough.', 'For instance, the cutting element 460 may be secured to a distal end side, surface, or portion of the substrate 461.; FIGS.', '5a and 5b show embodiments of example cutting elements 560a, 560b.', 'The geometry of cutting element 560a may be comparable to those shown in FIGS.', '3a and 3b, while the geometry of cutting element 560b may be comparable to those shown in FIGS. 4a and 4b.', 'As can be seen, both cutting elements 560a and 560b may include a super-hard material 563a, 563b bonded or otherwise coupled to a side (e.g., a distal end surface) of a substrate 561a, 561b.', 'An external surface of the super-hard material 563a, 563b may include a ridge 570a, 570b protruding from a remainder of the external surface.', 'The ridge 570a is shown as being of a generally constant height relative to the substrate 561a, while the ridge 570b may have a variable height relative to the substrate 561b.', '; FIGS.', '6a-6d show embodiments of cutting elements 660a-660d, respectively, at various positions relative to a formation, road surface, or other degradable material 603a-603d.', 'Each of the cutting elements 660a-660d may include a super-hard material 663a-663d coupled to a substrate 661a-661d.', 'Each super-hard material 663a-663d may have a ridge 670a-670d protruding from an external surface thereof.', 'FIG.', '6a shows cutting element 660a with a length of the ridge 670a extending in a direction oriented at 0° from, and substantially perpendicular to, a surface of the degradable material 603a.', 'Further, a length of the ridge 670b in FIG.', '6b is shown as extending in a direction oriented at 35° relative to the surface of the degradable material 603b, while a length of the ridge 670c of FIG.', '6c is oriented at 50° from the surface of the degradable material 603c, and a length of the ridge 670d of FIG.', '6d is oriented at 70° from the surface of the degradable material 603d.', 'The position of the cutting element 660a-660d relative to the surface of a degradable material (e.g., road surface, formation, rock, etc.) may affect how much of each ridge is presented to the degradable material, and thus the aggressiveness of each cutting element.', 'For example, with hard degradable materials, a ridge may be positioned less aggressively (i.e., at a lower angle) such that the degradable material rides up the ridge upon engagement until a sharp enough radius is obtained to degrade the material.', 'This may prolong a useful life of such a cutting element.', 'Accordingly, cutting elements as described herein may be secured to drill bits, picks, mining tools, or other cutting instruments and strategically placed and oriented to customize cutting aggressiveness, durability, and the like for specific locations or situations.; FIGS.', '7-9 show embodiments of additional example embodiments of cutting elements 760, 860, and 960, respectively, which include a substrate 761, 961 with a super-hard material 763, 863, 963 coupled to one end thereof.', 'In some embodiments, the super-hard material 763, 863, 963 may include a geometry arranged, designed, or otherwise configured to withstand high forces.', 'The illustrated example geometry may include an external surface including multiple ridges 770, 870 extending radially outward from a common center 771, 871.', 'In some embodiments, a depression 772, 872 may be located between each of the ridges 770, 870 and may extend axially toward the substrate 761, 961.; FIG.', '10 is a side view of a mining machine 1000 performing an example mining operation that may be used when extracting valuable materials, such as coal, from the earth.', 'The mining machine 1000 may include a plurality of picks 1002 coupled to a rotatable drum 1001 similar to that shown in FIG.', '2.', 'As the rotatable drum 1001 rotates, the picks 1002 may engage and degrade a potentially valuable material 1003 that forms aggregate 1033.', 'The aggregate 1033 may be removed by a conveyor 1009.', 'Each of the plurality of picks 1002 may include a cutting element such as those described herein, including a cutting element with one or more ridges protruding therefrom.', 'Such ridges may be aligned with the direction of rotation of the rotatable drum 1001.', 'Such alignment may allow the cutting elements to withstand higher forces in various applications.; FIG. 11a schematically illustrates an example drilling system used in an earth boring operation used to explore for or extract subterranean oil, gas, or geothermal energy deposits from the earth.', 'In such operations, a drill bit 1110 may be coupled to an end of a drill string 1112 suspended from a derrick 1114.', 'The derrick 1114 may rotate the drill string 1112 causing the drill bit 1110 to advance into an earthen formation 1103.', '; FIG.', '11b shows an example PDC, or “drag” drill bit 1110 including a threaded pin 1122 for connection to the drill string 1112.', 'The drill bit 1110 may further have a plurality of blades 1124 protruding from a distal end opposite the threaded pin 1122.', 'The blades 1124 and the distal end of the drill bit 1110 may define a bit face, and a plurality of cutting elements 1160 may be secured to the blades 1124 on the bit face of the drill bit 1110.', 'The cutting elements 1160 may be positioned such that as the drill bit 1110 rotates, the cutting elements 1160 degrade the earthen formation 1103 to form or extend a wellbore in the earthen formation 1103.', 'Some or each of the cutting elements 1160 may include a ridge protruding therefrom.', 'Such ridges may be aligned with the direction of rotation of the drill bit 1110, which may allow the cutting elements to withstand higher forces in many applications.', 'In other applications, the cutting elements 1160 may be secured to the drill bit 1110 such that the ridge is positioned parallel, non-parallel, or perpendicular to a direction of rotation of the drill bit.', 'For example, cutting element 1181 may be positioned relatively parallel to a direction of rotation, cutting element 1183 may be positioned relatively perpendicular to a direction of rotation, while cutting element 1182 may be positioned somewhere in between.', 'Such positioning may affect how much of each ridge is presented to a formation and thus the aggressiveness of each cutting element.', 'This may prolong a useful life of such cutting elements.', 'Accordingly, cutting elements as described herein may be secured to drill bits or picks strategically to customize operation, durability, use, or the like at specific locations or for specific situations.; FIG. 12a is a side view of an example percussion drill bit 1210 including an attachment end 1212 for connection to a drill string such as drill string 1112 illustrated in FIG. 11a.', 'Opposite the attachment end 1212, the percussion drill bit has a bit face 1214 for impacting and breaking up a formation.', 'A central bit axis 1202 runs from the attachment end 1202 to the bit face 1214.', 'An example of the bit face 1214 is further illustrated in FIG. 12b which depicts the bit face 1214 of the percussion hammer bit 1210 having a plurality of cutting elements or inserts 1220, 1230, and 1240 coupled thereto.', 'The bit face 1214 may include a center region 1216 and a gage region 1218, according to some embodiments of the present disclosure.', 'In such embodiments, the gage region 1218 is located around the periphery of the bit face 1214, and generally corresponds to the maximum size or diameter of the bit face 1214.', 'In some embodiments, the gage region 1218 fully or partially surrounds the center region 1216.', 'In some embodiments, the gage region 1218 includes a single row of inserts around the periphery of the bit face 1214, while in other embodiments, the gage region 1218 may include multiple rows (e.g., a gage row, and an adjacent-to-gage row).']

US11920079

Compositions and methods for well cementing

Dec 10, 2021

Bipin Jain, Shameed Ashraf

SCHLUMBERGER TECHNOLOGY CORPORATION

Nelson et al., “Laboratory Testing, Evaluation and Analysis of Well Cements,” in Nelson EB and Guillot D (eds.): Well Cementing—2nd Edition, Schlumberger, 2006, pp. 641-643.; Nelson et al., “Special Cement Systems,” in Nelson EB and Guillot D (eds.): Well Cementing—2nd Edition, Schlumberger, 2006, pp. 235-237.; International Search Report and Written Opinion issued in International Patent application PCT/US2022/052249 dated Apr. 17, 2023, 12 pages.; International Search Report and Written Opinion issued in International Patent application PCT/US2022/052233 dated Apr. 17, 2023, 9 pages.; International Search Report and Written Opinion issued in International Patent application PCT/US2022/052257 dated Apr. 17, 2023, 13 pages.; Office Action issued in U.S. Appl. No. 17/643,701 dated Oct. 11, 2023, 14 pages.

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2457974; May 2012; EP; 2014078069; May 2014; WO; 2015195596; December 2015; WO; WO-2017023159; February 2017; WO; 2018144355; August 2018; WO

['The effectiveness of expansive cement systems may be diluted when, during a well cementing operation, commingling takes place between the cement slurry and a spacer fluid, a drilling fluid, or both.', 'Incorporating expansive agents in the spacer fluid or drilling fluid may reduce or negate the loss of expansion at the cement slurry/spacer interface or the cement slurry/drilling fluid interface, thereby promoting zonal isolation throughout the cemented interval.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThe statements in this section merely provide background information related to the present disclosure and may not constitute prior art.', 'The present disclosure broadly relates to well cementing.', 'More particularly the invention relates to compositions that contain materials that expand upon hydration, thereby improving zonal isolation in a subterranean well.', 'Good bonding between set cement and casing, and between the set cement and the formation, is essential for effective zonal isolation.', 'Poor bonding limits production, and reduces the effectiveness of stimulation treatments.', 'Communication between zones can be caused by inadequate drilling fluid removal, poor cement/formation bonding, expansion and contraction of the casing resulting from internal pressure or thermal stress, and cement contamination by drilling or formation fluids.', 'Under such circumstances, a small gap or “microannulus” may develop at the cement/casing or the cement/formation interface.', 'Cement systems that expand slightly after setting are a proven means of sealing microannuli and improving primary cementing results.', 'The improved bonding is the result of mechanical resistance or tightening of the cement against the pipe and formation.', 'Portland cement manufacturers limit the amount of certain alkaline impurities to avoid expansion of the set cement, a condition called “unsoundness.”', 'In an unrestrained environment such as a road or building, expansion of the set cement can result in cracking and failure.', 'In a wellbore environment, however, the cement is restrained by the casing and, when competent, the formation; consequently, once the cement has expanded to eliminate void spaces, further expansion reduces internal cement porosity.', 'Most expansive well cement systems rely upon the formation of the mineral ettringite, after the cement has set.', 'Ettringite crystals have a greater bulk volume than the components from which they form; consequently, expansion occurs because of the internal pressure exerted upon crystallization.', 'Today the most common method for preparing ettringite-base expansive cements is to add calcium sulfate hemihydrate (CaSO\n4\n·½ H\n2\nO) to a portland cement that contains at least 5 wt % tricalcium aluminate (abbreviated as C\n3\nA).', 'A limitation of ettringite-base systems is their inability to provide significant expansion at curing temperatures above about 170° F. (76° C.).', 'Ettringite is not stable at higher temperatures, and converts to a more dense calcium sulfoaluminate hydrate and gypsum.', 'Cement slurries containing high concentrations of NaCl, Na\n2\nSO\n4 \nor both were among the earliest expansive well cements.', 'After setting, cement expansion occurs because of internal pressure exerted by the crystallization of the salts within pores, and by chlorosilicate reactions.', 'These systems are effective at temperatures up to about 400° F. (204° C.).', 'Calcium oxide and magnesium oxide provide an expansive force within the cement matrix resulting from hydration to their respective hydroxides.', 'The hydrated material occupies more space than that of the original ingredients.', 'CaO may be more effective than MgO at curing temperatures below about 60° C. (140° F.).', 'For well cementing operations, MgO may be calcined at temperatures between about 700° C. and 2000° C., or', 'between 1100° C. and 1300° C.', 'Such calcination may delay the expansion reaction until after the cement slurry sets.', 'In some cases, blends of CaO and calcined MgO may be employed to provide effective expansion throughout a wider curing temperature range.', 'A thorough discussion concerning expanding cement systems may be found in the following publication.', 'Nelson E B et al.: “Special Cement Systems,” in Nelson E B and Guillot D (eds.):', 'Well Cementing—\n2\nnd \nEdition, Schlumberger (2006) 235-237.', 'During a well cementing operation, the cement slurry may contact a spacer fluid or a drilling fluid.', 'During displacement in the well, operators endeavor to minimize commingling of the cement slurry with other fluids; however, should such commingling take place, dilution of the cement slurry may occur, possibly resulting in suboptimal zonal isolation.', 'SUMMARY\n \nApplicant has determined that including one or more expanding agents in a spacer fluid, drilling fluid or both may minimize the deleterious effects arising from commingling with the cement slurry, thereby preserving cement slurry expansion and promoting zonal isolation.', 'In an aspect, embodiments relate to compositions comprising water, a viscosifying agent and an expanding agent comprising calcium oxide or calcined magnesium oxide or both.', 'In a further aspect, embodiments relate to methods comprising preparing a spacer fluid the comprises water, a viscosifying agent and an expanding agent comprising calcium oxide, calcined magnesium oxide or both.', 'During a well cementing operation, the spacer fluid is placed in the well such that the spacer fluid flows between a drilling fluid and a cement slurry.', 'The spacer fluid commingles with the drilling fluid or the cement slurry, thereby forming an interface.', 'The cement slurry and the interface are cured, wherein the interface expands or does not shrink upon the curing.', 'In a further aspect, embodiments relate to compositions comprising a non-aqueous liquid and an expanding agent comprising calcium oxide or calcined magnesium oxide or both.', 'In a further aspect, embodiments relate to methods comprising preparing a drilling fluid comprising a non-aqueous fluid and an expanding agent comprising calcium oxide or calcined magnesium oxide or both.', 'During a well cementing operation, the drilling fluid is placed in the well such that the drilling fluid flows ahead of a cement slurry.', 'The drilling fluid commingles with the cement slurry, thereby forming an interface.', 'The cement slurry and the interface are cured, wherein the interface expands or does not shrink upon the curing.', 'In a further aspect, embodiments relate to compositions comprising an aqueous cement slurry and a non-aqueous additive comprising a suspension of an expanding agent comprising calcium oxide or a mixture of calcium oxide and calcined magnesium oxide.', 'In a further aspect, embodiments relate to methods comprising preparing a composition comprising an aqueous cement slurry and a non-aqueous additive comprising a suspension of an expanding agent comprising calcium oxide and calcined magnesium oxide or both.', 'During a well cementing operation, the cement slurry is placed in the well such that the cement slurry flows behind a spacer fluid or a drilling fluid or both.', 'The spacer fluid or the drilling fluid may commingle with the cement slurry, thereby forming an interface.', 'The cement slurry and the interface are cured, wherein the interface expands or does not shrink upon the curing.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a photograph of a linear expansion cell.\n \nFIG.', '2\n presents linear expansion data from expansive cement slurries contaminated by an oil-base drilling fluid, with and without an expansion agent in the drilling fluid.\n \nFIG.', '3\n presents linear expansion data from expansive cement slurries contaminated by an aqueous spacer fluid, with and without an expansion agent in the spacer fluid.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of the present disclosure.', 'However, it may be understood by those skilled in the art that the methods of the present disclosure may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', "At the outset, it should be noted that in the development of any such actual embodiment, numerous implementation—specific decisions are made to achieve the developer's specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort might be complex and time consuming but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'In addition, the composition used/disclosed herein can also comprise some components other than those cited.', 'In the summary of the disclosure and this detailed description, each numerical value should be read once as modified by the term “about” (unless already expressly so modified), and then read again as not so modified unless otherwise indicated in context.', 'The term about should be understood as any amount or range within 10% of the recited amount or range (for example, a range from about 1 to about 10 encompasses a range from 0.9 to 11).', 'Also, in the summary and this detailed description, it should be understood that a concentration range listed or described as being useful, suitable, or the like, is intended that any concentration within the range, including the end points, is to be considered as having been stated.', 'For example, “a range of from 1 to 10” is to be read as indicating each possible number along the continuum between about 1 and about 10.', 'Furthermore, one or more of the data points in the present examples may be combined together, or may be combined with one of the data points in the specification to create a range, and thus include each possible value or number within this range.', 'Thus, even if specific data points within the range, or even no data points within the range, are explicitly identified or refer to a few specific, it is to be understood that inventors appreciate and understand that any data points within the range are to be considered to have been specified, and that inventors possessed knowledge of the entire range and the points within the range.\n \nSpacer Fluids Containing Expanding Agents\n \nIn an aspect, embodiments relate to compositions comprising water, a viscosifying agent and an expanding agent comprising calcium oxide or calcined magnesium oxide or both.', 'Such compositions may be spacer fluids.', 'In a further aspect, embodiments relate to methods comprising preparing a spacer fluid the comprises water, a viscosifying agent and an expanding agent comprising calcium oxide, calcined magnesium oxide or both.', 'During a well cementing operation, the spacer fluid is placed in the well such that the spacer fluid flows between a drilling fluid and a cement slurry.', 'The spacer fluid commingles with the drilling fluid or the cement slurry, thereby forming an interface.', 'The cement slurry and the interface are cured, wherein the interface expands or does not shrink upon the curing.', 'The cement slurry may comprise portland cement, pozzolan cement, gypsum cement, high alumina cement, slag cement, lime-silica blends or geopolymer cements or combinations thereof.', 'The volume ratio between the cement slurry and the spacer fluid in the commingled cement slurry and spacer fluid may be between 99:1 and 1:99.', 'For both aspects, the MgO may be calcined at temperatures between about 700° C. and 2000° C., or between 1100° C. and 1300° C.', 'For both aspects, the viscosifying agent may comprise an organophilic clay, hydrophobically modified silica, hydrophobically modified biopolymers or hydrophobically modified synthetic polymers or combinations thereof.', 'The hydrophobically modified biopolymer may comprise acetone-formaldehyde-sodium bisulfate polymer and D-Glucopyranuoic acid, polymer with 6-deoxy-L-mannose, D-glucose and D-mannose, calcium potassium sodium salt.', 'The weight ratio between the acetone-formaldehyde-sodium bisulfate polymer and the D-Glucopyranuoic acid, polymer with 6-deoxy-L-mannose, D-glucose and D-mannose, calcium potassium sodium salt may be between 80:20 and 20:80, or between 66.7:33.3 and 33.3:66.7.', 'For both aspects, the viscosifying agent may further comprise bentonite, present at a concentration in the viscosifying agent between 0.1 wt % and 10 wt %, or between 0.5 wt % and 5.0 wt %.', 'For both aspects, the viscosifying agent may be present in the composition at a concentration between 0.1 wt % and 10 wt %, or between 0.5% and 5.0 wt %.', 'For both aspects, the expanding agent may be present in the composition at a concentration between 0.1 wt % and 20 wt %, or between 0.5 wt % and 10 wt %.', 'The expanding agent may be a blend of calcium oxide and calcined magnesium oxide.', 'The weight ratio between the calcium oxide and the calcined magnesium oxide may vary between 10:90 and 90:10, or between 60:40 and 40:60.', 'For both aspects, the expanding agent may be suspended in a non-aqueous additive comprising a hydrocarbon liquid, and the expanding agent may be present in the non-aqueous additive at a concentration between 10 wt % and 80 wt %, or between 30 wt % and 60 wt %.', 'The hydrocarbon liquid may comprise alkanes, alkenes, alkynes, cycloalkanes, aromatic hydrocarbons, natural gas liquids, liquid paraffins, naphthas, mineral oils, crude oils, synthesized hydrocarbon liquids, fuel oils, diesels, gasolines, biomass derived hydrocarbon liquids, coal derived hydrocarbon liquids, or kerosine, or mixtures thereof.', 'The hydrocarbon liquid may be Escaid™ 110, available from ExxonMobil.', 'For both aspects, the non-aqueous additive may further comprise a dispersant comprising polynaphthalene sulfonate, sulfonated acetone formaldehyde condensate, polycarboxylate ethers or microparticles or combinations thereof.', 'The dispersant may be present in the non-aqueous additive at a concentration between 0.1 wt % and 20 wt %, or between 2.0 wt % and 10 wt %.', 'For both aspects, the non-aqueous additive may further comprise an emulsifier comprising polysorbates or sorbitan esters, or both.', 'The emulsifier may be present at a concentration between 0.01 wt % and 10 wt %, or 1 wt % to 5 wt %.', 'For both aspects, the expanding agent may be encapsulated by a coating having a thickness between about 2 μm and 80 μm.', 'The coating may comprise a polymer comprising a polyester, a polyacrylate, an epoxy, a polyhydroxyacid, a polypeptide, a polyesteramide, a polysulfide, a polysiloxane, a block copolymer comprising blocks joined through ester bonds, or a block copolymer comprising blocks joined through amide bonds, or combinations thereof.', 'Or, the coating may comprise silica that is sprayed onto the encapsulating agent as a silicate solution.', 'For both aspects, the compositions may further comprise a weighting agent comprising silica, barite, hematite, calcium carbonate, ilmenite or manganese tetraoxide or combinations thereof.', 'The density of the composition may therefore vary between about 10 lbm/gal (1200 kg/m\n3\n) and about 24 lbm/gal (2880 kg/m\n3\n).', 'To achieve lower densities, for example as low as 8 lbm/gal (960 kg/m\n3\n), the composition may further comprise low-density additives including ceramic microspheres, glass microspheres or plastic beads or combinations thereof.', 'Or, the compositions may be foamed with air or nitrogen.', 'Non-Aqueous Drilling Fluids Containing Expanding Agents', 'In a further aspect, embodiments relate to compositions comprising a non-aqueous liquid and an expanding agent comprising calcium oxide or calcined magnesium oxide or both.', 'The compositions may be drilling fluids.', 'In a further aspect, embodiments relate to methods comprising preparing a drilling fluid comprising a non-aqueous fluid and an expanding agent comprising calcium oxide or calcined magnesium oxide or both.', 'During a well cementing operation, the drilling fluid is placed in the well such that the drilling fluid flows ahead of a cement slurry.', 'The drilling fluid commingles with the cement slurry, thereby forming an interface.', 'The cement slurry and the interface are cured, wherein the interface expands or does not shrink upon the curing.', 'A spacer fluid may be placed between the drilling fluid and the cement slurry.', 'The cement slurry may comprise portland cement, pozzolan cement, gypsum cement, high alumina cement, slag cement, lime-silica blends or geopolymer cements or combinations thereof.', 'The volume ratio between the cement slurry and the drilling fluid in the commingled cement slurry and spacer fluid may be between 99:1 and 1:99.', 'For both aspects, the non-aqueous fluid may comprise one liquid phase or a water-in-oil emulsion wherein the oil is the external phase.', 'For both aspects, the MgO may be calcined at temperatures between about 700° C. and 2000° C., or between 1100° C. and 1300° C.', 'For both aspects, the expanding agent may be present in the composition at a concentration between 0.1 wt % and 20 wt %, or between 0.5 wt % and 10 wt %.', 'For both aspects, the expanding agent may be encapsulated by a coating having a thickness between about 2 μm and 80 μm.', 'The coating may comprise a polymer comprising a polyester, a polyacrylate, an epoxy, a polyhydroxyacid, a polypeptide, a polyesteramide, a polysulfide, a polysiloxane, a block copolymer comprising blocks joined through ester bonds, or a block copolymer comprising blocks joined through amide bonds, or combinations thereof.', 'Or, the coating may comprise silica that is sprayed onto the encapsulating agent as a silicate solution.', 'For both aspects, the expanding agent may be suspended in a non-aqueous additive comprising a hydrocarbon liquid, and the expanding agent may be present in the non-aqueous additive at a concentration between 10 wt % and 80 wt %, or between 30 wt % and 60 wt %.', 'The hydrocarbon liquid may comprise alkanes, alkenes, alkynes, cycloalkanes, aromatic hydrocarbons, natural gas liquids, liquid paraffins, naphthas, mineral oils, crude oils, synthesized hydrocarbon liquids, fuel oils, diesels, gasolines, biomass derived hydrocarbon liquids, coal derived hydrocarbon liquids, or kerosine, or mixtures thereof.', 'The hydrocarbon liquid may be Escaid™ 110, available from ExxonMobil.', 'For both aspects, the non-aqueous additive may further comprise a dispersant comprising polynaphthalene sulfonate, sulfonated acetone formaldehyde condensate, polycarboxylate ethers or microparticles or combinations thereof.', 'The dispersant may be present in the non-aqueous additive at a concentration between 0.1 wt % and 20 wt %, or between 2.0 wt % and 10 wt %.', 'For both aspects, the non-aqueous additive may further comprise an emulsifier comprising polysorbates or sorbitan esters, or both.', 'The emulsifier may be present at a concentration between 0.01 wt % and 10 wt %, or between 1 wt % and 5 wt %.', 'For both aspects, the composition may further comprise a weighting agent comprising silica, barite, hematite, calcium carbonate, ilmenite or manganese tetraoxide or combinations thereof.', 'The density of the composition may therefore vary between about 10 lbm/gal (1200 kg/m\n3\n) and about 24 lbm/gal (2880 kg/m\n3\n).', 'To achieve lower densities, for example as low as 8 lbm/gal (960 kg/m\n3\n), the composition may further comprise low-density additives including ceramic microspheres, glass microspheres or plastic beads or combinations thereof.', 'Or, the compositions may be foamed with air or nitrogen.', 'For both aspects, the viscosifying agent may comprise an organophilic clay, hydrophobically modified silica, hydrophobically modified biopolymers or hydrophobically modified synthetic polymers or combinations thereof.', 'The hydrophobically modified biopolymer may comprise acetone-formaldehyde-sodium bisulfate polymer and D-Glucopyranuoic acid, polymer with 6-deoxy-L-mannose, D-glucose and D-mannose, calcium potassium sodium salt.', 'The weight ratio between the acetone-formaldehyde-sodium bisulfate polymer and the D-Glucopyranuoic acid, polymer with 6-deoxy-L-mannose, D-glucose and D-mannose, calcium potassium sodium salt may be between 80:20 and 20:80, or between 66.7:33.3 and 33.3:66.7.', 'For both aspects, the viscosifying agent may further comprise bentonite, present at a concentration in the viscosifying agent between 0.1 wt % and 10 wt %, or between 0.5 wt % and 5.0 wt %.', 'Cement Slurries\n \nIn a further aspect, embodiments relate to compositions comprising an aqueous cement slurry and a non-aqueous additive comprising a suspension of an expanding agent comprising calcium oxide or a mixture of calcium oxide and calcined magnesium oxide.', 'In a further aspect, embodiments relate to methods comprising preparing a composition comprising an aqueous cement slurry and a non-aqueous additive comprising a suspension of an expanding agent comprising calcium oxide and calcined magnesium oxide or both.', 'During a well cementing operation, the cement slurry is placed in the well such that the cement slurry flows behind a spacer fluid or a drilling fluid or both.', 'The spacer fluid or the drilling fluid may commingle with the cement slurry, thereby forming an interface.', 'The cement slurry and the interface are cured, wherein the interface expands or does not shrink upon the curing.', 'The aqueous cement slurry may comprise water, portland cement, pozzolan cement, gypsum cement, high alumina cement, slag cement, lime-silica blends or geopolymer cements or combinations thereof.', 'The volume ratio between the cement slurry and the drilling fluid in the commingled cement slurry and spacer fluid, or between the cement slurry and the spacer fluid in the commingled cement slurry and spacer fluid, may be between 99:1 and 1:99.', 'For both aspects, the non-aqueous additive may comprise a hydrocarbon liquid.', 'The hydrocarbon liquid may comprise alkanes, alkenes, alkynes, cycloalkanes, aromatic hydrocarbons, natural gas liquids, liquid paraffins, naphthas, mineral oils, crude oils, synthesized hydrocarbon liquids, fuel oils, diesels, gasolines, biomass derived hydrocarbon liquids, coal derived hydrocarbon liquids, or kerosine, or mixtures thereof.', 'The hydrocarbon liquid may be Escaid™ 110, available from ExxonMobil.', 'The hydrocarbon liquid may be present in the non-aqueous additive at a concentration between 1 wt % and 99 wt %, or between 30 wt % and 70 wt %.', 'For both aspects, the MgO may be calcined at temperatures between about 700° C. and 2000° C., or between 1100° C. and 1300° C.', 'For both aspects, the expanding agent may be present in the non-aqueous additive at a concentration between 0.1 wt % and 20 wt %, or between 0.5 wt % and 10 wt %.', 'For both aspects, the non-aqueous additive may further comprise a dispersant comprising polynaphthalene sulfonate, sulfonated acetone formaldehyde condensate, polycarboxylate ethers or microparticles or combinations thereof.', 'The dispersant may be present in the non-aqueous additive at a concentration between 0.1 wt % and 20 wt %, or between 2.0 wt % and 10 wt %.', 'For both aspects, the non-aqueous additive may further comprise an emulsifier comprising polysorbates or sorbitan esters, or both.', 'The emulsifier may be present at a concentration between 0.01 wt % and 10 −wt %, or between 1 wt % and 5 wt %.', 'For both aspects, the composition may further comprise a weighting agent comprising silica, barite, hematite, calcium carbonate, ilmenite or manganese tetraoxide or combinations thereof.', 'The density of the composition may therefore vary between about 10 lbm/gal (1200 kg/m\n3\n) and about 24 lbm/gal (2880 kg/m\n3\n).', 'To achieve lower densities, for example as low as 8 lbm/gal (960 kg/m\n3\n), the composition may further comprise low-density additives including ceramic microspheres, glass microspheres or plastic beads or combinations thereof.', 'Or, the compositions may be foamed with air or nitrogen.', 'EXAMPLES', 'The following examples are presented to provide a general illustration of the present disclosure, and are not intended to limit the scope of the disclosure in any way.', 'The following examples describe expansion experiments that were performed using five fluid formulations, described below.', 'Formulation 1 was a 15.8 lbm/gal (1900 kg/m\n3\n)', 'Class G cement slurry, with 0.1 gal/94-lb sack (0.88 L/tonne of cement) silicone antifoam agent and 0.28 gal/sk (24.86 L/tonne of cement) liquid expansion additive.', 'The liquid expansion additive had a 50:50 solid:liquid ratio.', 'The solid portion was CaO and calcined MgO in a 60:40 weight ratio.', 'The liquid phase was 97% Escaid™ 110 oil and 3% viscosifying polymer.', 'The viscosifying polymer was poly(propylene-alt-ethylene) multi-arm, available from Kraton Corporation, Houston, Tex., USA.', 'Formulation 2 was a 14.0-lbm/gal (1680 kg/m\n3\n) aqueous spacer fluid containing an expansion additive.', 'The fluid contained 0.1 gal/bbl silicone antifoam, 4 lbm/bbl bentonite, 4 lbm/bbl of a viscosifier comprising 66.7% acetone-formaldehyde-sodium bisulfate polymer and 33.3% D-Glucopyranuoic acid, polymer with 6-deoxy-L-mannose, D-glucose and D-mannose, calcium potassium sodium salt, 5.3 gal/bbl liquid expansion additive (as described in Formulation 1) and 6.8 lbm/bbl barite weighting agent.', 'Formulation 3 was a 14.0-lbm/gal (1680 kg/m\n3\n) aqueous spacer fluid without an expansion additive.', 'The fluid contained 0.1 gal/bbl silicone antifoam, 4 lbm/bbl bentonite, 4 lbm/bbl of a viscosifier comprising 66.7% acetone-formaldehyde-sodium bisulfate polymer and 33.3% D-Glucopyranuoic acid, polymer with 6-deoxy-L-mannose, D-glucose and D-mannose, calcium potassium sodium salt and 6.8 lbm/bbl barite weighting agent.', 'Formulation 4 was a 10.8 lbm/gal (1300 kg/m\n3\n) oil-base drilling fluid containing an expansion additive.', 'The fluid composition is given in Table 1 below.', 'TABLE 1\n \n \n \n \n \n \n \n \nFormulation 4 composition.', 'Concentration\n \n \n \n \n \n \n \n \n \n \n \n \n \nField, lbm per bbl\n \nLab, g for 350 ml\n \n \n \n#\n \nProducts\n \nof prepared fluid\n \nprepared fluid\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n\u20021\n \nMG-3 base oil, \n \n165.21\n \n165.21\n \n \n \n \navailable from \n \n \n \n \n \n \nPetronas\n \n \n \n \n \n\u20022\n \nCalcium chloride\n \n24.73\n \n24.73\n \n \n \n\u20023\n \nVG SUPREME \n \n6.00\n \n6.00\n \n \n \n \norganophilic clay \n \n \n \n \n \n \nviscosifier, available \n \n \n \n \n \n \nfrom Schlumberger\n \n \n \n \n \n\u20024\n \nCalcium hydroxide\n \n5.00\n \n5.00\n \n \n \n\u20025\n \nVERSATROL M \n \n5.00\n \n5.00\n \n \n \n \nasphaltic resin, available \n \n \n \n \n \n \nfrom Schlumberger\n \n \n \n \n \n\u20026\n \nCalcium carbonate\n \n10.00\n \n10.00\n \n \n \n\u20027\n \nVERSAMOD gelling \n \n1.00\n \n1.00\n \n \n \n \nagent, available from \n \n \n \n \n \n \nSchlumberger\n \n \n \n \n \n\u20028\n \nSUREMUL PLUS \n \n6.00\n \n6.00\n \n \n \n \nemulsifier, available\n \n \n \n \n \n \nfrom Schlumberger\n \n \n \n \n \n\u20029\n \nWater\n \n82.07\n \n82.07\n \n \n \n10\n \nBarite\n \n148.58\n \n148.58\n \n \n \n11\n \n60:40 blend of CaO \n \n29.86\n \n29.86\n \n \n \n \nand calcined MgO\n \n \n \n \n \n \n \n \n \n \nFormulation 5 was a 10.8 lbm/gal (1300 kg/m\n3\n) oil-base drilling fluid without an expansion additive.', 'The fluid composition is given in Table 2 below.', 'TABLE 2\n \n \n \n \n \n \n \n \nFormulation 5 composition.', 'Concentration\n \n \n \n \n \n \n \n \n \n \n \n \n \nField, lbm per bbl\n \nLab, g for 350 ml\n \n \n \n#\n \nProducts\n \nof prepared fluid\n \nprepared fluid\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n\u20021\n \nMG-3 base oil, \n \n165.21\n \n165.21\n \n \n \n \navailable from \n \n \n \n \n \n \nPetronas\n \n \n \n \n \n\u20022\n \nCalcium chloride\n \n24.73\n \n24.73\n \n \n \n\u20023\n \nVG SUPREME \n \n6.00\n \n6.00\n \n \n \n \norganophilic clay\n \n \n \n \n \n \nviscosifier, available \n \n \n \n \n \n \nfrom Schlumberger\n \n \n \n \n \n\u20024\n \nCalcium hydroxide\n \n5.00\n \n5.00\n \n \n \n\u20025\n \nVERSATROL M \n \n5.00\n \n5.00\n \n \n \n \nasphaltic resin, available \n \n \n \n \n \n \nfrom Schlumberger\n \n \n \n \n \n\u20026\n \nCalcium carbonate\n \n10.00\n \n10.00\n \n \n \n\u20027\n \nVERSAMOD gelling \n \n1.00\n \n1.00\n \n \n \n \nagent, available from \n \n \n \n \n \n \nSchlumberger\n \n \n \n \n \n\u20028\n \nSUREMUL PLUS \n \n6.00\n \n6.00\n \n \n \n \nemulsifier, available\n \n \n \n \n \n \nfrom Schlumberger\n \n \n \n \n \n\u20029\n \nWater\n \n82.07\n \n82.07\n \n \n \n10\n \nBarite\n \n148.58\n \n148.58\n \n \n \n \n \n \n \n \n \n \nLinear expansion tests were performed with the above formulations.', 'The fluids were prepared and mixed in a 200-mL beaker of either pure fluid or with fluid blends to simulate commingling in a wellbore during placement.', 'The test fluids were placed within an expansion cell (\nFIG.', '1\n) and then lowered into a water bath.', 'Expansion measurements were taken periodically during curing in the water bath.', 'Additional information concerning the expansion test method may be found in the following publication.', 'Dargaud B and Boukhelifa L: “Laboratory Testing, Evaluation and Analysis of Well Cements,” in Nelson E B and Guillot D (eds.):', 'Well Cementing—\n2\nnd \nEdition, Schlumberger (2006) 641-643.', 'Example 1\n \nTesting was conducted to determine the effects of commingling between a cement slurry containing an expanding agent and oil-base drilling fluids with and without an expanding agent.', 'Three fluids were tested: a control system of Formulation 1 alone; an 80:20 volume ratio of Formulation 1 and Formulation 4; and an 80:20 volume ratio of Formulation 1 and Formulation 5.', 'The curing temperature was 54° C.', 'The results, shown in \nFIG.', '2\n, reveal that the best performing system was the one in which the cement slurry was contaminated with the oil-base drilling fluid containing the expansion agent.', 'Next, was Formulation 1 alone.', 'The smallest expansion was observed when the oil-base drilling fluid did not also contain the expansion agent.', 'Thus, commingling of the cement slurry with oil-base drilling fluid containing expansion agent leads to better expansion and bonding between the set cement and the casing and formation surfaces, leading to better zonal isolation.', 'Example 2\n \nTesting was conducted to determine the effects of commingling between a cement slurry containing an expanding agent and aqueous spacer fluids with and without an expanding agent.', 'Three fluids were tested: a control system of Formulation 1 alone; an 80:20 volume ratio of Formulation 1 and Formulation 2; and an 80:20 volume ratio of Formulation 1 and Formulation 3.', 'The curing temperature was 54° C.', 'The results, shown in \nFIG.', '3\n, reveal that the best performing system was the one in which the cement slurry was contaminated with the spacer fluid containing the expansion agent.', 'This was followed by Formulation 1 alone.', 'The smallest expansion was observed when the spacer fluid did not also contain the expansion agent.', 'Thus, commingling of the cement slurry with spacer fluid containing expansion agent leads to better expansion and bonding between the set cement and the casing and formation surfaces, leading to better zonal isolation.', 'The preceding description has been presented with reference to present embodiments.', 'Persons skilled in the art and technology to which this disclosure pertains will appreciate that alterations and changes in the described structures and methods of operation can be practiced without meaningfully departing from the principle, and scope of this present disclosure.', 'Accordingly, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.']

['1.', 'A method, comprising:\n(a) preparing a composition comprising an aqueous cement slurry and a non-aqueous additive comprising a suspension of an expanding agent comprising calcium oxide, calcined magnesium oxide, or both;\n(b) during a well cementing operation, placing the cement slurry in the well such that the cement slurry flows behind a spacer fluid or a drilling fluid, or both;\n(c) causing the spacer fluid or the drilling fluid to commingle with the cement slurry, thereby forming an interface; and\n(d) curing the cement slurry and the interface, wherein the interface expands or does not shrink upon the curing;\nwherein the non-aqueous additive further comprises an emulsifier comprising polysorbates or sorbitan esters, or both; wherein the emulsifier is present in the non-aqueous additive at a concentration between 0.01 wt % and 10 wt %.', '2.', 'The method of claim 1, wherein the aqueous cement slurry comprises water, portland cement, pozzolan cement, gypsum cement, high alumina cement, slag cement, lime-silica blends or geopolymer cements or combinations thereof.', '3.', 'The method of claim 1, wherein a volume ratio between the cement slurry and the spacer fluid in the commingled cement slurry and spacer fluid, or a volume ratio between the cement slurry and the drilling fluid, is between 99:1 and 1:99.', '4.', 'The method of claim 1, wherein the non-aqueous additive further comprises a hydrocarbon liquid.', '5.', 'The method of claim 4, wherein the hydrocarbon liquid comprises alkanes, alkenes, alkynes, cycloalkanes, aromatic hydrocarbons, natural gas liquids, liquid paraffins, naphthas, mineral oils, crude oils, synthesized hydrocarbon liquids, fuel oils, diesels, gasolines, biomass derived hydrocarbon liquids, coal derived hydrocarbon liquids, or kerosene, or mixtures thereof; wherein the hydrocarbon liquid is present in the non-aqueous additive at a concentration between 1 wt % and 99 wt %.', '6.', 'The method of claim 1, wherein the calcined magnesium oxide is calcined at a temperature between 700° C. and 2000° C.\n\n\n\n\n\n\n7.', 'The method of claim 1, wherein the expanding agent is present in the non-aqueous additive at a concentration between 10 wt % and 80 wt %.\n\n\n\n\n\n\n8.', 'The method of claim 1, wherein the non-aqueous additive further comprises a dispersant comprising polynaphthalene sulfonate, sulfonated acetone formaldehyde condensate, polycarboxylate ethers, or micro particles or combinations thereof; wherein the dispersant is present in the non-aqueous additive at a concentration between 0.1 wt % and 20 wt %.', '9.', 'The method of claim 1, wherein the cement slurry further comprises a weighting agent, the weighting agent comprising silica, barite, hematite, ilmenite or manganese tetraoxide or combinations thereof.']

['FIG.', '1 is a photograph of a linear expansion cell.; FIG.', '2 presents linear expansion data from expansive cement slurries contaminated by an oil-base drilling fluid, with and without an expansion agent in the drilling fluid.; FIG.', '3 presents linear expansion data from expansive cement slurries contaminated by an aqueous spacer fluid, with and without an expansion agent in the spacer fluid.']

US11938544

Systems and methods for manufacturing or repairing components at a remote work site

Sep 28, 2017

Srinand Sreedharan Karuppoor, Manuel Marya, Iain Michael Cooper

SCHLUMBERGER TECHNOLOGY CORPORATION

Gibson, I. et al. “Additive manufacturing technologies” 2010. Springer. ISBN: 978-1-4419-1119-3 e-ISBN: 978-1-4419-1120-9. (Year: 2010).; Banovic, S.W. et al. “The role of aluminum on the weldability and sulfidation behavior of iron-aluminum cladding.” 1999. Welding research supplement. p. 23-30 (Year: 1999).; Duliu, O. “Computer axial tomography in geosciences: an overview”. 1999. Earth science reviews. 48. p. 265-281. (Year: 1999).; Antony, L. et al. “Processes for production of high-purity metal powders.” 2003. JOM. p. 14-18 (Year: 2003).; Schade, C. et al. “Atomization” 2015. ASM Handbook vol. 7. ASM international. p. 58-71. (Year: 2015).; Ratnayake, R.M. “Making sense of 3d printing/additive layer manufacturing in offshore petroleum industry: state of the art.” 2016. Proceedings of the ASME 2016 35th International Conference on Ocean, Offshore and Arctic Engineering. p. 1-13. (Year: 2016).; International Search Report and Written Opinion issued in the related PCT application PCT/US2018/053259, dated Jan. 24, 2019 (13 pages).; International Preliminary Report on Patentability issued in the PCT application PCT/US2018/053259, dated Apr. 9, 2020 (10 pages).; Written Opinion issued in Singapore patent application 11202002961R dated Mar. 17, 2021, 6 pages.

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101787509; July 2010; CN

['A system includes a mobile platform that includes a metal powder production machine that receives solid and continuous metal and outputs a metal powder.', 'The mobile platform further includes an additive manufacturing system that receives the metal powder and outputs a manufactured component.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThis disclosure relates to systems and methods for the generation of reusable material (e.g., metal, alloys, plastics, etc.) and utilizing the reusable material for the manufacture or repair of components.', 'This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present techniques, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, these statements are to be read in this light, and not as admissions of any kind.', 'In some industries (e.g., oil and gas, mining, logging, etc.), a work site may in a remote location that makes it difficult to transport tools, supplies, or replacement components to the work site in a timely manner.', 'Further, the work site may use specialized tools (e.g., drilling tools, downhole Exploration and Production tools, earth moving tools, cutting tools, etc.) that endure harsh conditions that cause the tools to break down in unexpected ways and/or that may involve frequent servicing.', 'As such, it may be desirable to decrease the time to repair or replace the tools or components of the tools.', 'SUMMARY\n \nA summary of certain embodiments disclosed herein is set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.', 'In one example, a system includes a mobile platform that includes a metal powder production machine that receives solid and continuous metal and outputs a metal powder.', 'The mobile platform further includes an additive manufacturing system that receives the metal powder and outputs a manufactured component.', 'In another example, a method for manufacturing components includes storing a metal powder production machine and an additive manufacturing system in a vehicle at an oil and gas work site.', 'The method further includes receiving, via the metal powder production machine, a solid and continuous metal from an oil and gas work site.', 'Also, the method includes producing, via the metal powder production machine, a metal powder from the solid and continuous metal.', 'In addition, the method includes manufacturing, via the additive manufacturing system, a component from the metal powder.', 'In yet another example, a system includes a storage container coupled to a vehicle, and the storage container includes a metal powder production machine that receives solid and continuous metal and outputs a metal powder.', 'The storage container also includes an additive manufacturing system that receives the metal powder and outputs a manufactured component.', 'In addition, the storage container includes a process diagnosis machine that performs non-destructive testing on the manufactured component.', 'Various refinements of the features noted above may be undertaken in relation to various aspects of the present disclosure.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'The brief summary presented above is intended only to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings in which:\n \nFIG.', '1\n illustrates an oil and gas work site that may employ the systems and methods of this disclosure;\n \nFIG.', '2\n is an embodiment of a schematic flow diagram of a component production system for producing components at the oil and gas site of \nFIG.', '1\n;\n \nFIG.', '3\nA\n illustrates a first embodiment of a metal powder production machine of the component production system of \nFIG.', '2\n;\n \nFIG.', '3\nB\n illustrates a second embodiment of the metal powder production machine of the component production system of \nFIG.', '2\n;\n \nFIG.', '3\nC\n illustrates a third embodiment of the metal powder production machine of the component production system of \nFIG.', '2\n;\n \nFIG.', '3\nD\n illustrates a fourth embodiment of the metal powder production machine of the component production system of \nFIG.', '2\n;\n \nFIG.', '4\nA\n illustrates a first embodiment of an additive manufacturing system of the component production system of \nFIG.', '2\n;\n \nFIG.', '4\nB\n illustrates a second embodiment of the additive manufacturing system of the component production system of \nFIG.', '2\n;\n \nFIG.', '4\nC\n illustrates a third embodiment of the additive manufacturing system of the component production system of \nFIG.', '2\n;\n \nFIG.', '5\n illustrates possible components manufactured by the additive manufacturing system of the component production system of \nFIG.', '2\n; and\n \nFIG.', '6\n is a flow chart depicting an embodiment of a method of producing a component at an industrial work site, such as the oil and gas work site of \nFIG.', '1\n.', 'DETAILED DESCRIPTION', 'One or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'The present disclosure relates to systems and methods that decrease the time to replace and/or repair tools at a remote work site having a location separated by some travel time from a manufacturing facility that makes or repairs tools used at the remote work site.', 'Indeed, remote work sites may use tools in harsh conditions that cause the tools to wear down or break in unexpected ways.', 'Further, the work site may not store spare parts for every component that could wear down or break.', 'When the work site does not have spare parts to repair a tool, the production of the work site may slow down or stop until the tool is repaired.', 'Because the work sites are often remote, it may be difficult and/or take a long time for the work site to acquire the spare parts.', 'However, the work site may store scrap metal or other spare parts that are not used.', 'Therefore, it is desirable to decrease the time to acquire spare parts for tools at work sites.', 'Accordingly, embodiments of this disclosure relate to systems and methods for the mobile generation of reusable material (e.g., metal, alloys, plastics, etc.) and utilizing the reusable material for the manufacture and repair of components.', 'That is, some embodiments include one or more mobile platforms (e.g., a truck) that may receive material (e.g., scrap metal, spare parts, etc.) and output a component that may be used to repair and/or replace part of a tool.', 'For example, the one or more mobile platforms may include a machine that receives material and atomizes the material to produce a powder of the material.', 'The one or more mobile platforms may include a second machine that uses the powder to generate a desired component that repairs and/or replaces a tool used at the work site.', 'With this in mind, \nFIG.', '1\n illustrates an oil and gas work site \n10\n that may employ the systems and methods of this disclosure.', 'The oil and gas work site \n10\n may include a well system \n12\n used to bore into a geological formation \n14\n via a wellbore \n16\n.', 'Further, the well system \n12\n may include a downhole Exploration and Production tool \n18\n that may be used to drill into the geological formation \n14\n to form the wellbore \n16\n, or the downhole Exploration and Production tool \n18\n may be used to inspect certain features within the wellbore \n16\n.', 'Further, the wellbore \n16\n may not continue straight down into the geological formation \n14\n, and the wellbore \n16\n may contain a turn 20.', 'The wellbore \n16\n may continue past the turn into the geological formation \n14\n at an angle as high as ninety degrees.', 'In the example of \nFIG. \n1\n, the downhole Exploration and Production tool \n18\n is conveyed on a cable \n22\n via a logging winch system \n24\n.', 'Although the logging winch system \n24\n is schematically shown in \nFIG.', '1\n as a fixed (e.g., a long-term installation that is substantially permanent or modular) logging winch system', ', the logging winch system \n24\n may be mobile (e.g., affixed to a vehicle).', 'The oil and gas work site \n10\n also includes a scrap metal area \n26\n that may include any metal that is not being used in an operation at the oil and gas work site \n10\n.', 'For example, some components may degrade and/or break down such that they are no longer useful for their intended function.', 'Rather than throwing the component away, the component may be stored in the scrap metal area \n26\n so that the material of the component may be used for other purposes (e.g., metal powder production and/or additive manufacturing).', 'The scrap metal area \n26\n may also include excess metal from certain operations.', 'For example, some components may be constructed or repaired at the oil and gas work site \n10\n.', 'After the construction or repair of components, there may be some material left over that may be included in the scrap metal area \n26\n.', 'Further, scrap metal may be transported to the oil and gas work site \n10\n and stored in the scrap metal area \n26\n.', 'In addition, spare parts that may be used to repair or replace components may also be included in the scrap metal area \n26\n.', 'Further, the type of metal included in the scrap metal area may be any type of metal, including low steel alloys (e.g., 4140, 4330, 8630, F22, 9Cr-1Mo, etc.), stainless steel alloys (e.g., 17-4PH, 15-5PH, 13-8Mo, 410/420, etc.), nickel base alloys (e.g., 718, 725, 625+, 625, 825, Alloy 28, etc.), titanium alloys (e.g., Ti6Al4V, Grade Beta C, etc.), cobalt based alloys (e.g., Stellite, etc.), tungsten alloys, molybdenum alloys, and so forth.', 'The scrap metal from the scrap metal area \n26\n may be useful in the oil and gas work site \n10\n to provide material for operations that use metal.', 'For example, the scrap metal may be used in a metal powder production and/or additive manufacturing process.', 'Accordingly, the oil and gas work site \n10\n includes a metal powder production machine \n28\n and an additive manufacturing system \n30\n.', 'The metal powder production machine \n28\n receives a piece of solid and continuous metal (e.g., scrap metal from the metal scrap area \n26\n) and atomizes the piece of metal to produce a powder from the piece of metal.', 'The metal powder production machine \n28\n may use any suitable process to turn the piece of metal into powder, including gas atomization, water atomization, atomization with a consumable electrode, centrifugal atomization, or any other process.', 'The metal powder production machine \n28\n may produce a metal powder with particles of any suitable size, including 0 to 120 micrometers, 0 to 25 micrometers, 15 to 45 micrometers, 30 to 65 micrometers, 45 to 100 micrometers, or 50 to 120 micrometers.', 'The size of the particles produced by the metal powder production machine \n28\n may depend at least in part on the type of process used, the type of additive manufacturing system \n30\n, the type of scrap metal, etc.', 'Further, the metal powder may also include pellets, flakes, or any other suitable type of fine particulates.', 'The additive manufacturing system \n30\n is used to receive a metal powder (e.g., from the metal powder production machine \n28\n or from a metal powder storage) and output a component.', 'For example, the additive manufacturing system \n30\n may use a hot isostatic pressing (“HIP”) process, a powder bed fusion (“PBF”) process, a direct energy deposition process, or any other process to turn metal powder into useable components.', 'Further, the output component may be a finished component that is ready for use, or the component may be a partially finished component that may require further treatment (e.g., grinding, machining, thermal processes, heat treatments such as sintering, etc.) to become a finished component.', 'In some embodiments, additional systems (e.g., computer numerical control machines, grinding machines, lathes, sintering systems, heat treatment systems, etc.) may be included at the oil and gas work site \n10\n to receive the partially finished component and output the finished component.', 'Further, the additional systems may be included as a part of the additive manufacturing system \n30\n, or the additional systems may be separate from the additive manufacturing system.', 'Moreover, for embodiments in which the additional systems are separate, the additional systems may be stationary at the oil and gas work site \n10\n, included on a vehicle \n32\n, or located remotely from the oil and gas work site \n10\n.', 'Although the metal powder production machine \n28\n and the additive manufacturing system \n30\n are schematically shown in \nFIG.', '1\n as a mobile (e.g., affixed to the vehicle \n32\n) metal powder production machine and additive manufacturing system, the metal powder production machine \n28\n and the additive manufacturing system \n30\n may be fixed (e.g., a long-term installation that is substantially permanent or modular).', 'For example, the metal powder production machine \n28\n and the additive manufacturing system \n30\n may fit within a storage container that is carried by the vehicle \n32\n.', 'Further, the storage container may be separate from the vehicle \n32\n and may be able to couple to different vehicles.', 'By providing the metal powder production machine \n28\n and the additive manufacturing system \n30\n on the vehicle \n32\n, the metal powder production machine \n28\n and the additive manufacturing system \n30\n may be more quickly dispatched to the oil and gas work site \n10\n.', 'Further, the vehicle \n32\n may travel from one oil and gas work site to another and transport the metal powder production machine \n28\n and the additive manufacturing system \n30\n without taking the time to pack and unpack the machines.', 'Although the vehicle \n32\n is shown as a single vehicle in \nFIG.', '1\n, the vehicle \n32\n may include multiple vehicles and each vehicle may carry a portion or all of either the metal powder production machine \n28\n or the additive manufacturing system \n30\n.', 'Further, the metal powder production machine \n28\n and/or the additive manufacturing system \n30\n, may be connected to a control system \n40\n.', 'The control system \n40\n may be used to control one or more functions of the metal powder production machine \n28\n and/or the additive manufacturing system \n30\n.', 'For example, the control system \n40\n may enable input and selection of computer models for the additive manufacturing system \n30\n.', 'Further, the control system \n40\n may be physically coupled to the metal powder production machine \n28\n and/or the additive manufacturing system \n30\n, or the control system \n40\n may be remotely connected to the metal powder production machine \n28\n and/or the additive manufacturing system \n30\n (e.g., via Bluetooth, Wi-Fi, etc.).', 'In addition, the control system \n40\n may be a computer application executable by any computing device (e.g., a computer, a smartphone, a laptop, a tablet, etc.).', 'As such, the control system \n40\n may enable partial or full remote control over the metal powder production machine \n28\n and/or the additive manufacturing system \n30\n.\n \nFIG.', '2\n is an embodiment of a schematic flow diagram of a component production system \n42\n for producing components at the oil and gas site of \nFIG.', '1\n.', 'The component production system \n42\n includes a metal source \n44\n, the metal powder production machine \n28\n, the additive manufacturing system \n30\n, and a process diagnosis machine \n46\n (e.g., a machine that monitors and/or diagnoses any other disclosed machine and/or process).', 'The metal source \n44\n may be the metal from the metal area \n26\n shown in \nFIG.', '1\n.', 'The metal source \n44\n provides metal to the metal powder production machine \n28\n, which receives the metal and outputs a metal powder.', 'The metal powder produced by the metal powder production machine \n28\n is then used by the additive manufacturing system \n30\n to produce a desired component.', 'The process diagnosis machine \n46\n may be used to monitor and/or inspect the metal \n44\n, the metal powder production machine \n28\n, and/or the additive manufacturing system \n30\n.', 'For example, the process diagnosis machine \n46\n may be used to inspect the metal \n44\n to determine the chemical composition of the metal \n44\n (e.g., determine which elements are present and in what concentration).', 'Further, the process diagnosis machine \n46\n may be used to monitor the progress of the metal powder production machine \n28\n.', 'For example, the process diagnosis machine \n46\n may stop the operation of the metal powder production machine \n28\n if the process diagnosis machine \n46\n determines that the metal powder production machine \n28\n has produced a sufficient amount of metal powder.', 'In addition, the process diagnosis machine \n46\n may inspect the metal powder produced by the metal powder production machine \n28\n to determine a chemical composition of the metal powder.', 'In some embodiments, the process diagnosis machine \n46\n may alter the composition of the metal powder by adding, removing, or mixing a different metal powder into the metal powder produced by the metal powder production machine \n28\n.', 'Further, the process diagnosis machine \n46\n may monitor the progress of the additive manufacturing system \n30\n.', 'For example, the process diagnosis machine \n46\n may monitor (e.g., in real time) the component as it is being produced by the additive manufacturing system \n30\n.', 'If the process diagnosis machine \n46\n determines that the component being produced does not comply with the desired component, then the process diagnosis machine \n46\n may stop operation of the additive manufacturing system \n30\n.', 'In addition, the process diagnosis machine \n46\n may inspect the components produced by the additive manufacturing system \n30\n.', 'For example, the process diagnosis machine \n46\n may use non-destructive testing to inspect the components to determine if the produced component complies with certain standards applicable to the component produced (e.g., chemical composition, density, porosity, homogeneity, etc.).', 'It should be appreciated that the process diagnosis machine \n46\n may include any suitable structure to perform the above described functions, including a processor, a memory, a display, a graphical user interface, a general purpose computer, a controller, a camera (e.g., the camera may be operable at any spectrum including infrared, ultrasonic, visual, etc.), a dye pen, an x-ray imaging device, a computerized axial tomography scan device, a powder blender, etc.', 'Further, the process diagnosis machine \n46\n may be coupled to any combination of the metal powder production machine \n28\n or the additive manufacturing system \n30\n, or the process diagnosis machine \n46\n may located remotely from the metal powder production machine \n28\n, the additive manufacturing system \n30\n, or both.\n \nFIGS.', '3\nA through \n3\nD\n illustrate embodiments of the metal powder production machine \n28\n.', 'FIG.', '3\nA\n illustrates an embodiment of a metal powder production machine \n28\nA that uses a gas atomization process to receive a molten metal and output a metal powder.', 'The scrap metal is first melted into a molten metal \n52\n and contained within a ladle \n50\n.', 'The ladle \n50\n then pours the molten metal \n52\n into a tundish \n54\n.', 'Then the molten metal \n52\n flows through the hole in the bottom of the tundish \n54\n and comes into contact with an atomizing gas spray \n56\n, which separates the molten metal \n52\n into metal particles \n60\n.', 'The metal particles \n60\n then harden into a metal powder in an atomizing chamber \n58\n.', 'FIG.', '3\nB\n illustrates an embodiment of a metal powder production machine \n28\nB that uses a water atomization process to receive a molten metal and output a metal powder.', 'The scrap metal is first melted into a molten metal \n52\n and contained within a ladle \n50\n.', 'The ladle \n50\n then pours the molten metal \n52\n into a tundish \n54\n.', 'Then the molten metal \n52\n flows through the hole in the bottom of the tundish \n54\n and comes into contact with an atomizing water spray \n61\n from a high-pressure water manifold \n62\n, which separates the molten metal \n52\n into metal particles \n60\n.', 'The metal particles \n60\n then harden into a metal powder and combine with water from the atomizing water spray \n61\n in an atomizing tank \n64\n.', 'Then the mixture of the metal particles \n60\n and water flow along a path \n66\n to separate the metal particles \n60\n and the water.\n \nFIG.', '3\nC\n illustrates an embodiment of a metal powder production machine \n28\nC that uses a centrifugal atomization process to receive a molten metal and output a metal powder.', 'The scrap metal is first melted into a molten metal \n52\n and contained within a ladle \n50\n.', 'The ladle \n50\n then pours the molten metal \n52\n into a tundish \n54\n.', 'Then the molten metal \n52\n flows through the hole in the bottom of the tundish \n54\n and comes into contact with a spinning disk \n68\n, which separates the molten metal \n52\n into metal particles \n60\n.', 'The metal particles \n60\n then harden into a metal powder and are collected.', 'FIG.', '3\nD\n illustrates an embodiment of a metal powder production machine \n28\nD that uses a rotating consumable electrode atomization process to receive a conductive solid metal and output a metal powder.', 'The scrap metal is fitted into a spindle \n70\n such that the scrap metal becomes a rotating consumable electrode \n72\n.', 'The spindle \n70\n and the rotating consumable electrode are placed in a chamber \n74\n that may be filled with an inert gas flow \n76\n through a first port \n78\n and/or the gas may be evacuated along a vacuum flow path \n80\n through a second port \n82\n.', 'A nonrotating electrode (e.g., a tungsten electrode) \n84\n may be inserted into the chamber \n74\n, opposite of the rotating consumable electrode \n72\n.', 'Then, electricity is passed through the non-rotating electrode \n84\n, which causes the rotating consumable electrode \n72\n to begin melting.', 'While the rotating consumable electrode \n72\n is melting, the rotating consumable electrode \n72\n is spun such that as the rotating consumable electrode \n72\n melts, metal particles \n60\n separate from the rotating consumable electrode \n72\n.', 'Then, the metal particles \n60\n harden and fall into a collection port \n86\n at the bottom of the chamber \n74\n.\n \nFIGS.', '4\nA through \n4\nC\n illustrate embodiments of the additive manufacturing system \n30\n.', 'FIG.', '4\nA\n illustrates an embodiment of an additive manufacturing system \n30\nA that uses a powder bed fusion (“PBF”) process to receive a metal powder and output a component.', 'First, a controller \n100\n receives a computer model (e.g., a computer aided design drawing or computer aided manufacturing drawing) of a manufactured component \n101\n to be produced.', 'For example, a user may interact with a display \n105\n to select a computer model.', 'The display \n105\n may be physically coupled to the controller \n100\n, or the display \n105\n may be remotely located.', 'For example, the display \n105\n may be coupled to a different controller and remotely send (e.g., via Bluetooth, internet web link, etc.)', 'the computer model to the controller \n100\n.', 'After receiving the computer model, the controller \n100\n splits the model into a number of layers with each layer having a thickness.', 'Further, the metal particles \n60\n collected from the metal powder production machine \n28\n are collected in a powder delivery system \n100\n.', 'To construct a layer of the component, a first piston \n104\n moves in a y-direction \n108\n to push the metal particles \n60\n upwards.', 'Then, a roller \n106\n moves in an x-direction \n110\n to push the metal particles \n60\n toward a production area \n112\n.', 'The roller \n106\n deposits the metal particles \n60\n in the production area \n112\n such that the metal particles \n60\n have a thickness of one layer of the manufactured component \n101\n.', 'Then, the controller \n100\n sends a signal to a laser device \n114\n to produce a laser \n116\n.', 'The controller \n100\n also sends a signal to a scanning device \n118\n to control a position of the laser \n116\n by using a mirror \n120\n.', 'The mirror \n120\n directs the laser \n116\n to conform to the layer of the computer model of the manufactured component \n101\n.', 'The laser \n116\n causes the metal powder \n60\n to melt at the point of impact.', 'After the layer of the manufactured component \n101\n is completed, a second piston \n122\n moves in the x-direction by a distance of the thickness of the layer, and the above process is repeated for each layer of the manufactured component \n101\n until all of the layers have been completed.', 'FIG.', '4\nB\n illustrates an embodiment of an additive manufacturing system \n30\nB that uses a direct energy deposition process to receive a metal powder and output a component.', 'A focused thermal energy source \n142\n (e.g., a laser) is provided to melt the metal powder \n60\n.', 'The metal powder \n60\n is blown through one or more metal powder delivery nozzles \n140\n toward the focused thermal energy source \n142\n.', 'As the metal powder \n60\n passes through the focused thermal energy source \n142\n, the metal powder \n60\n melts onto a deposition surface \n144\n of the manufactured component \n101\n.', 'The metal powder \n60\n is deposited onto the manufactured component \n101\n until the manufactured component \n101\n is complete.', 'FIG.', '4\nC\n illustrates an embodiment of an additive manufacturing system \n30\nC that uses a hot isostatic pressing process to receive a metal powder and output a component.', 'The metal powder \n60\n is inserted into a chamber \n150\n filled with an inert gas \n152\n (e.g., argon).', 'The metal powder \n60\n may be inserted into the chamber \n150\n in the desired shape of the manufactured component.', 'Then the chamber \n150\n is heated, causing the pressure inside the chamber \n150\n to increase.', 'In some embodiments, more inert gas \n152\n may be pumped into the chamber \n150\n to achieve the desired pressure.', 'The heat and pressure inside of the chamber \n150\n causes the metal powder \n60\n to solidify into one piece.', 'In addition, the pressure inside of the chamber \n150\n may be applied to components manufactured by either the additive manufacturing system \n30\nA or the additive manufacturing system \n30\nB to reduce the porosity and/or increase the density of the components.\n \nFIG.', '5\n illustrates possible components \n170\n manufactured by the additive manufacturing system \n30\n.', 'The possible components may include measurement while drilling alternators, rotary steerable pads wear band and stabilizer repair, port holes, flow diverters, drill bits, packer expansion elements, etc.', 'As illustrated by the possible components \n170\n, the additive manufacturing system \n30\n may manufacture a component having any shape or internal structure.\n \nFIG.', '6\n is a flow chart depicting an embodiment of a method \n180\n of producing a component at an industrial work site.', 'Although the following method \n180\n describes a number of operations that may be performed, it should be noted that the method \n180\n may be performed in a variety of suitable orders and all of the operations may not be performed.', 'Further, some or all of the steps may be implemented by any combination of the control system \n40\n, the metal powder production machine \n28\n, the additive manufacturing system \n30\n, or the process diagnosis machine \n46\n.', 'The method \n180\n includes receiving (e.g., at the metal powder production machine) the metal (e.g., from the scrap metal area) (block \n182\n).', 'The metal may include any metal that is not being used in an operation at the industrial work site.', 'For example, some components may degrade and/or break down such that they are no longer useful for their intended function.', 'Rather than throwing the component away, the component may be stored so that the material of the component may be used for other purposes (e.g., metal powder production and/or additive manufacturing).', 'The metal may also include excess metal from certain operations.', 'For example, some components may be constructed or repaired at the industrial work site.', 'After the construction or repair of components, there may be some metal left over.', 'In addition, the metal may be brought and stored at the industrial work site for flexible usage.', 'After receiving the metal, the method \n180\n includes producing (e.g., via the metal powder production machine) metal powder from the received metal (block \n184\n).', 'The metal powder may be produced utilizing any suitable process to turn the metal into powder, including gas atomization, water atomization, atomization with a consumable electrode, centrifugal atomization, or any other process.', 'The produced metal powder may include particles of any suitable size, including 0 to 120 micrometers, 0 to 25 micrometers, 15 to 45 micrometers, 30 to 65 micrometers, 45 to 100 micrometers, or 50 to 120 micrometers.', 'Next, the method \n180\n includes inspecting (e.g., via the process diagnosis machine) the produced metal powder (block \n186\n).', 'The metal powder may be inspected for chemical composition (e.g., determining which elements are present and in what concentration), particle size, particle uniformity, etc.', 'In some embodiments, the inspection may include mixing the produced metal powder with other metal powders to alter a characteristic of the produced metal powder (e.g., chemical composition).', 'Then, the method \n180\n includes manufacturing (e.g., via the additive manufacturing system) a component from the metal powder (block \n188\n).', 'The component may be manufactured utilizing a hot isostatic pressing (“HIP”) process, a powder bed fusion (“PBF”) process, a direct energy deposition process, or any other process to turn metal powder into useable components.', 'The manufactured components may include measurement while drilling alternators, rotary steerable pads wear band and stabilizer repair, port holes, flow diverters, drill bits, packer expansion elements, etc.', 'Next, the method \n180\n includes inspecting (e.g., via the process diagnosis machine or by on-site or remote operators) the manufactured component (block \n190\n).', 'Inspecting the manufactured component may use non-destructive testing (e.g., x-ray imaging, computerized axial tomography scans, etc.) to determine if the manufactured component complies with certain standards applicable to the component produced (e.g., chemical composition, density, porosity, homogeneity, etc.).', 'With the foregoing in mind, embodiments presented herein provide systems and methods that enable production of components at remote work sites.', 'The systems and methods include a metal powder production machine and/or an additive manufacturing system on a mobile platform that enables component production at any location.', 'Providing a metal powder production machine and/or an additive manufacturing system on a mobile platform also reduces the time to receive replacement parts at a work site.', 'The specific embodiments described above have been shown by way of example, and it should be understood that these embodiments may be susceptible to various modifications and alternative forms.', 'It should be further understood that the claims are not intended to be limited to the particular forms disclosed, but rather to cover all modifications, equivalents, and alternatives falling within the spirit and scope of this disclosure.']

['1.', 'A system comprising:\na mobile platform configured to be dispatched to an oil and gas work site, wherein the mobile platform is separate from and configured to couple to a plurality of vehicles, the mobile platform comprising: a metal powder production machine having inputs of scrap metal or spare parts from the oil and gas work site and an additional metal powder and an output of a scrap metal powder, wherein the metal powder production machine is configured to atomize the scrap metal or the spare parts via at least one of a gas atomization process, a water atomization process, a centrifugal atomization process, or a consumable electrode atomization process; a process diagnosis machine configured to determine a chemical composition of the scrap metal powder produced by the metal powder production machine, wherein the process diagnosis machine comprises a camera, a dye pen, an x-ray imaging device, a computerized axial tomography scan device, or a powder blender, and wherein determining the chemical composition of the scrap metal powder comprises determining one or more elements that comprise the scrap metal powder and determining concentrations of the one or more elements in the scrap metal powder; an additive manufacturing system configured to receive the scrap metal powder and output a downhole exploration and production tool configured to be used during formation of a wellbore from the oil and gas work site; and a control system communicatively connected to the metal powder production machine and the additive manufacturing system, wherein the control system comprises a computer application executable by a computing device, and wherein the computer application, when executed by the computing device in response to receiving the chemical composition of the scrap metal powder that is determined by the process diagnosis machine, causes the computer application to: transmit a first control signal to cause the metal powder production machine to output the scrap metal powder based at least in part on the chemical composition of the scrap metal powder that is determined by the process diagnosis machine; transmit a second control signal to cause the additive manufacturing system to output the downhole exploration and production tool using the scrap metal powder based at least in part on the chemical composition of the scrap metal powder that is determined by the process diagnosis machine; and transmit a third control signal to cause the process diagnosis machine to alter the chemical composition of the scrap metal powder based at least in part on the chemical composition of the scrap metal powder that is determined by the process diagnosis machine by removing at least a portion of the additional metal powder from the scrap metal powder produced by the metal powder production machine; wherein the process diagnosis machine is further configured to perform non-destructive testing on the downhole exploration and production tool to determine whether the downhole exploration and production tool complies with one or more standards for the downhole exploration and production tool relative to downhole conditions to be experienced by the downhole exploration and production tool during formation of the wellbore, wherein compliance with the one or more standards is determined based on chemical composition of the downhole exploration and production tool, density of the downhole exploration and production tool, porosity of the downhole exploration and production tool, or homogeneity of the downhole exploration and production tool as determined by the non-destructive testing.', '2.', 'The system of claim 1, wherein the mobile platform comprises a storage container configured to couple to a vehicle.', '3.', 'The system of claim 1, wherein the additive manufacturing system is configured to receive computer models remotely, and wherein the computer models comprise computer aided drawings of a plurality of manufactured tools.\n\n\n\n\n\n\n4.', 'The system of claim 1, wherein the additive manufacturing system is configured to be controlled by a remote device, and wherein the remote device comprises a smartphone or a tablet.', '5.', 'The system of claim 1, wherein the downhole exploration and production tool comprises a measurement while drilling alternator, a rotary steerable pad, a wear band, a port hole, a flow diverter, a drill bit, or a packer expansion element, or any combination thereof.', '6.', 'The system of claim 1, wherein the additive manufacturing system is configured to output the downhole exploration and production tool via at least one of a hot isostatic pressing process, a powder bed fusion process, or a direct energy deposition process.', '7.', 'The system of claim 1, wherein the process diagnosis machine is configured to determine an amount of the scrap metal powder produced by the metal powder production machine, wherein the computer application, when executed by the computing device in response to receiving the chemical composition of the scrap metal powder that is determined by the process diagnosis machine, causes the computer application to:\ntransmit the first control signal to cause the metal powder production machine to adjust an operating parameter of the metal powder production machine based at least in part on the amount and the chemical composition of the scrap metal powder that is determined by the process diagnosis machine;\ntransmit the second control signal to cause the additive manufacturing system to output the downhole exploration and production tool using the scrap metal powder based at least in part on the amount and the chemical composition of the scrap metal powder that is determined by the process diagnosis machine; and\ntransmit a fourth control signal to cause the additive manufacturing system to adjust an operating parameter of the additive manufacturing system based at least in part on the determination of whether the downhole exploration and production tool complies with the one or more standards for the downhole exploration and production tool.', '8.', 'The system of claim 1, wherein the process diagnosis machine comprises the camera.', '9.', 'The system of claim 1, wherein the process diagnosis machine comprises the dye pen.', '10.', 'The system of claim 1, wherein the process diagnosis machine comprises the x-ray imaging device.', '11.', 'The system of claim 1, wherein the process diagnosis machine comprises the computerized axial tomography scan device.\n\n\n\n\n\n\n12.', 'The system of claim 1, wherein the process diagnosis machine comprises the powder blender.', '13.', 'The system of claim 1, wherein the metal powder production machine comprises the gas atomization process that melts the scrap metal or spare parts into molten metal contained within a ladle of the metal powder production machine, which pours the molten metal into a tundish of the metal powder production machine, wherein the tundish comprises a hole in a bottom of the tundish through which the molten metal flows and comes into contact with an atomizing gas spray, wherein the atomizing gas spray separates the molten metal into metal particles that harden into the scrap metal powder in an atomizing chamber of the metal powder production machine.\n\n\n\n\n\n\n14.', 'The system of claim 1, wherein the metal powder production machine comprises the water atomization process that melts the scrap metal or spare parts into molten metal contained within a ladle of the metal powder production machine, which pours the molten metal into a tundish of the metal powder production machine, wherein the tundish comprises a hole in a bottom of the tundish through which the molten metal flows and comes into contact with an atomizing water spray from a high-pressure water manifold of the metal powder production machine, wherein the atomizing water spray separates the molten metal into metal particles that harden into the scrap metal powder and combine with water from the atomizing water spray in an atomizing tank of the metal powder production machine, and wherein the metal powder production machine further includes a separation flow path within which the scrap metal powder and the water separate.', '15.', 'The system of claim 1, wherein the metal powder production machine comprises the centrifugal atomization process that melts the scrap metal or spare parts into molten metal contained within a ladle of the metal powder production machine, which pours the molten metal into a tundish of the metal powder production machine, wherein the tundish comprises a hole in a bottom of the tundish through which the molten metal flows and comes into contact with a spinning disk of the metal powder production machine, wherein the spinning disk separates the molten metal into metal particles that harden into the scrap metal powder.\n\n\n\n\n\n\n16.', 'The system of claim 1, wherein the metal powder production machine comprises the consumable electrode atomization process wherein the scrap metal or spare parts are fitted into a spindle of the metal powder production machine such that the metal powder production machine becomes a rotating consumable electrode, wherein the spindle and rotating consumable electrode are placed in a chamber of the metal powder production machine that is filled with an inert gas flow, wherein the chamber comprises a nonrotating electrode opposite the rotating consumable electrode through which electricity passes to melt the rotating consumable electrode while the rotating consumable electrode spins such that metal particles separate from the rotating consumable electrode, and wherein the metal particles harden into the scrap metal powder and fall into a collection port of at a bottom of the chamber.']

['FIG. 1 illustrates an oil and gas work site that may employ the systems and methods of this disclosure;; FIG.', '2 is an embodiment of a schematic flow diagram of a component production system for producing components at the oil and gas site of FIG.', '1;; FIG.', '3A illustrates a first embodiment of a metal powder production machine of the component production system of FIG.', '2;; FIG.', '3B illustrates a second embodiment of the metal powder production machine of the component production system of FIG.', '2;; FIG.', '3C illustrates a third embodiment of the metal powder production machine of the component production system of FIG.', '2;;', 'FIG.', '3D illustrates a fourth embodiment of the metal powder production machine of the component production system of FIG.', '2;; FIG.', '4A illustrates a first embodiment of an additive manufacturing system of the component production system of FIG.', '2;; FIG.', '4B illustrates a second embodiment of the additive manufacturing system of the component production system of FIG.', '2;; FIG.', '4C illustrates a third embodiment of the additive manufacturing system of the component production system of FIG.', '2;; FIG. 5 illustrates possible components manufactured by the additive manufacturing system of the component production system of FIG.', '2; and; FIG.', '6 is a flow chart depicting an embodiment of a method of producing a component at an industrial work site, such as the oil and gas work site of FIG.', '1.; FIG. 2 is an embodiment of a schematic flow diagram of a component production system 42 for producing components at the oil and gas site of FIG.', '1.', 'The component production system 42 includes a metal source 44, the metal powder production machine 28, the additive manufacturing system 30, and a process diagnosis machine 46 (e.g., a machine that monitors and/or diagnoses any other disclosed machine and/or process).', 'The metal source 44 may be the metal from the metal area 26 shown in FIG.', '1.', 'The metal source 44 provides metal to the metal powder production machine 28, which receives the metal and outputs a metal powder.', 'The metal powder produced by the metal powder production machine 28 is then used by the additive manufacturing system 30 to produce a desired component.; FIGS.', '3A through 3D illustrate embodiments of the metal powder production machine 28.', 'FIG.', '3A illustrates an embodiment of a metal powder production machine 28A that uses a gas atomization process to receive a molten metal and output a metal powder.', 'The scrap metal is first melted into a molten metal 52 and contained within a ladle 50.', 'The ladle 50 then pours the molten metal 52 into a tundish 54.', 'Then the molten metal 52 flows through the hole in the bottom of the tundish 54 and comes into contact with an atomizing gas spray 56, which separates the molten metal 52 into metal particles 60.', 'The metal particles 60 then harden into a metal powder in an atomizing chamber 58.;', 'FIG.', '3B illustrates an embodiment of a metal powder production machine 28B that uses a water atomization process to receive a molten metal and output a metal powder.', 'The scrap metal is first melted into a molten metal 52 and contained within a ladle 50.', 'The ladle 50 then pours the molten metal 52 into a tundish 54.', 'Then the molten metal 52 flows through the hole in the bottom of the tundish 54 and comes into contact with an atomizing water spray 61 from a high-pressure water manifold 62, which separates the molten metal 52 into metal particles 60.', 'The metal particles 60 then harden into a metal powder and combine with water from the atomizing water spray 61 in an atomizing tank 64.', 'Then the mixture of the metal particles 60 and water flow along a path 66 to separate the metal particles 60 and the water.; FIG.', '3C illustrates an embodiment of a metal powder production machine 28C that uses a centrifugal atomization process to receive a molten metal and output a metal powder.', 'The scrap metal is first melted into a molten metal 52 and contained within a ladle 50.', 'The ladle 50 then pours the molten metal 52 into a tundish 54.', 'Then the molten metal 52 flows through the hole in the bottom of the tundish 54 and comes into contact with a spinning disk 68, which separates the molten metal 52 into metal particles 60.', 'The metal particles 60 then harden into a metal powder and are collected.', '; FIG.', '3D illustrates an embodiment of a metal powder production machine 28D that uses a rotating consumable electrode atomization process to receive a conductive solid metal and output a metal powder.', 'The scrap metal is fitted into a spindle 70 such that the scrap metal becomes a rotating consumable electrode 72.', 'The spindle 70 and the rotating consumable electrode are placed in a chamber 74 that may be filled with an inert gas flow 76 through a first port 78 and/or the gas may be evacuated along a vacuum flow path 80 through a second port 82.', 'A nonrotating electrode (e.g., a tungsten electrode) 84 may be inserted into the chamber 74, opposite of the rotating consumable electrode 72.', 'Then, electricity is passed through the non-rotating electrode 84, which causes the rotating consumable electrode 72 to begin melting.', 'While the rotating consumable electrode 72 is melting, the rotating consumable electrode 72 is spun such that as the rotating consumable electrode 72 melts, metal particles 60 separate from the rotating consumable electrode 72.', 'Then, the metal particles 60 harden and fall into a collection port 86 at the bottom of the chamber 74.; FIGS.', '4A through 4C illustrate embodiments of the additive manufacturing system 30.', 'FIG.', '4A illustrates an embodiment of an additive manufacturing system 30A that uses a powder bed fusion (“PBF”) process to receive a metal powder and output a component.', 'First, a controller 100 receives a computer model (e.g., a computer aided design drawing or computer aided manufacturing drawing) of a manufactured component 101 to be produced.', 'For example, a user may interact with a display 105 to select a computer model.', 'The display 105 may be physically coupled to the controller 100, or the display 105 may be remotely located.', 'For example, the display 105 may be coupled to a different controller and remotely send (e.g., via Bluetooth, internet web link, etc.)', 'the computer model to the controller 100.; FIG.', '4B illustrates an embodiment of an additive manufacturing system 30B that uses a direct energy deposition process to receive a metal powder and output a component.', 'A focused thermal energy source 142 (e.g., a laser) is provided to melt the metal powder 60.', 'The metal powder 60 is blown through one or more metal powder delivery nozzles 140 toward the focused thermal energy source 142.', 'As the metal powder 60 passes through the focused thermal energy source 142, the metal powder 60 melts onto a deposition surface 144 of the manufactured component 101.', 'The metal powder 60 is deposited onto the manufactured component 101 until the manufactured component 101 is complete.;', 'FIG.', '4C illustrates an embodiment of an additive manufacturing system 30C that uses a hot isostatic pressing process to receive a metal powder and output a component.', 'The metal powder 60 is inserted into a chamber 150 filled with an inert gas 152 (e.g., argon).', 'The metal powder 60 may be inserted into the chamber 150 in the desired shape of the manufactured component.', 'Then the chamber 150 is heated, causing the pressure inside the chamber 150 to increase.', 'In some embodiments, more inert gas 152 may be pumped into the chamber 150 to achieve the desired pressure.', 'The heat and pressure inside of the chamber 150 causes the metal powder 60 to solidify into one piece.', 'In addition, the pressure inside of the chamber 150 may be applied to components manufactured by either the additive manufacturing system 30A or the additive manufacturing system 30B to reduce the porosity and/or increase the density of the components.; FIG.', '5 illustrates possible components 170 manufactured by the additive manufacturing system 30.', 'The possible components may include measurement while drilling alternators, rotary steerable pads wear band and stabilizer repair, port holes, flow diverters, drill bits, packer expansion elements, etc.', 'As illustrated by the possible components 170, the additive manufacturing system 30 may manufacture a component having any shape or internal structure.', '; FIG.', '6 is a flow chart depicting an embodiment of a method 180 of producing a component at an industrial work site.', 'Although the following method 180 describes a number of operations that may be performed, it should be noted that the method 180 may be performed in a variety of suitable orders and all of the operations may not be performed.', 'Further, some or all of the steps may be implemented by any combination of the control system 40, the metal powder production machine 28, the additive manufacturing system 30, or the process diagnosis machine 46.']

US11761978

Vibration monitor

Feb 26, 2021

Christophe Laurent, Hugues Trifol

Schlumberger Technology Corporation

Machine translation of CN109642460 (Year: 2019).

8010312; August 30, 2011; Hocker; 9291520; March 22, 2016; Fleury, Jr.; 10673143; June 2, 2020; Osawa; 20200072661; March 5, 2020; Forster-Knight

109642460; April 2019; CN; 2021/174179; September 2021; WO

['A vibration monitoring apparatus is disclosed that includes a vibration sensor, a controller electrically coupled to the vibration sensor, a power unit electrically coupled to the controller and the vibration sensor, and an environment-resistant material encapsulating the vibration sensor, the controller, and the power unit.', 'The vibration monitoring apparatus includes processing capability to process vibration data and transmission hardware to transmit processed or unprocessed vibration data.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application claims benefit of U.S. Provisional Patent Application Ser.', 'No. 62/982,764 filed Feb. 28, 2020, which is incorporated herein by reference.', 'FIELD\n \nEmbodiments herein generally relate to hydrocarbon prospecting.', 'Specifically, methods and apparatus are disclosed for monitoring equipment vibration in processing environments.', 'BACKGROUND\n \nIn oil and gas production, and particularly in testing of hydrocarbon well production, it can be useful to monitor vibration in piping and equipment.', 'Vibration monitoring in piping can help in understanding of flow characteristics such as multi-phase flow rates, flow obstructions from, for example, hydrate formation, flow leakage, flow changes at the choke of a well testing facility, gun shock detecting, and sand characteristics.', 'Vibration monitoring in equipment can help in understanding reliability of the equipment, the need for preventive maintenance, and nascent malfunctions.', 'Current solutions for vibration monitoring are limited.', 'Most are connected by wire and are sensitive to environmental factors such as moisture.', 'There is a need in the industry for a more useful vibration monitoring solution.', 'SUMMARY\n \nEmbodiments described herein provide a vibration monitoring apparatus that includes a vibration sensor, a controller, and a power unit all encapsulated in an environment-resistant material.', 'Other embodiments described herein provide a vibration monitoring apparatus, comprising an accelerometer, a controller electrically coupled to the accelerometer, a storage unit electrically coupled to the controller, an inductively rechargeable battery electrically coupled to the accelerometer, the controller, and the storage unit, and an environment-resistant material encapsulating the accelerometer, the controller, the storage unit, and the inductively rechargeable battery.', 'Other embodiments described herein provide a vibration monitoring apparatus, comprising an operative unit encapsulated in an environment-resistant material\n \nOther embodiments described herein provide a monitoring system including a plurality of operating units connected by fluid conduits and at least a vibration monitoring apparatus as described hereinabove coupled to one of the operating units and the fluid conduits, wherein the monitoring system is for processing liquid and gaseous hydrocarbons produced from a hydrocarbon reservoir, wherein the plurality of operating units include at least one of a phase separator, surge tank, pump, liquid manifold, gas manifold, heater, a valve, a flow meter\n \n \nBRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the appended drawings.', 'It is to be noted, however, that the appended drawings illustrate only exemplary embodiments and are therefore not to be considered limiting of its scope, may admit to other equally effective embodiments.\n \nFIG.', '1\n is an isometric view of a vibration monitoring apparatus according to one embodiment.\n \nFIG.', '2\n is a top view of a circuitry portion of the vibration monitoring apparatus of \nFIG.', '1\n, according to one embodiment.', 'FIG.', '3\n is a block diagram of a microcontroller of the circuitry portion of \nFIG.', '2\n.', 'FIG.', '4\n is a schematic plan view of a processing system according to one embodiment.\n \nFIG.', '5\n is a schematic top view of a vibration monitoring apparatus according to another embodiment of the disclosure.\n \nFIG.', '6\n is a flow diagram summarizing a method according to one embodiment of the disclosure.', 'To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures.', 'It is contemplated that elements and features of one embodiment may be beneficially incorporated in other embodiments without further recitation.', 'DETAILED DESCRIPTION\n \nFIG.', '1\n is a functional block diagram of a vibration monitoring apparatus \n100\n according to one embodiment.', 'The apparatus \n100\n includes a container \n102\n that facilitates attachment of the apparatus \n100\n to a tubular object such as a cylindrical pipe.', 'The container \n102\n is made of a material that is resistant to high temperatures and hydrocarbon environments, including acids normally encountered in hydrocarbon processing.', 'Plastics such as polypropylene, polyurethane, and polyisocyanate, and mixtures thereof, can be used.', 'The container \n102\n can be molded or printed.', 'The container \n102\n has a non-planar contact surface \n104\n for transmitting vibration from the tubular object to a vibration sensor \n106\n, located in a circuitry portion \n108\n of the apparatus \n100\n.', 'The non-planar contact surface \n104\n may be angled, with a single angle as in \nFIG.', '1\n, or may have multiple angles or may be curved.', 'The non-planar contact surface \n104\n is configured to contact an object to be monitored for vibration at more than one contact point.', 'Contacting the object at more than one contact point increases attachment stability of the apparatus \n100\n to the object being monitored.', 'The apparatus \n100\n may have a fastening device, such as a strap or bracket, to fasten the apparatus \n100\n to the object for monitoring.', 'The container \n102\n here has two separable parts.', 'A first part \n120\n fits within a second part \n122\n.', 'The second part \n122\n has the contact surface \n104\n, and both the first part and the second part are made of plastic, as described above.', 'The first part \n120\n has the circuitry portion \n108\n.', 'The circuitry portion \n108\n extends over an area, and in this case is rectangular, but could be any shape.', 'A stand portion \n126\n extends from the circuitry portion \n108\n in a direction generally perpendicular to a plane defined by the circuitry portion \n108\n.', 'Here, the stand portion \n126\n comprises two walls \n128\n that extend in a direction along an axis of the first part \n120\n and extend from opposite sides of the circuitry portion \n108\n away from the plane defined by the circuitry portion in a direction perpendicular to the plane.', 'Between the walls \n128\n is a notch \n130\n that extends in the same direction as the walls \n128\n in the direction along the axis of the first part \n120\n.', 'The notch \n130\n allows the walls \n128\n to straddle a peak \n132\n of the second part \n122\n, extending in the direction along the axis of the first part \n120\n, that in part defines the non-planar surface \n104\n.', 'At least one of the walls \n128\n has a recess \n134\n in an outer surface thereof that generally extends in the direction along the axis of the first part \n120\n.', 'The recess, in this case, is a battery compartment, where a battery unit \n136\n is disposed.', 'The battery unit \n136\n includes one or more rechargeable batteries capable of integration with an inductive charging portion.', 'When the stand portion \n126\n is placed on a surface, and the circuitry portion \n108\n and battery unit \n136\n are installed, the battery unit \n136\n resides beneath the circuitry portion \n108\n in the recess \n134\n.', 'Connectors (not shown) are provided in the recess \n134\n for electrically coupling the battery unit \n136\n with the circuitry portion \n108\n.', 'The first part \n120\n is assembled, with the stand portion \n126\n, circuitry portion \n108\n, and battery unit \n136\n, and is then placed into the second part \n122\n.', 'The walls \n128\n contact an interior of the second part \n122\n when the first part \n120\n is placed into the second part \n122\n, straddling the peak \n132\n, as mentioned above.', 'The second part \n122\n thus has a non-planar interior surface that engages with the walls \n128\n.', 'In other embodiments, the second part \n122\n may be shaped to provide the non-planar contact surface \n104\n on the exterior of the second part \n122\n and a planar interior surface for engaging with the first part \n120\n.', 'Any mode of engagement between the first part \n120\n and the second part \n122\n may be contemplated.', 'For example, the interior surface of the second part \n122\n may be concave, and/or may have a groove for engaging with the walls \n128\n.', 'The first part \n120\n and the second part \n122\n together define a gap \n138\n in an interior space of the second part \n122\n.', 'When the first part \n120\n is installed into the second part \n122\n, the gap may be filled with a sealant material that encapsulates the electronics, insulating the electronics from the environment.', 'In this case, the battery unit \n136\n is also encapsulated, so charging the battery unit \n136\n requires remote charging such as inductive charging.', 'For this reason, a charging portion \n140\n is included in the circuitry portion \n108\n within the container \n102\n.', 'The first part \n120\n has a lid \n142\n that encloses the circuitry portion \n108\n.', 'In this case, the lid \n142\n has a plurality of holes \n146\n that allow viewing of indicator lights \n148\n attached to the circuitry portion \n108\n.', 'The indicator lights \n148\n show a status of the apparatus \n100\n, in this case battery charge.', 'The lid \n142\n of the first part \n120\n is installed before the second part \n122\n is filled with encapsulant, so the electronics inside the first part \n120\n (e.g. the circuitry portion \n108\n and the battery unit \n136\n) are sealed within the apparatus \n100\n.', 'The second part \n122\n, in this case, does not have a lid.', 'The second part \n122\n is a container that holds the first part \n120\n and is filled with encapsulant to protect and immobilize the first part \n120\n, and hardware contained in the first part \n120\n.', 'A lid can be used, if desired, with the second part \n122\n.', 'For example, after filling the second part \n122\n with encapsulant, a lid can be applied before the encapsulant sets.', 'The gap between the first part \n120\n and the second part \n122\n is large enough to provide a layer of protective encapsulant between the electronic hardware in the first part \n120\n and the outer environment.', 'Sealing the electronics inside an environment resistant encapsulant makes the apparatus \n100\n usable in various restricted ways.', 'Disposing the operative components of the vibration monitor \n100\n inside the first part before encapsulating allows the components to be accessed, following encapsulation, by cutting through the second part \n122\n, the encapsulant, and the first part \n120\n.', 'The operative components can then be maintained or replaced.', 'The operative components can then be disposed in another first part \n120\n and second part \n122\n, and re-encapsulated.', 'By encapsulating the operative components, the apparatus \n100\n is ATEX Zone 1 compliant and is an “mb” type apparatus under EN-60079-18.', 'The circuitry portion \n108\n of the first part \n120\n sits below the top of the second part \n122\n to allow encapsulant to flow over and seal all around the first part \n120\n without spilling out of the second part \n122\n.', 'Thus, in this case, the second part \n122\n extends 3-6 mm above the top of the first part \n120\n to provide a layer of encapsulant over the first part \n120\n that is thick enough for protection and thin enough to allow for inductive charging from an inductive source on the inside surface of the lid \n142\n.', 'The encapsulant is generally an environment-resistant material derived from a precursor that can flow into the gap between the first and second parts \n120\n and \n122\n before solidifying into the environment-resistant material.', 'The type of encapsulant can be selected based on the environment in which the vibration monitor is to be used.', 'Many encapsulants that are convenient for such purposes are A/B polymers made by blending a liquid A material with a liquid B material and allowing the mixture to cure.', 'Polyurethanes, epoxies, and amine-aldehyde resins are examples of resins that can be used to encapsulate the components of the vibration monitors described herein.', 'Resins from conjugate reactions such as Michael reactions or Diels-Alder reactions can also be used.', 'Mixtures and multi-polymers of such materials can also be used.', 'Such materials are useable in many environments that would otherwise be hostile or inadvisable for electronic components.', 'For example, the encapsulated vibration monitors described above can be used while immersed in water, or in a chemically active atmosphere or liquid, such as acidic or basic liquids or atmospheres.', 'The encapsulant can be impregnated with other types of barriers to extend the range of atmospheres and environments in which they can be used.', 'For example, lead shielding can be applied to the outside of the first part \n120\n, if desired, to allow using the vibration monitor in a radioactive environment.', 'Alternately, shielding particles such as lead or lead oxide particles can be incorporated in the encapsulant precursor liquid material to provide radiation shielding following cure.', 'If viscosity of the liquid precursor material becomes too high, solvent can be used to target a workable viscosity so that the gap between the first and second parts \n120\n and \n122\n can be filled.', 'The vibration monitoring apparatus \n100\n of \nFIG.', '1\n has a second vibration sensor \n133\n.', 'The second vibration sensor \n133\n is an optional component that can be used to increase the frequency response range of the apparatus \n100\n.', 'The second vibration sensor \n133\n is configured to have usable sensitivity in frequency ranges where the vibration sensor \n106\n has low sensitivity.', 'For example, in one embodiment, a MEMS device may have useful frequency response up to about 2 kHz, while a microphone has useful frequency response above 2 kHz.', 'The second vibration sensor \n133\n may be located along a lower surface of the apparatus \n100\n to be located close to the source of vibration.', 'Since higher frequency vibrations tend to attenuate over shorter distances than lower frequency vibrations, locating the second vibration sensor \n133\n closer to the source of vibration increases detectability of high frequency vibrations.', 'The second vibration sensor \n133\n may be located inside the second part \n122\n or on an outer surface of the second part \n122\n.', 'FIG.', '2\n is a plan view of the circuitry portion \n108\n of the apparatus \n100\n.', 'The vibration sensor \n106\n is a 3-axis vibration sensor located in a central area of the circuitry portion \n108\n.', 'The vibration sensor \n106\n is for instance a MEMS accelerometer, such as an MPU \n9250\n accelerometer.', 'The circuitry, including the vibration sensor \n106\n, of the circuitry portion \n108\n is attached to a circuit board \n202\n that integrates with the first part \n120\n of the apparatus \n100\n.', 'The vibration sensor \n106\n is electrically coupled to a digital microcontroller unit \n204\n.', 'A voltage regulation circuit (not shown) can be included in the circuitry portion to condition power coming from the batteries \n136\n to the circuitry portion \n108\n and/or to condition power going from the charging unit \n140\n to the batteries \n136\n.', 'The circuitry components shown as part of the circuitry portion \n108\n are shown in a configuration parallel to the circuit board \n202\n, and generally in rectilinear alignment with the circuit board \n202\n.', 'The circuitry components can be oriented non-parallel with the circuit board \n202\n, if desired.', 'For example, socket connections can be provided on the circuit board \n202\n, and the circuitry components, as appropriate, can be connected by insertion into the socket connector, such that the circuitry components so connected are substantially perpendicular to the circuit board \n202\n.', 'Other orientations can also be used.', 'Additionally, the circuitry components can be unaligned with respect to the rectilinear orientation of the circuit board \n202\n.', 'For example, one or more of the circuitry components could be positioned such that a major axis of the circuitry component forms an angle with a major axis of the circuit board \n202\n that is not zero or 90°.', 'In certain situations, the vibration sensor \n106\n may be oriented to amplify its sensitivity.', 'For example, if the vibration sensor \n106\n has sensitivity in two perpendicular directions, the vibration sensor \n106\n can be oriented to sense a vibration mode in a direction that is a vector sum of the two perpendicular directions, such that the sensitivity of each perpendicular direction contributes to the overall sensitivity in the direction of the vibration mode to be detected.', 'FIG.', '3\n is a block diagram showing units of the digital microcontroller unit \n204\n.', 'Here, the digital microcontroller unit \n204\n includes a core module \n302\n, which has a digital processor \n304\n, that generally operates at a high-frequency clock speed, ROM \n303\n, and SRAM memory \n305\n.', 'The digital microcontroller unit \n204\n contains programming, stored in the ROM \n303\n and/or the RAM \n305\n, that when executed by the digital processor \n304\n causes the digital processor to perform certain pre-processing of vibration data.', 'Such pre-processing may include frequency analysis such as Fast Fourier Transform analysis.', 'Any other type of integral transform analysis can be included to target specific frequencies and patterns of vibration.', 'Other processing to amplify, diminish, focus, or defocus known or suspected patterns of vibration, such as noise treatment, frequency filtering and amplification, signal-to-noise optimization, and other treatments can be included in the pre-processing programming.', 'Convolution and deconvolution processing can be included.', 'Pre-processing the vibration data can reduce the volume of data to be transmitted by the vibration monitor \n100\n.', 'It should be noted that the pre-processing is optional, that the vibration monitor \n100\n may, additionally or instead, transmit raw vibration data.', 'Raw vibration data can be used for troubleshooting and diagnosis of problems with the vibration monitor, or for quality control of the data produced by the vibration monitor.', 'The digital microcontroller unit \n204\n also includes a communication module \n306\n, which has radio, BLUETOOTH, and WiFi transceivers.', 'An SD card may be provided for mass storage of vibration data.', 'When pre-processing vibration data, the digital processor \n302\n can obtain vibration data from the SD card, process the vibration data, and store the processed data on the SD card Flash memory \n308\n, hardware acceleration unit \n310\n, and low power management subsystem \n312\n which are provided, along with several peripheral interfaces, with/in an interface module \n314\n, for secure communication, infrared, Ethernet, temperature sensors, touch sensors, A/D converters, and serial interfaces.', 'The serial interface of the digital microcontroller unit \n204\n is electrically coupled to the vibration sensor \n106\n by a serial bus \n206\n.', 'In one case, the apparatus \n100\n uses the MQTT communication protocol for wireless communication, but any convenient protocol can be used.', 'The interfaces can be used to integrate other sensors with the vibration sensor.', 'For example, a temperature sensor can be connected using one of the interfaces and used to monitor temperature in the environment around the vibration monitor.', 'The temperature sensor would be located near the surface of the environment-resistant encapsulant to sense the environmental temperature.', 'In one embodiment, the temperature sensor can be wired to one of the interfaces using a wire that extends across the gap between the first and second parts \n120\n/\n122\n of \nFIG.', '1\n.', 'The environment-resistant material is then formed in the gap, leaving the temperature sensor outside the environment-resistant material and wired to the vibration monitor through the environment resistant material.', 'The temperature sensor can then be attached to the environment-resistant material using a thin film of encapsulant\n \nThe charging portion \n140\n is included in the circuitry portion \n108\n and electrically coupled to the battery unit \n136\n (not shown in \nFIG.', '2\n), which when assembled is located on the opposite side of the circuit board \n202\n from the circuitry portion \n108\n.', 'The charging portion \n140\n charges the battery unit \n136\n, and can be powered by an inductive source.', 'An inductive source is attached to the interior surface of the lid \n142\n of the first part \n120\n, in this case, but may be coupled to the apparatus \n100\n at any convenient location.', 'A smart reboot circuit \n210\n (\nFIG.', '2\n) may be included in this embodiment to reboot the processing hardware, after a low power shutdown, when charging commences.', 'For example, in a low power situation, the low power management subsystem \n312\n (\nFIG.', '3\n) activates to supply power to essential components.', 'When charging begins, the smart reboot circuit \n210\n is configured to reboot the processing hardware automatically.', 'FIG.', '4\n is a schematic plan view of a monitoring system \n400\n according to one embodiment.', 'The monitoring system \n400\n of \nFIG.', '4\n has a monitoring area \n402\n and a non-monitoring area \n404\n.', 'The monitoring area \n402\n has a plurality of operating units \n406\n connected by fluid conduits \n408\n.', 'A plurality of vibration monitors \n100\n is coupled to the various operating units \n406\n and fluid conduits \n408\n to monitor vibration in all areas of the monitoring system \n400\n.', 'The monitoring area \n402\n may have environment or atmosphere that is incompatible with operating electronics, but the vibration monitors \n100\n are all sealed for isolation from the environment to prevent unwanted interaction between the electronics and the environment.', 'A data hub \n410\n is located in the non-monitoring area \n404\n.', 'The non-monitoring area \n404\n has an environment that is not incompatible with operating electronics, so the data hub \n410\n can be safely located and operated in the non-processing area \n404\n.', 'The data hub \n410\n includes wireless communication hardware for communicating with the vibration monitors \n100\n, each of which has wireless communication hardware, as described above.', 'The data hub \n410\n can also have processing capability for analyzing vibration patterns in the data harvested from the vibration monitors \n100\n.', 'All the processing routines described above for the digital microcontroller unit \n204\n can also be included in the data hub, for example if the vibration monitor \n100\n transmits raw vibration data.', 'The data hub \n410\n may then include hardware and software for performing Fourier Transform, or other integral transform, analysis of the vibration data.', 'For example, in one case, the data hub includes a Fast-Fourier Transform algorithm.', 'Other noise treatment, signal-to-noise treatment, filtering, and optimization routines and capabilities may be included in the data hub.', 'The data hub \n410\n can also include hardware and software for operating artificial intelligence analysis routines, such as neural networks and principal component analysis routines.', 'The various processing routines can be arranged to work in serial and/or parallel modes by arranging processing flow within the data hub \n410\n.', 'The data hub \n410\n is also configured to communicate with one or more of the operating units \n406\n via a wired or wireless communication.', 'The data hub may also include a user interface for interacting with a user, such as as display, tablet, etc.', 'The operating units \n406\n may be any operating units, but in one example, the operating units \n406\n are for processing liquid and gaseous hydrocarbons produced from a hydrocarbon reservoir.', 'So, for example, the operating units \n406\n may include phase separators, surge tanks, pumps, liquid and gas manifolds, heaters, valves, flow meters and the like.', 'A liquid product line \n416\n and a gas product line \n410\n are included in this case.', 'As shown in \nFIG.', '4\n, the vibration monitoring apparatus \n100\n can be coupled in all manner to operating units and conduits to monitor vibration in any part of the monitoring system.', 'If desired, vibration monitors \n100\n can be moved from one location in the monitoring system \n400\n to another.', 'The vibration monitors can indicate equipment failure or near failure and detect flow or lack thereof in a conduit.', 'For example, in a first application, if a valve (such as a safety relief valve) is activated (opened or closed), a vibration monitor disposed on the valve may detect activation of the valve or leak at the valve.', 'For such application, the vibration monitor may also enable to determine fatigue of the valve.', 'In a first embodiment, activation of the valve may be determined by comparing the vibration data to a threshold.', 'For instance, a processed signal of the vibration monitor \n100\n may be compared with one or more threshold, for instance in one or more frequency bands.', 'In a second embodiment, the status of the valve may be determined by comparing a signal based on the vibration data to a calibration signal representative of at least one event signature.', 'In the present case, for instance, the processed signal of the vibration monitor \n100\n may be compared to a plurality of calibration signals corresponding respectively to one or more functional valve activation signatures, one or more fatigued valve activation signatures and one or more valve leak signatures.', 'In order to determine to which signature the processed signal corresponds, specific features of the signal may be extracted and compared to the calibration signals.', 'Alternatively, a machine learning model (such as neural network) may be used to classify the processed signal in view of the calibration signals.', 'In another application, a vibration monitor can analyze the material flowing in the conduit.', 'For instance, the vibration monitor can detect when solids, are present in a fluid flow and possibly determine the type of the solids, either rocks, metal, sand or hydrate solids.', 'The vibration monitor can also be used to infer fluid nature, for example, if the fluid consists of gas, oil, water or a mix of several fluids, which is especially advantageous in applications where sampling is challenging (such as when the fluid comprises a toxic gas such as H2S or solids that may damage the sampling installation).', 'As explained above, the presence of solids or type of fluid flow may be detected by comparing the processed signal obtained from the vibration monitor with one or more calibration signal corresponding to the signatures of the flow in different configuration (including different type of solids or with different flow composition).', 'Such comparison may be performed as indicated above using classical processing or machine learning techniques.', 'In a third application specific to a floating platform, a vibration monitor \n100\n may enable to establish reference vibration of the platform (due for instance to a crane activation).', 'More generally, changes in vibration patterns can also be detected by the vibration monitors \n100\n and related to significant events involving the monitored equipment.', 'As explained above, a signal based on the vibration data obtained from the vibration sensor, such as a signal representative of raw vibration data or of processed data may be compared with calibration signals corresponding to one or more event signature in order to detect such events.', 'The output of the vibration monitor may be used by the data hub to perform one or more actions in connection with the monitoring system.', 'In a first embodiment, it may be used to correct a measurement performed by an operating unit of the monitoring system.', 'For instance, in the third application mentioned above, the reference vibration of the floating platform may be used to correct the output of a flow meter, such as a Coriolis flow meter, also disposed on the floating platform and perturbated by the reference vibration.', 'In another embodiment, it may be used to trigger an alarm on a user interface.', 'For instance, in the first application, it may generate an alarm to let the user know that the relief safety valve has been opened, which may trigger an emergency procedure.', 'If a leak or fatigue on a valve is detected, an alarm for maintenance on this valve may also be triggered.', 'Similarly, in the second application, if sand is detected, an alarm for inspection and maintenance of sand filters may be triggered.', 'The alarm may be visual (such as on a display of the user monitor), and/or auditive.', 'In another embodiment, the output of the vibration monitor may be used as an input to generate a parameter value of one or more of the operating units of the monitoring system based on a model of the system stored in the data hub (such model using for instance historical data that comprise operational adjustment data for operational adjustments responsive to conditions).', 'For instance, a parameter of one of the units of the system may be generated in order to obtain optimal operational conditions of the system, emergency operational conditions or diagnostic conditions for diagnostics of unit of the system.', 'Once the parameter is generated, the system may be automatically controlled using the generated parameter value.', 'A method for automatically controlling a system based on sensor data—in this case, vibration monitor data, is described in more details in the U.S. Provisional application entitled “Autonomous Surface System” having Ser.', 'No. 62/982,766, filed 28 Feb. 2020, which is incorporated by reference herein.', 'For instance, in the first application described hereinabove, when the activation of the safety relief valve is detected via the vibration monitor, emergency procedures modifying the parameter values of one or more units such as the phase separator may be triggered by the control system.', 'Similarly, in the second application, when a certain fluid flow is detected, parameter values of the phase separator may be modified so that the separator is tuned to analyze the flow in an optimal way.', 'In another example, when hydrates in a solid form are detected, the temperature of a heater of the monitoring system may be increased.', 'The monitoring system \n400\n may also include a charging station \n412\n for wirelessly charging the vibration monitors \n100\n, for example using inductive charging.', 'A vibration monitor \n100\n with low battery charge, as indicated by the indicator lights \n148\n (\nFIG.', '1\n), or by signal to the data hub \n410\n, can be uncoupled from the equipment or conduit being monitored and can be brought to the charging station \n412\n for recharging.', 'After recharging, the vibration monitor \n100\n can be redeployed at a convenient time and location.', 'For example, one or more extra vibration monitors \n100\n can be staged at the charging station \n412\n.', 'When a vibration monitor \n100\n in the monitoring area \n402\n reaches a low battery state, it can be replaced with one of the extra vibration monitors \n100\n from the charging station \n412\n so that there is essentially no interruption in monitoring.', 'The vibration monitor \n100\n with low battery can then be taken to the charging station \n412\n and recharged for future redeployment.', 'The vibration monitors described herein can be used for monitoring any vibration detectable by the device.', 'The vibration monitor may be in contact with a vibrating object, or may be spaced apart from the vibrating object but still able to detect the vibration.', 'Vibration monitors of this type can be used for a vast array of vibration monitoring, from seismic monitoring, to effects of wind on structures or vehicles, to operating machinery, to acoustics.', 'These vibration monitors can also be used in water without modification.', 'Any vibration detectable in any way by the vibration monitors herein can be monitored and analyzed using the apparatus and methods described herein.', 'The vibration monitors described herein can be used remotely.', 'For example, in the embodiment of \nFIG.', '4\n, the data hub \n410\n may be connected, using a wire or wireless network, to a processing system that includes hardware and software for displaying, integrating, and processing data from vibration monitors at multiple remote locations.', 'In this way, vibration monitors can be deployed by field personnel at multiple locations anywhere in the world, including subsea locations, and the data captured by the vibration monitors can be reviewed and analyzed in one or more centralized locations.', 'In other embodiments, a vibration monitoring apparatus can be made ATEX Zone 1 compliant by enclosing the components of the apparatus in an explosion-proof container, such as an “Ex d” box. \nFIG.', '5\n is a schematic top view of a vibration monitor \n500\n according to another embodiment.', 'The vibration monitor \n500\n has an operational module \n501\n contained within an explosion-proof container \n508\n.', 'The explosion-proof container \n508\n, in this case, has a transparent portion that enables viewing the operational module \n501\n inside.', 'The operational module \n501\n includes a sensor module \n502\n, a data module \n504\n, a communication module \n506\n, and optionally a storage module \n507\n.', 'In this case, power is supplied externally by a power connection \n510\n suitably coupled through a port \n512\n of the container \n508\n.', 'The container \n508\n may have a tab \n514\n, or other type of physical extension, that can be used to attach the vibration monitor \n500\n to an object, such as a pipe, to monitor vibration.', 'A fastener can be used to hold the tab \n514\n against the object to which the vibration monitor \n500\n is fastened.', 'For example, a tie can be looped around the tab \n514\n and around the monitored object to secure the vibration monitor \n500\n to the object.', 'In this case, the vibration monitor \n500\n can forego use of batteries altogether, making the vibration monitor \n500\n battery-less.', 'In other cases, rechargeable batteries can be provided for recharging using the port \n512\n.', 'The communication module \n506\n may be a wireless communication module or a wire communication module.', 'In the embodiment of \nFIG.', '5', ', the communication module \n506\n is a wire communication module, such as an Ethernet module.', 'A wire connection \n516\n is provided through a second portal \n518\n for communicating signals to and from the communication module \n506\n.', 'In the case where the communication module \n506\n is wireless, the wire connection \n516\n can be omitted and the second portal \n518\n omitted, unused, or used for another purpose.', 'In general, while the communication features of the various embodiments described herein can be used to transmit data and/or signals from the vibration monitors to a receiving unit, the communication features can also be used to upload data and/or signals to the vibration monitors from another sending unit.', 'For example, processing commands can be transmitted from a control unit to the vibration monitor.', 'Additionally, firmware and/or calibration data can be uploaded and/or updated on a vibration monitor using the communication features therein.', 'In the case of calibration data, new calibration information can be uploaded for any of the instruments included in the vibration monitor, such as the vibration sensor itself and any other instruments, such as temperature instruments, in the vibration monitor.', 'Various programming can also be uploaded/updated on the vibration monitor, such as programming to perform diagnostic tests, synchronization programming, automated processing and transmission programming, user interface programming, and the like.\n \nFIG.', '6\n is a flow diagram summarizing a method \n600\n according to one embodiment.', 'The method \n600\n is a method of monitoring vibration of a monitored article in a monitoring environment.', 'The monitoring environment may feature an atmosphere with combustible components.', 'At \n602\n, a vibration monitor is enclosed inside an environmental barrier.', 'The vibration monitor includes a chargeable power source, a vibration sensor, a processing unit, and a communication unit.', 'The vibration monitor may also include a storage unit.', 'At \n604\n, the power source is charged wirelessly.', 'For example, the power source may be one or more rechargeable batteries coupled to a wireless charging circuit, such as an inductive charging circuit.', 'The power source, in this case, can be charged by positioning the inductive charging circuit within an inductive field.', 'The environmental barrier is a material that shields the vibration monitor from an external environment that may negatively affect the vibration monitor or react with the vibration monitor in undesired ways.', 'For example, the environmental barrier may be a barrier that prevents a combustible material from reaching the electronics, or other operative components, of the vibration monitor.', 'Alternately, the environmental barrier may be a barrier that prevents components of the environment, such as water, acid, sulfur, and the like, from reaching the electronics, or other operative components, of the vibration monitor.', 'At \n606\n, the vibration sensor is used to form a signal representing detected vibration, and to send the signal to the processing unit.', 'The signal may be a voltage signal or a current signal, which may emanate from a MEMS or piezoelectric vibration sensor, for example.', 'The signal may be conditioned in any suitable way before exiting the vibration sensor, or within the processing unit.', 'At \n608\n, the processing unit is used to form data representing the signal received from the vibration sensor.', 'The data may be a time series of voltage or current, or a convenient transformation thereof.', 'For example, the processing unit may perform any type of integral transform to general spectrum data.', 'The processing unit may also perform modeling, statistical analysis, noise processing, or other useful processing.', 'The processing unit may also perform processing to present the data on an output device, such as a display, to manipulate the data for display purposes, or to prepare the data for communication using the communication module.', 'At \n610\n, the processing unit outputs a signal representing data produced by the processing unit to the storage unit for storage.', 'At \n612\n, the communication module outputs a wireless signal representing data obtained from the processing unit, or directly from the vibration sensor.', 'The wireless signal is output according to a standard that can be interpreted by any receiving device.', 'In this way, the vibration monitor can be completely free of electrical connections outside the oxygen barrier.', 'The communication module may also receive wireless signals sent from an external unit for purposes of programming the processing unit or delivering commands to the processing unit to produce or manipulate data.', 'While the foregoing is directed to embodiments, other and further embodiments of the present disclosure may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.', 'The disclosure relates to a vibration monitoring apparatus, comprising a vibration sensor, a controller electrically coupled to the vibration sensor, a power unit electrically coupled to the controller and the vibration sensor, and an environment-resistant material encapsulating the vibration sensor, the controller, and the power unit.', 'In an embodiment, the power unit comprises an inductively rechargeable battery.', 'In an embodiment, the vibration monitoring apparatus further comprises a wireless transceiver within the environment-resistant material and electrically coupled to the controller.', 'The wireless transceiver may include an MQTT transceiver and/or a BLUETOOTH transceiver (i.e., a transceiver that utilizes the MQTT communication protocol for wireless communication and/or a transceiver that utilizes the BLUETOOTH communication protocol for wireless communication).', 'In an embodiment, the vibration monitoring apparatus further comprises a storage unit within the environment-resistant material and electrically coupled to the controller.', 'In an embodiment, the vibration monitoring apparatus further comprises a digital processor and instructions to cause the digital processor to process vibration data from the vibration sensor.', 'The instructions may include Fast Fourier Transform instructions.', 'In an embodiment, the vibration monitoring apparatus further comprises a first part, into which the vibration sensor, the controller, and the power unit are disposed and a second part into which the first part is disposed, the first and second parts defining a gap into which the environment-resistant material is disposed.', 'The environment-resistant material may be an A/B resin.', 'In an embodiment, the vibration sensor includes an accelerator, in particular a 3-axis MEMS accelerometer.', 'The disclosure also relates to a vibration monitoring apparatus, comprising an accelerometer, a controller electrically coupled to the accelerometer, a storage unit electrically coupled to the controller, an inductively rechargeable battery electrically coupled to the accelerometer, the controller, and the storage unit, and an environment-resistant material encapsulating the accelerometer, the controller, the storage unit, and the inductively rechargeable battery.', 'In an embodiment, the vibration monitoring apparatus further comprises a wireless transceiver within the environment-resistant material and electrically coupled to the controller and to the inductively rechargeable battery.', 'The wireless transceiver may include an MQTT transceiver and/or a BLUETOOTH transceiver.', 'In an embodiment, the accelerometer is a 3-axis MEMS accelerometer.', 'In an embodiment, the controller includes a digital processor with instructions that, when executed by the digital processor, cause the digital processor to perform pre-processing of vibration data.', 'The instructions may include Fast Fourier Transform instructions.', 'The disclosure also relates to a vibration monitoring apparatus, comprising an operative unit encapsulated in an environment-resistant material.', 'The operative unit may comprise a power unit, a vibration sensor, and a transceiver.', 'The operative unit may further comprise a processor.', 'The processor may be configured to process signals produced by the vibration sensor into vibration data and to send the vibration data wirelessly using the transceiver.', 'In an embodiment, the vibration monitoring apparatus further comprises a first part and a second part, the operative unit is disposed in the first part, the first part is disposed in the second part, the first part and the second part define a gap, and the environment-resistant material is disposed in the gap.', 'The disclosure also relates to a monitoring system including a plurality of operating units connected by fluid conduits and at least a vibration monitoring apparatus as disclosed hereinabove coupled to one of the operating units and the fluid conduits, wherein the monitoring system is for processing liquid and gaseous hydrocarbons produced from a hydrocarbon reservoir, wherein the plurality of operating units include at least one of a phase separator, surge tank, pump liquid manifold, gas manifold, heater, a valve, a flow meter.', 'In an embodiment, the vibration monitoring apparatus includes a wireless transceiver as disclosed hereinabove, and the monitoring system further includes a data hub disposed remotely to the operating units, wherein the data hub includes wireless communication hardware to communicate with the at least one vibration monitoring apparatus.', 'The data hub may be configured to communicate with one or more of the operating units.', 'The operating units may be disposed in an atmosphere incompatible with operating electronics contrary to the data hub disposed in a safe atmosphere for operating electronics.', 'In an embodiment, the monitoring system includes a processor and instructions to cause the processor to process vibration data from the vibration sensor to detect an event, wherein the processor is configured to compare a signal based on the vibration data with a calibration signal corresponding to at least a signature of an event.', 'The comparison may be performed using one or more machine learning techniques.', 'The processor may be part of the vibration monitoring apparatus and/or the data hub.', 'In a first application, the vibration monitoring apparatus is disposed on a valve and the processor is configured to detect one or more of activation, leak or fatigue of the valve using the vibration data.', 'In a second application, the vibration monitoring apparatus is disposed on a fluid conduit and the processor is configured to detect using the vibration data, one or more of a fluid type—the fluid is one or more of gas, oil, water, gas, or a combination thereof—a presence of solids, and solids type, in the flow flowing in the fluid conduit.', 'In a third application, the monitoring system is disposed on a floating platform and the processor is configured to determine a reference vibration of the floating platform using the vibration data.', 'In an embodiment where the data hub communicates with the vibration monitoring apparatus and operating units as disclosed above, the data hub is further configured to perform one or more of the following upon detection of an event by the processor: \n \n \n \nCorrect a measurement obtained from an operating unit, such as a measurement obtained from a flow meter that can be corrected using vibration data representative of a reference vibration of a floating platform,\n \nTrigger an alarm through one or more user interface, in particular an emergency alarm when it a safety relief valve is opened, or a maintenance alarm when a leak or fatigue is detected on a valve or when a certain solids type such as sand is detected in a fluid conduit,\n \nGenerate a parameter value of one or more of the operating units based on a model of the monitoring system, in particular a parameter value of a phase separator depending on a detected fluid type or a parameter value of a heater when a certain type of solids (such as hydrates) is detected in the fluid conduit.']

['1.', 'An apparatus configured for attachment to a tubular object and operable for monitoring vibration of the tubular object, wherein the apparatus comprises:\na vibration sensor operable to output vibration data indicative of vibrations of the tubular object;\na controller electrically coupled to the vibration sensor; and\na container assembly comprising: an outer container made of a plastic material and comprising an outer contact surface configured to accommodate and contact the tubular object, wherein the outer contact surface is non-planar; an inner container made of a plastic material and disposed within the outer container, wherein the inner container contains the vibration sensor and the controller; a stand extending between the inner container and the outer container; and\na sealant material disposed within a space defined between the inner container and the outer container, wherein the sealant material encapsulates the inner container; and\nan inductively rechargeable battery electrically coupled to the vibration sensor and the controller.', '2.', 'A system comprising a plurality of operating units connected by fluid conduits and a vibration monitoring apparatus, wherein:\nthe vibration monitoring apparatus comprises a vibration sensor, a controller, and a power unit;\nthe operating units are for processing a fluid comprising liquid and gaseous hydrocarbons produced from a hydrocarbon reservoir;\nthe vibration sensor is operable to output vibration data of a tubular object; and\nthe controller is operable to receive the vibration data and to detect, based on the vibration data, at least one of: a fluid type comprising at least one of gas, oil, water, and a combination thereof; a presence of solids in the fluid; and a solids type in the fluid; and an inner container disposed within an outer container, wherein the inner container contains the vibration sensor and the controller, and wherein the out container has an outer contact surface configured to accommodate and contact the tubular object, wherein the outer contact surface is non-planar; a stand extending between the inner container and the outer container; and a sealant material disposed within a space defined between the inner container and the outer container, wherein the sealant material encapsulates the inner container.', '3.', 'The system according to claim 2, wherein the vibration monitoring apparatus further comprises a wireless transceiver electrically coupled to the controller, wherein the system further includes a data hub disposed remotely to the operating units, and wherein the data hub includes wireless communication hardware to communicate with the vibration monitoring apparatus.', '4.', 'The system according to claim 3, wherein the data hub is configured to communicate with one or more of the operating units.', '5.', 'The system according to claim 2, wherein the controller includes a processor and instructions to cause the processor to process the vibration data from the vibration sensor to detect an event, wherein the processor is configured to compare a signal based on the vibration data with a calibration signal corresponding to a signature of the event, and wherein the event comprises at least one of:\nthe fluid type;\nthe presence of solids; and\nthe solids type.', '6.', 'The system according to claim 2, wherein the operating units comprise a valve, and wherein the controller is further operable to detect, based on the vibration data, one or more of activation, leak, and fatigue of the valve based on the vibration data.', '7.', 'The system according to claim 2, wherein the system is disposed on a floating platform, and wherein the controller is further operable to determine a reference vibration of the floating platform based on the vibration data and to correct a measurement obtained from an instance of the operating units based on the reference vibration.', '8.', 'The system according to claim 2, wherein the controller is further operable to perform one or more of the following upon detection of an event:\ncorrect a measurement obtained from the at least one of the operating units,\ntrigger an alarm through one or more user interface, and\ngenerate a parameter value of the at least one of the operating units based on a model of the system.\n\n\n\n\n\n\n9.', 'The system according to claim 2, wherein the operating units include at least one of a phase separator, surge tank, pump, liquid manifold, gas manifold, heater, a valve, and a flow meter.', '10.', 'An apparatus configured for attachment to a tubular object and operable for monitoring vibration of the tubular object, wherein the apparatus comprises:\na vibration sensor operable to output vibration data indicative of vibrations of the tubular object;\na controller electrically coupled to the vibration sensor; and\na container assembly comprising: an outer container made of a plastic material and comprising an outer contact surface configured to accommodate and contact the tubular object, wherein the outer contact surface is non-planar; an inner container made of a plastic material and disposed within the outer container, wherein the inner container contains the vibration sensor and the controller; a stand extending between the inner container and the outer container; and a sealant material disposed within a space defined between the inner container and the outer container, wherein the sealant material encapsulates the inner container.', '11.', 'The apparatus of claim 10 further comprising a wireless transceiver within the inner container and electrically coupled to the controller, an inductively rechargeable battery electrically coupled to the vibration sensor and the controller, or both.\n\n\n\n\n\n\n12.', 'The apparatus of claim 10 further comprising a data storage unit within the inner container and electrically coupled to the controller.\n\n\n\n\n\n\n13.', 'The apparatus of claim 10 wherein the controller comprises a digital processor and instructions to cause the digital processor to process the vibration data from the vibration sensor.', '14.', 'The apparatus of claim 10 wherein the sealant material is an AB resin.', '15.', 'The apparatus of claim 10 wherein the outer contact surface is curved.', '16.', 'The apparatus of claim 10 wherein the outer contact surface comprises an angle between a first portion of the outer contact surface and a second portion of the outer contact surface.', '17.', 'The apparatus of claim 10 wherein the outer container further comprises an inner surface opposite the outer contact surface, and wherein the inner surface comprises a peak between a first portion of the inner surface and a second portion of the inner surface.', '18.', 'The apparatus of claim 17 wherein the stand comprises a notch between a first portion of the stand and a second portion of the stand, and wherein the notch accommodates at least a portion of the peak.', '19.', 'The apparatus of claim 10 wherein:\nthe vibration sensor is a first vibration sensor;\nthe vibration data is a first vibration data;\nthe outer container further comprises an inner surface opposite the outer contact surface;\nthe apparatus further comprises a second vibration sensor operable to output second vibration data indicative of the vibrations of the tubular object;\nthe second vibration sensor is disposed on the inner surface; and\nthe second vibration sensor comprises a vibration frequency response that is higher than a vibration frequency response of the first vibration sensor.', '20.', 'The apparatus of claim 10 wherein the sealant material is caused to flow into the space between the inner container and the outer container and permitted to solidify such that the sealant material encapsulates the inner container.']

['FIG.', '1 is an isometric view of a vibration monitoring apparatus according to one embodiment.; FIG.', '2 is a top view of a circuitry portion of the vibration monitoring apparatus of FIG.', '1, according to one embodiment.', '; FIG.', '3 is a block diagram of a microcontroller of the circuitry portion of FIG.', '2.; FIG.', '4 is a schematic plan view of a processing system according to one embodiment.; FIG.', '5 is a schematic top view of a vibration monitoring apparatus according to another embodiment of the disclosure.', '; FIG.', '6 is a flow diagram summarizing a method according to one embodiment of the disclosure.', '; FIG. 1 is a functional block diagram of a vibration monitoring apparatus 100 according to one embodiment.', 'The apparatus 100 includes a container 102 that facilitates attachment of the apparatus 100 to a tubular object such as a cylindrical pipe.', 'The container 102 is made of a material that is resistant to high temperatures and hydrocarbon environments, including acids normally encountered in hydrocarbon processing.', 'Plastics such as polypropylene, polyurethane, and polyisocyanate, and mixtures thereof, can be used.', 'The container 102 can be molded or printed.; FIG. 2 is a plan view of the circuitry portion 108 of the apparatus 100.', 'The vibration sensor 106 is a 3-axis vibration sensor located in a central area of the circuitry portion 108.', 'The vibration sensor 106 is for instance a MEMS accelerometer, such as an MPU 9250 accelerometer.', 'The circuitry, including the vibration sensor 106, of the circuitry portion 108 is attached to a circuit board 202 that integrates with the first part 120 of the apparatus 100.', 'The vibration sensor 106 is electrically coupled to a digital microcontroller unit 204.', 'A voltage regulation circuit (not shown) can be included in the circuitry portion to condition power coming from the batteries 136 to the circuitry portion 108 and/or to condition power going from the charging unit 140 to the batteries 136.; FIG.', '3 is a block diagram showing units of the digital microcontroller unit 204.', 'Here, the digital microcontroller unit 204 includes a core module 302, which has a digital processor 304, that generally operates at a high-frequency clock speed, ROM 303, and SRAM memory 305.', 'The digital microcontroller unit 204 contains programming, stored in the ROM 303 and/or the RAM 305, that when executed by the digital processor 304 causes the digital processor to perform certain pre-processing of vibration data.', 'Such pre-processing may include frequency analysis such as Fast Fourier Transform analysis.', 'Any other type of integral transform analysis can be included to target specific frequencies and patterns of vibration.', 'Other processing to amplify, diminish, focus, or defocus known or suspected patterns of vibration, such as noise treatment, frequency filtering and amplification, signal-to-noise optimization, and other treatments can be included in the pre-processing programming.', 'Convolution and deconvolution processing can be included.', 'Pre-processing the vibration data can reduce the volume of data to be transmitted by the vibration monitor 100.', 'It should be noted that the pre-processing is optional, that the vibration monitor 100 may, additionally or instead, transmit raw vibration data.', 'Raw vibration data can be used for troubleshooting and diagnosis of problems with the vibration monitor, or for quality control of the data produced by the vibration monitor.', '; FIG.', '4 is a schematic plan view of a monitoring system 400 according to one embodiment.', 'The monitoring system 400 of FIG.', '4 has a monitoring area 402 and a non-monitoring area 404.', 'The monitoring area 402 has a plurality of operating units 406 connected by fluid conduits 408.', 'A plurality of vibration monitors 100 is coupled to the various operating units 406 and fluid conduits 408 to monitor vibration in all areas of the monitoring system 400.', 'The monitoring area 402 may have environment or atmosphere that is incompatible with operating electronics, but the vibration monitors 100 are all sealed for isolation from the environment to prevent unwanted interaction between the electronics and the environment.', 'A data hub 410 is located in the non-monitoring area 404.', 'The non-monitoring area 404 has an environment that is not incompatible with operating electronics, so the data hub 410 can be safely located and operated in the non-processing area 404.; FIG.', '6 is a flow diagram summarizing a method 600 according to one embodiment.', 'The method 600 is a method of monitoring vibration of a monitored article in a monitoring environment.', 'The monitoring environment may feature an atmosphere with combustible components.', 'At 602, a vibration monitor is enclosed inside an environmental barrier.', 'The vibration monitor includes a chargeable power source, a vibration sensor, a processing unit, and a communication unit.', 'The vibration monitor may also include a storage unit.', 'At 604, the power source is charged wirelessly.', 'For example, the power source may be one or more rechargeable batteries coupled to a wireless charging circuit, such as an inductive charging circuit.', 'The power source, in this case, can be charged by positioning the inductive charging circuit within an inductive field.']

US11905821

Offset well analysis using well trajectory similarity

Aug 15, 2019

Vladimir Zhernakov, Xiaotong Suo, Jose Celaya Galvan, Velizar Vesselinov, Neil Holger White Eklund

Schlumberger Technology Corporation

Elmore, Kimberly, “Euclidean Distance as a Similarity Metric for Principal Component Analysis”, Weather Monthly Review, 2001 (Year: 2001).; Shimodaira, Hiroshi, “Similarity and Recommender Systems”, 2015 (Year: 2015).; Chen, et al. “Noisy logo recognition using line segment hausdorff distance,” Pattern Recognition, 36 (2003), pp. 943-955.; International Search Report and Written Opinion dated Oct. 30, 2020 for international Patent PCT/US2020/041933.; Extended Search Report issued in European Patent Application No. 20852989.1 dated Aug. 11, 2023, 7 pages.

20040210394; October 21, 2004; Trappe; 20060247903; November 2, 2006; Schottle et al.; 20090234623; September 17, 2009; Germain; 20110038527; February 17, 2011; Liu; 20120090834; April 19, 2012; Imhof et al.; 20120261135; October 18, 2012; Nowak; 20160090822; March 31, 2016; Lu; 20180106133; April 19, 2018; Bolchover; 20190003297; January 3, 2019; Brannigan et al.; 20190257189; August 22, 2019; Bang; 20200183042; June 11, 2020; Amidi

2018217679; November 2018; WO; 2019161343; August 2019; WO

['A method for offset well analysis includes receiving offset well data collected from an offset well, the offset well data including data representing a trajectory of an offset well, receiving subject well data comprising a trajectory of at least a portion of a subject well, partitioning the trajectory of the offset well into a plurality of offset well segments, partitioning the trajectory of the subject well into a plurality of subject well segments, determining a distance between at least some of the plurality of offset well segments and at least some of the plurality of subject well segments, selecting the offset well based in part on the distance, and performing an offset well analysis using the offset well and the subject well.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nWhen planning, drilling, or engineering a well, experiential data recorded while drilling and completing other wells is often used to assist in the process.', 'This is often referred to as “offset well analysis” or OWA.', 'In OWA, a data set of drilling parameters, observations, geological characteristics, etc. of offset wells is provided.', 'A driller, planner, etc., may access this data set and identify wells that are likely to include useful information about the risk of various hazards, drilling parameters that were beneficial, and the like, and apply them to the design and drilling of a new well.', 'Thus, OWA may assist users in identifying potential problem areas in the formation and/or the subject well, so that they can be addressed in the planning phase.', 'OWA may also allow a user to identify past events on similar wells that might influence well design, equipment selection and schedule, identify beneficial practices from similar wells that should be continued, provide the information to conduct a risk analysis, establish a baseline measure performance for benchmarking, identify potential constraints and areas of opportunity, and/or validate new well design assumptions\n \nOne challenge in OWA is identifying the wells that are likely to include helpful information, as the data set can contain vast numbers of wells, many of which are dissimilar from the subject well and thus unlikely to be of much assistance.', 'The initial step for OWA is a selection of relevant offset wells with geometrical and geological similarity.', 'Trajectory similarity analysis (geometrical type) in most of the cases is done considering existing wells from within the vicinity of planned well, through search and basic filtering by trajectory type, maximum inclination and hole depth.', 'Accordingly, OWA often resolves to a time-consuming, manual process by which a user searches through and analyzes drilling reports, logs, downhole data, etc. of geographically close wells.', 'SUMMARY\n \nA method for offset well analysis is disclosed.', 'The method includes receiving offset well data collected from an offset well, the offset well data including data representing a trajectory of an offset well, receiving subject well data comprising a trajectory of at least a portion of a subject well, partitioning the trajectory of the offset well into a plurality of offset well segments, partitioning the trajectory of the subject well into a plurality of subject well segments, determining a distance between at least some of the plurality of offset well segments and at least some of the plurality of subject well segments, selecting the offset well based in part on the distance, and performing an offset well analysis using the offset well and the subject well.', 'A computing system is disclosed.', 'The computing system includes one or more processors, and a memory system including one or more non-transitory computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations.', 'The operations include receiving offset well data collected from an offset well, the offset well data including data representing a trajectory of an offset well, receiving subject well data comprising a trajectory of at least a portion of a subject well, partitioning the trajectory of the offset well into a plurality of offset well segments, partitioning the trajectory of the subject well into a plurality of subject well segments, determining a distance between at least some of the plurality of offset well segments and at least some of the plurality of subject well segments, selecting the offset well based in part on the distance, and performing an offset well analysis using the offset well and the subject well.', 'A non-transitory computer-readable media is disclosed.', 'The medium stores instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations.', 'The operations include receiving offset well data collected from an offset well, the offset well data including data representing a trajectory of an offset well, receiving subject well data comprising a trajectory of at least a portion of a subject well, partitioning the trajectory of the offset well into a plurality of offset well segments, partitioning the trajectory of the subject well into a plurality of subject well segments, determining a distance between at least some of the plurality of offset well segments and at least some of the plurality of subject well segments, selecting the offset well based in part on the distance, and performing an offset well analysis using the offset well and the subject well\n \nIt will be appreciated that this summary is intended merely to introduce some aspects of the present methods, systems, and media, which are more fully described and/or claimed below.', 'Accordingly, this summary is not intended to be limiting.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings.', 'In the figures:\n \nFIG.', '1\n illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.\n \nFIG.', '2\n illustrates a flowchart of a method for offset well analysis, according to an embodiment.\n \nFIG.', '3\n illustrates a flowchart of a distance calculation process, according to an embodiment.\n \nFIG.', '4\n illustrates a plot of a subject well and an offset well, according to an embodiment.\n \nFIG.', '5\n illustrates a plot of two segments and a process of calculating one type of “distance” (e.g., a similarity value) therebetween, according to an embodiment.\n \nFIG.', '6\n illustrates a visualization a subject well and several offset wells, according to an embodiment.\n \nFIG.', '7\n illustrates a plot of inclination versus measured depth in a subject well and several similar offset wells, according to an embodiment.\n \nFIG.', '8\n illustrates a schematic view of a computing system, according to an embodiment.', 'DETAILED DESCRIPTION\n \nReference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures.', 'In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention.', 'However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details.', 'In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms are only used to distinguish one element from another.', 'For example, a first object or step could be termed a second object or step, and, similarly, a second object or step could be termed a first object or step, without departing from the scope of the present disclosure.', 'The first object or step, and the second object or step, are both, objects or steps, respectively, but they are not to be considered the same object or step.', 'The terminology used in the description herein is for the purpose of describing particular embodiments and is not intended to be limiting.', 'As used in this description and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will also be understood that the term “and/or” as used herein refers to and encompasses any possible combinations of one or more of the associated listed items.', 'It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.', 'Attention is now directed to processing procedures, methods, techniques, and workflows that are in accordance with some embodiments.', 'Some operations in the processing procedures, methods, techniques, and workflows disclosed herein may be combined and/or the order of some operations may be changed.\n \nFIG.', '1\n illustrates an example of a system \n100\n that includes various management components \n110\n to manage various aspects of a geologic environment \n150\n (e.g., an environment that includes a sedimentary basin, a reservoir \n151\n, one or more faults \n153\n-\n1\n, one or more geobodies \n153\n-\n2\n, etc.).', 'For example, the management components \n110\n may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment \n150\n.', 'In turn, further information about the geologic environment \n150\n may become available as feedback \n160\n (e.g., optionally as input to one or more of the management components \n110\n).', 'In the example of \nFIG.', '1\n, the management components \n110\n include a seismic data component \n112\n, an additional information component \n114\n (e.g., well/logging data), a processing component \n116\n, a simulation component \n120\n, an attribute component \n130\n, an analysis/visualization component \n142\n and a workflow component \n144\n.', 'In operation, seismic data and other information provided per the components \n112\n and \n114\n may be input to the simulation component \n120\n.', 'In an example embodiment, the simulation component \n120\n may rely on entities \n122\n.', 'Entities \n122\n may include earth entities or geological objects such as wells, surfaces, bodies, reservoirs, etc.', 'In the system \n100\n, the entities \n122\n can include virtual representations of actual physical entities that are reconstructed for purposes of simulation.', 'The entities \n122\n may include entities based on data acquired via sensing, observation, etc. (e.g., the seismic data \n112\n and other information \n114\n).', 'An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property).', 'Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.', 'In an example embodiment, the simulation component \n120\n may operate in conjunction with a software framework such as an object-based framework.', 'In such a framework, entities may include entities based on pre-defined classes to facilitate modeling and simulation.', 'A commercially available example of an object-based framework is the MICROSOFT® .NET® framework (Redmond, Washington), which provides a set of extensible object classes.', 'In the .NET® framework, an object class encapsulates a module of reusable code and associated data structures.', 'Object classes can be used to instantiate object instances for use in by a program, script, etc.', 'For example, borehole classes may define objects for representing boreholes based on well data.', 'In the example of \nFIG.', '1\n, the simulation component \n120\n may process information to conform to one or more attributes specified by the attribute component \n130\n, which may include a library of attributes.', 'Such processing may occur prior to input to the simulation component \n120\n (e.g., consider the processing component \n116\n).', 'As an example, the simulation component \n120\n may perform operations on input information based on one or more attributes specified by the attribute component \n130\n.', 'In an example embodiment, the simulation component \n120\n may construct one or more models of the geologic environment \n150\n, which may be relied on to simulate behavior of the geologic environment \n150\n (e.g., responsive to one or more acts, whether natural or artificial).', 'In the example of \nFIG. \n1\n, the analysis/visualization component \n142\n may allow for interaction with a model or model-based results (e.g., simulation results, etc.).', 'As an example, output from the simulation component \n120\n may be input to one or more other workflows, as indicated by a workflow component \n144\n.', 'As an example, the simulation component \n120\n may include one or more features of a simulator such as the ECLIPSE™ reservoir simulator (Schlumberger Limited, Houston Texas), the INTERSECT™ reservoir simulator (Schlumberger Limited, Houston Texas), etc.', 'As an example, a simulation component, a simulator, etc. may include features to implement one or more meshless techniques (e.g., to solve one or more equations, etc.).', 'As an example, a reservoir or reservoirs may be simulated with respect to one or more enhanced recovery techniques (e.g., consider a thermal process such as SAGD, etc.).', 'In an example embodiment, the management components \n110\n may include features of a commercially available framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Texas).', 'The PETREL® framework provides components that allow for optimization of exploration and development operations.', 'The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).', 'In an example embodiment, various aspects of the management components \n110\n may include add-ons or plug-ins that operate according to specifications of a framework environment.', 'For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Texas) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow.', 'The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user-friendly interfaces for efficient development.', 'In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'FIG.', '1\n also shows an example of a framework \n170\n that includes a model simulation layer \n180\n along with a framework services layer \n190\n, a framework core layer \n195\n and a modules layer \n175\n.', 'The framework \n170\n may include the commercially available OCEAN® framework where the model simulation layer \n180\n is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.', 'As an example, a framework may include features for implementing one or more mesh generation techniques.', 'For example, a framework may include an input component for receipt of information from interpretation of seismic data, one or more attributes based at least in part on seismic data, log data, image data, etc.', 'Such a framework may include a mesh generation component that processes input information, optionally in conjunction with other information, to generate a mesh.', 'In the example of \nFIG.', '1\n, the model simulation layer \n180\n may provide domain objects \n182\n, act as a data source \n184\n, provide for rendering \n186\n and provide for various user interfaces \n188\n.', 'Rendering \n186\n may provide a graphical environment in which applications can display their data while the user interfaces \n188\n may provide a common look and feel for application user interface components.', 'As an example, the domain objects \n182\n can include entity objects, property objects and optionally other objects.', 'Entity objects may be used to geometrically represent wells, surfaces, bodies, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters.', 'For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).', 'In the example of \nFIG.', '1\n, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks.', 'The model simulation layer \n180\n may be configured to model projects.', 'As such, a particular project may be stored where stored project information may include inputs, models, results and cases.', 'Thus, upon completion of a modeling session, a user may store a project.', 'At a later time, the project can be accessed and restored using the model simulation layer \n180\n, which can recreate instances of the relevant domain objects.', 'In the example of \nFIG.', '1\n, the geologic environment \n150\n may include layers (e.g., stratification) that include a reservoir \n151\n and one or more other features such as the fault \n153\n-\n1\n, the geobody \n153\n-\n2\n, etc.', 'As an example, the geologic environment \n150\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n152\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n155\n.', 'Such information may include information associated with downhole equipment \n154\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n156\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n155\n that may be configured for communications, noting that the satellite may additionally or instead include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n150\n as optionally including equipment \n157\n and \n158\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n159\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n157\n and/or \n158\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As mentioned, the system \n100\n may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable in the PETRE® software, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, a workflow may be a process implementable in the OCEAN® framework.', 'As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).\n \nFIG.', '2\n illustrates a flowchart of a method \n200\n for offset well analysis, according to an embodiment.', 'The method \n200\n employs the concept of “distance” between two wells.', 'As the term is used herein, “distance” means the difference in shape and/or orientation of two wells, e.g., if they were considered to start at the same location (or shared another point in common), and not the physical, geographical distance between the drilling locations of two wells.', 'The distance calculation is thus a measurement that represents a similarity between two wells.', 'The distance calculation allows for an automatic comparison of the offset wells to a subject well, thereby allowing for an automatic selection of the offset wells with the highest quantitative similarity (e.g., least distance) to be employed in an offset well analysis.', 'As such, the identification of the wells, which was previously a manual process, is done automatically by the application of rules that define the similarity of the offset wells to the subject well.', 'This may lead to the subjective, human-based approach being partially replaced with a more objective, repeatable process, completed at least in part by a computer.', 'For example, the vast number of offset wells may be reduced based on the similarity value, allowing a human user to select from a manageable number of wells for further analysis.', 'This may have various practical applications, including providing a display of the most-similar wells (e.g., shortest distance) and/or leading to changes in a well drilling plan.', 'Further, the selection of the most-appropriate wells may increase the accuracy of the offset well analysis, and thus may lead to refinements in the subject well (e.g., trajectory, drilling parameters, etc.) that may avoid certain drilling risks, increase the rate of penetration, increase efficiency, or otherwise assist in the drilling process that might otherwise not have been realized.', 'Turning to the specific, illustrated embodiment of \nFIG.', '2\n, the method \n200\n includes receiving offset well data, as at \n202\n, and subject well data, as at \n204\n, as input.', 'The offset well data may be data collected while drilling previous wells, whether geographically nearby or not.', 'The offset well data may include various drilling parameters, wellbore trajectory, and may include observations, e.g., in the form of drilling logs, which may be linked to the depth of the offset well.', 'The offset well data thus includes experiential data about wells that were previously drilled, e.g., what worked, what led to hazardous conditions, etc.', 'In contrast, the subject well data may be a well plan for a well that has not yet been drilled or is partially drilled.', 'The subject well data may specify similar characteristics as the offset well data, such as trajectory, drilling parameters, etc.', 'The method \n200\n may then include automatically determining a distance representing the similarity between the trajectory of the offset wells and the subject well, as at \n206\n.', 'The automatic determination at \n206\n may be done by a computer processor, according to a rules-based algorithm for determining distance.', 'To begin, the surface location (or another location) of the offset well and the subject well may be considered to coincide.', 'The calculated distance may be Euclidian.', 'In other embodiments, the distance may be a modified Hausdorff distance, as will be described below.', 'Further, in some embodiments, two or more distances may be calculated, e.g., along all, a portion, or one or more segments of the offset wells and the subject well, and combined to define a composite distance measurement, which may be a straight combination/superposition, an average, a weighted average, or any other type of combination.', 'The method \n200\n may then proceed to selecting one or more of the offset wells based in part on the distance, as at \n208\n.', 'For example, a threshold distance may be established, either predetermined, entered by a user, or otherwise determined, and any offset wells with a calculated distance that is lower than the threshold may be selected.', 'In another embodiment, a number of wells with the lowest distance (highest similarity) may be determined, and then that number selected, e.g., from a ranked list of the offset wells.', 'The selection of offset wells based on the distance may serve to reduce the number of offset wells that a user may choose from to a number that is more manageable to a human, for example, a dozen wells, rather than a thousand.', 'The user may then further select from the wells, e.g., based on other factors and/or subjectively.', 'In some embodiments, the method \n200\n may include displaying a digital model of the selected offset wells and the subject well that visually depicts the similarity/distance, as at \n210\n.', 'Such a digital display may assist in the offset', 'well analysis by allowing for a manual selection of the similar wells, e.g., allowing for a user to discount wells with a similarity that becomes too attenuated.', 'Further, the display may provide the user the ability to make a more subjective comparison of the well trajectories or a comparison of attributes not considered so far in the similarity metric used at the time.', 'For example, some curvatures for a well that have multiple targets may not be considered in the metric but may remain relevant to some users (but not to other users).', 'Thus, the visual display may provide an additional tool to allow a user to make a custom, potentially subjective/qualitative determination, while factoring in the similarity metric.', 'The method \n200\n may then proceed to conducting an offset well analysis using the subject well and the selected offset wells, as at \n212\n.', 'The offset well analysis may be conducted in any suitable manner but may be based on the wells identified as having sufficient similarity at \n210\n.', 'Accordingly, the result of the offset well analysis may inform the well/drilling plan of the subject well.', 'As such, in some embodiments, one or more parameters or characteristics of the subject well may be adjusted, as at \n214\n, as a result of and according to the offset well analysis.', 'For example, drilling parameters (e.g., weight on bit, rotation speed, mud weight, etc.), or geometric parameters (e.g., dog leg severity) may be adjusted based on risks identified in the offset wells, among various other changes that may be made.', 'FIG.', '3\n illustrates a flowchart of the process for determining the distance representing the similarity at \n206\n (hereinafter, “the process \n206\n”), according to an embodiment.', 'The process \n206\n may include partitioning a subject well into a plurality of subject well depth segments based on depth, as at \n300\n.', 'Further, one of the offset wells from the offset well data may be selected, as at \n302\n \nIn some embodiments, the selected offset well may be partitioned into a plurality of segments based on depth, whether in the sense of the physical length of the well from the surface or true vertical depth from the surface, as at \n304\n.', 'These segments may then be compared to determine the distance between the wells.', 'In some embodiments, all segments may be compared.', 'In other embodiments, a depth of interest may be selected, and segments that are contained in that depth of interest may be used, and the others ignored.', 'FIG.', '4\n illustrates a plot of a subject well \n400\n and an offset well \n402\n, illustrating the partitioning discussed above.', 'In particular, as shown, the subject well \n400\n and the offset well \n402\n are considered to originate at the surface (depth value, represented on the vertical axis, is 0) at a common point \n404\n, as the subject and offset wells \n400\n, \n402\n are considered to start at the same point on the surface.', 'The trajectories of the wells \n400\n, \n402\n are divergent as extending downward and along different azimuths (rotated apart, as indicated) and different inclinations.', 'For example, the offset well \n402\n may turn toward the negative x-axis, as will be described in greater detail below.', 'Further, lines \n408\n (four are shown) conceptually demark segments (e.g., segments \n412\n and \n414\n are indicated) of the wells \n400\n, \n402\n.', 'Segments \n412\n, \n414\n representing the same depth interval (e.g., between two of the same lines \n408\n) may be considered to correspond to one another.', 'Referring again to \nFIG.', '3\n, the process \n206\n may proceed to selecting a segment of the offset well and a corresponding segment of the subject well, as at \n308\n.', 'For example, in \nFIG.', '4\n, the segments \n412\n and \n414\n, which are “corresponding” as defined above may be selected.', 'The process \n206\n may then proceed to calculating one or more distances between the corresponding segments of the subject well and the offset well, as at \n310\n.', 'The distance calculation may proceed by calculating the Euclidian distance between the segments (again, either in the depth interval of interest, or along the entire well), which may yield an inclination and azimuth turn rate similarity.', 'Calculating the Euclidian distance may proceed according to the basic distance formula:', 'd\n=√{square root over ((\nx\n2\n−x\n1\n)', '+(\ny\n2\n−y\n1\n))}\u2003\u2003(1) \n where d is the distance, x\n1 \nis the inclination of the subject well, x\n2 \nis the inclination of the offset well, y\n1 \nis the azimuth turn rate of the offset well, and y\n2 \nis the azimuth turn rate of the subject well.', 'It will be appreciated that weighting coefficients could be used to change the relative weight of the azimuth turn rate difference and the inclination difference.', 'The distance calculation may instead or additionally proceed using a modified Hausdorff distance.', 'For example, this may allow for inclination and azimuth similarity and/or shape similarity to be quantified.', 'In either case, three different distance measures are calculated, and then aggregated to arrive at the distance, which provides the similarity value.', 'Further, polar coordinates and measured depth may be used for this calculation.', 'In the case of similarity analysis for a defined interval of interest (rather than the entire well), polar coordinates of the start point of the analysis may be set to zero and the coordinates below may be shifted for the actual value of the starting point.', 'In addition, for calculating the shape similarity, the trajectory (or segment) is applied to evaluate the direction and calculate a distance measure to find a minimum value.', 'Thus, shape similarity provides a search of offset wells with directional similarity, without taking into account exact values of azimuth.\n \nFIG.', '5\n illustrates a basic example of calculating the modified Hausdorff distance, in this case, between two line segments.', 'This calculation may be applied to wellbore trajectories in any one of several ways, e.g., on a segment-by-segment basis, or considering the wellbores as a whole, or in any other manner.', 'Referring to the specific example of \nFIG.', '5\n, a first line segment L\ni \nmay be defined between the points s\nj \nand e\nj\n, and may proceed at an angle θ, in relation to a second line segment L\nj\n, which may extend between points s\ni \nand e\ni\n.', 'The modified Hausdorff distance may be calculated as follows.', 'First, a vertical distance d\n⊥ \nmay be calculated, as follows:\n \n \n \n \n \n \n \n \n \nl\n \n \n⊥\n \n1\n \n \n \n=\n \n \n \n\uf605\n \n \n \ns\n \nj\n \n \n-\n \n \np\n \ns\n \n \n \n\uf606\n \n \n2\n \n \n \n \n \n \n(\n \n2\n \n)\n \n \n \n \n \n \n \n \nl\n \n \n⊥\n \n2\n \n \n \n=\n \n \n \n\uf605\n \n \n \ne\n \nj\n \n \n-\n \n \np\n \ne\n \n \n \n\uf606\n \n \n2\n \n \n \n \n \n \n(\n \n3\n \n)\n \n \n \n \n \n \n \n \n \nd\n \n⊥\n \n \n\u2061\n \n \n(\n \n \n \nL\n \ni\n \n \n,\n \n \nL\n \nj\n \n \n \n)\n \n \n \n=\n \n \n \n \nl\n \n \n⊥\n \n1\n \n \n2\n \n \n+\n \n \nl\n \n \n⊥\n \n2\n \n \n2\n \n \n \n \n \nl\n \n \n⊥\n \n1\n \n \n \n+\n \n \nl\n \n \n⊥\n \n2\n \n \n \n \n \n \n \n \n \n(\n \n4\n \n)', 'Further, a horizontal distance d may be calculated as: \n \nl\n1\n=∥s\nj\n−p\ns\n∥\n2\n\u2003\u2003(5) \n \nl\n2\n=∥p\ne\n−e\nj\n∥\n2\n\u2003\u2003(6) \n \nd\n(\nl\ni\n,l\nj\n)=MIN(\nl\n1\n,l\n2\n)\u2003\u2003(7) \n \n \n \n \n \n \n \n \n \np\n \ns\n \n \n=\n \n \n \ns\n \ni\n \n \n+\n \n \n \nu\n \n1\n \n \n·\n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n \n \n \n \n \n \n(\n \n8\n \n)\n \n \n \n \n \n \n \n \n \np\n \ne\n \n \n=\n \n \n \ns\n \ni\n \n \n+\n \n \n \nu\n \n2\n \n \n·\n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n \n \n \n\u2062\n \n \n \n \n \n\u2062\n \nwhere\n \n \n \n \n \n(\n \n9\n \n)\n \n \n \n \n \n \n \n \nu\n \n1\n \n \n=\n \n \n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ns\n \nj\n \n \n \n→\n \n \n·\n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n \n \n \n\uf605\n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n\uf606\n \n \n2\n \n \n \n \n \n \n \n(\n \n10\n \n)\n \n \n \n \n \n \n \n \n \nu\n \n2\n \n \n=\n \n \n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ns\n \nj\n \n \n \n→\n \n \n·\n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n \n \n \n\uf605\n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n\uf606\n \n \n2\n \n \n \n \n\u2062\n \n \n \n \n \n\u2062\n \nand\n \n \n \n \n \n(\n \n11\n \n)\n \n \n \n \n \n \n \n \ncos\n \n\u2061\n \n \n(\n \nθ\n \n)\n \n \n \n=\n \n \n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n·\n \n \n \n \ns\n \nj\n \n \n\u2062\n \n \ne\n \nj\n \n \n \n→\n \n \n \n \n \n\uf605\n \n \n \n \ns\n \nι\n \n \n\u2062\n \n \ne\n \nι\n \n \n \n→\n \n \n\uf606\n \n \n\u2062\n \n \n\uf605\n \n \n \n \ns\n \nj\n \n \n\u2062\n \n \ne\n \nj\n \n \n \n→\n \n \n\uf606\n \n \n \n \n \n \n \n \n(\n \n12\n \n)\n \n \n \n \n \n \n \n which yields \n \nd\nθ\n(\nL\ni\n,L\nj\n)=∥\nL\nj\n∥×sin(θ)\u2003\u2003(13) \n \nThese three distances, vertical distance d\n⊥\n, horizontal distance d, and angular distance d\nθ\n, may then be combined into an aggregated distance measure which may represent a similarity value between the two segments, e.g., two corresponding segments of the wellbore.', 'The aggregation may proceed using any desired operator, e.g., average, minimum, maximum, etc.\n \nReturning to \nFIG.', '3\n, calculating distances between corresponding segments at \n310\n may be repeated until, as determined at \n312\n, no more segments are available (e.g., at all, or within the depth of interest), or the process \n206\n otherwise determines that no more distance calculations between segments of the offset well and the subject well are called for (e.g., if the distances exceed a certain threshold and it is apparent that the offset well is not sufficiently similar to the subject well so as to warrant continued consideration).', 'In some embodiments, distance between segments may repeat until reaching a distal terminus of the subject well, e.g., in cases where the offset well goes deeper.', 'At this point, the process \n206\n may include determining a similarity value for the offset well based at least in part on the calculated distances between the corresponding segments, as at \n314\n.', 'Because there are multiple segments and potentially multiple different ways to calculate the distance, the similarity value may be a composite of multiple distance values.', 'These values may be combined in any suitable way to arrive at such a composite value, e.g., by total distance, average distance, weighted average, etc.', 'The process \n206\n may then determine whether to consider another offset well from the offset well data set, as at \n316\n.', 'If no further wells are to be considered, the process \n206\n may end, and the method \n200\n may proceed to selecting the offset wells for well analysis at \n208\n (\nFIG.', '2\n).', 'Otherwise, the process \n206\n may loop back to selecting another offset well at \n302\n and iterate through again.', 'As mentioned with reference to box \n210\n of \nFIG.', '2\n, the method \n200\n may include displaying a digital model of one or more of the offset wells (e.g., those selected based on relatively high similarity) and the subject well. \nFIG.', '6\n illustrates an example of a plot of such a visualization \n600\n.', 'In the visualization \n600\n, three offset wells \n602\n, \n604\n, \n606\n are shown, facilitating a comparison between the three offset wells \n602\n, \n604\n, \n606\n and a subject well \n608\n.', 'As mentioned above, such visualizations may enable a user to incorporate additional factors into the comparison of the offset wells.\n \nFIG.', '7\n illustrates a comparison of inclination and measured depth.', 'Here again, this visualization may allow a user to apply a more subjective approach to finding wellbore similarities.', 'For example, the calculated similarity metric may be employed to winnow down the number of possible, similar wellbores, e.g., from thousands to dozens or fewer.', 'Next, the wells or metrics thereof, may be displayed, e.g., as shown in \nFIGS.', '6\n and \n7\n, and may allow a user to factor in other relevant considerations, as discussed above.', 'In some embodiments, the methods of the present disclosure may be executed by a computing system.', 'FIG.', '8\n illustrates an example of such a computing system \n800\n, in accordance with some embodiments.', 'The computing system \n800\n may include a computer or computer system \n801\nA, which may be an individual computer system \n801\nA or an arrangement of distributed computer systems.', 'The computer system \n801\nA includes one or more analysis modules \n802\n that are configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein.', 'To perform these various tasks, the analysis module \n602\n executes independently, or in coordination with, one or more processors \n804\n, which is (or are) connected to one or more storage media \n806\n.', 'The processor(s) \n804\n is (or are) also connected to a network interface \n808\n to allow the computer system \n801\nA to communicate over a data network \n809\n with one or more additional computer systems and/or computing systems, such as \n801\nB, \n801\nC, and/or \n801\nD (note that computer systems \n801\nB, \n801\nC and/or \n801\nD may or may not share the same architecture as computer system \n801\nA, and may be located in different physical locations, e.g., computer systems \n801\nA and \n801\nB may be located in a processing facility, while in communication with one or more computer systems such as \n801\nC and/or \n801\nD that are located in one or more data centers, and/or located in varying countries on different continents).', 'A processor may include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'The storage media \n806\n may be implemented as one or more computer-readable or machine-readable storage media.', 'Note that while in the example embodiment of \nFIG.', '8\n storage media \n806\n is depicted as within computer system \n801\nA in some embodiments, storage media \n806\n may be distributed within and/or across multiple internal and/or external enclosures of computing system \n801\nA and/or additional computing systems.', 'Storage media \n806\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY® disks, or other types of optical storage, or other types of storage devices.', 'Note that the instructions discussed above may be provided on one computer-readable or machine-readable storage medium, or may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture).', 'An article or article of manufacture may refer to any manufactured single component or multiple components.', 'The storage medium or media may be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In some embodiments, computing system \n800\n contains one or more offset well selection module(s) \n808\n.', 'In the example of computing system \n800\n, computer system \n801\nA includes the offset well selection module \n808\n.', 'In some embodiments, a single offset well selection module may be used to perform some aspects of one or more embodiments of the methods disclosed herein.', 'In other embodiments, a plurality of offset well selection modules may be used to perform some aspects of methods herein.', 'It should be appreciated that computing system \n800\n is merely one example of a computing system, and that computing system \n800\n may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of \nFIG.', '8\n, and/or computing system \n800\n may have a different configuration or arrangement of the components depicted in \nFIG. \n8\n.', 'The various components shown in \nFIG.', '8\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices.', 'These modules, combinations of these modules, and/or their combination with general hardware are included within the scope of the present disclosure.', 'Computational interpretations, models, and/or other interpretation aids may be refined in an iterative fashion; this concept is applicable to the methods discussed herein.', 'This may include use of feedback loops executed on an algorithmic basis, such as at a computing device (e.g., computing system \n800\n, \nFIG. \n8\n), and/or through manual control by a user who may make determinations regarding whether a given step, action, template, model, or set of curves has become sufficiently accurate for the evaluation of the subsurface three-dimensional geologic formation under consideration.', 'The foregoing description, for purpose of explanation, has been described with reference to specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or limiting to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'Moreover, the order in which the elements of the methods described herein are illustrate and described may be re-arranged, and/or two or more elements may occur simultaneously.', 'The embodiments were chosen and described in order to best explain the principals of the disclosure and its practical applications, to thereby enable others skilled in the art to best utilize the disclosed embodiments and various embodiments with various modifications as are suited to the particular use contemplated.']

['1.', 'A method for offset well analysis, comprising:\nreceiving offset well data collected from a plurality of existing offset wells, wherein the offset well data comprises experiential data regarding past events on the plurality of existing offset wells, and wherein the offset well data comprises data representing a trajectory of each existing offset well of the plurality of existing offset wells;\nreceiving subject well data comprising a trajectory of at least a portion of a potential subject well;\npartitioning the trajectory of each existing offset well of the plurality of existing offset wells into a plurality of offset well segments;\npartitioning the trajectory of the potential subject well into a plurality of subject well segments;\ndetermining a distance between at least some of the plurality of offset well segments of each existing offset well of the plurality of existing offset wells and at least some of the plurality of subject well segments, wherein a surface location of a top of each existing offset well of the plurality of existing offset wells and a surface location of a top of the potential subject well are considered to be the same, wherein determining the distance comprises determining a plurality of distances between corresponding segments of the plurality of offset well segments and the plurality of subject well segments, wherein determining the distance comprises combining the plurality of distances, and wherein the distance comprises one of: a total of the plurality of distances, an average of the plurality of distances, or a weighted average of the plurality of distances;\nselecting an existing offset well from among the plurality of existing offset wells based in part on the distance;\nperforming an offset well analysis using the existing offset', 'well and the potential subject well; and\nadjusting the trajectory of the potential subject well, or one or more drilling parameters for the potential subject well, or both based at least in part on the offset well analysis.', '2.', 'The method of claim 1, wherein determining the distance comprises calculating a Euclidean distance between an inclination and an azimuth turn rate of one of the plurality of subject well segments and one of the plurality of offset well segments.', '3.', 'The method of claim 1, wherein determining the distance comprises calculating a modified Hausdorff distance between a first segment of the plurality of subject well segments and a second segment of the plurality of offset well segments, the first and second segments having corresponding depths.', '4.', 'The method of claim 1, further comprising determining a depth interval of interest, wherein the at least some of the plurality of subject well segments and the at least some of the plurality of offset well segments are defined in the depth interval of interest.', '5.', 'The method of claim 1, further comprising:\nreceiving a set of rules defining a similarity between the existing offset', 'well and the potential subject well, wherein determining the distance comprises applying the set of rules to the existing offset', 'well and the potential subject well to quantify the similarity therebetween.', '6.', 'A computing system, comprising:\none or more processors; and\na memory system comprising one or more non-transitory computer-readable media storing instructions that, when executed by at least one of the one or more processors, cause the computing system to perform operations, the operations comprising: receiving offset well data collected from a plurality of existing offset wells, wherein the offset well data comprises experiential data regarding past events on the plurality of existing offset wells, and wherein the offset well data comprises data representing a trajectory of each existing offset well of the plurality of existing offset wells; receiving subject well data comprising a trajectory of at least a portion of a potential subject well; partitioning the trajectory of each existing offset well of the plurality of existing offset wells into a plurality of offset well segments; partitioning the trajectory of the potential subject well into a plurality of subject well segments; determining a distance between at least some of the plurality of offset well segments of each existing offset well of the plurality of existing offset wells and at least some of the plurality of subject well segments, wherein a starting surface location of each existing offset well of the plurality of existing offset wells and a starting surface location of the potential subject well are considered to be the same, wherein determining the distance comprises determining a plurality of distances between corresponding segments of the plurality of offset well segments and the plurality of subject well segments, wherein determining the distance comprises combining the plurality of distances, and wherein the distance comprises one of: a total of the plurality of distances, an average of the plurality of distances, or a weighted average of the plurality of distances; selecting an existing offset well from among the plurality of existing offset wells based in part on the distance; performing an offset well analysis using the existing offset', 'well and the potential subject well; and adjusting the trajectory of the potential subject well, or one or more drilling parameters for the potential subject well, or both based at least in part on the offset well analysis.', '7.', 'The computing system of claim 6, wherein determining the distance comprises determining the distance between corresponding segments of the plurality of offset well segments and the plurality of subject well segments, and wherein a surface location of the offset well and the potential subject well are considered to be the same.', '8.', 'The computing system of claim 6, wherein the operations further comprise determining a depth interval of interest, wherein the at least some of the plurality of subject well segments and the at least some of the plurality of offset well segments are defined in the depth interval of interest.', '9.', 'The computing system of claim 6, wherein the operations further comprise:\nreceiving a set of rules defining a similarity between the existing offset', 'well and the potential subject well, wherein determining the distance comprises applying the set of rules to the existing offset', 'well and the potential subject well to quantify the similarity therebetween.', '10.', 'The computing system of claim 6, further comprising displaying a visualization of the existing offset', 'well and the potential subject well representing the distance therebetween.', '11.', 'The computing system of claim 10, wherein the operations further comprise:\ndetermining a set of potentially relevant offset wells based on the distance; and\nselecting one or more of the set of the potentially relevant offset wells based on the visualization, wherein selecting the offset well comprises selecting from the one or more of the potentially relevant wells.', '12.', 'A non-transitory computer-readable medium storing instructions that, when executed by one or more processors of a computing system, cause the computing system to perform operations, the operations comprising:\nreceiving offset well data collected from a plurality of existing offset wells, wherein the offset well data comprises experiential data regarding past events on the plurality of existing offset wells, and wherein the offset well data comprises data representing a trajectory of each existing offset well of the plurality of existing offset wells;\nreceiving subject well data comprising a trajectory of at least a portion of a potential subject well;\npartitioning the trajectory of each existing offset well of the plurality of existing offset wells into a plurality of offset well segments;\npartitioning the trajectory of the potential subject well into a plurality of subject well segments;\ndetermining a distance between at least some of the plurality of offset well segments of each existing offset well of the plurality of existing offset wells and at least some of the plurality of subject well segments, wherein determining the distance comprises determining the distance between corresponding segments of the plurality of offset well segments and the plurality of subject well segments, and wherein a surface location of a top of each existing offset well of the plurality of existing offset wells and a location of a top of the potential subject well are considered to be the same for purposes of determining the distance, the distance representing a similarity of the trajectory of the at least some of the plurality of offset well segments of each existing offset well of the plurality of existing offset wells and the trajectory of the at least some of the plurality of subject well segments of the potential subject well, wherein determining the distance comprises determining a plurality of distances between corresponding segments of the plurality of offset well segments and the plurality of subject well segments, wherein determining the distance comprises combining the plurality of distances, and wherein the distance comprises one of: a total of the plurality of distances, an average of the plurality of distances, or a weighted average of the plurality of distances;\nselecting an existing offset well from among the plurality of existing offset wells based in part on the distance;\nperforming an offset well analysis using the existing offset', 'well and the potential subject well; and\nadjusting the trajectory of the potential subject well, or one or more drilling parameters for the potential subject well, or both based at least in part on the offset well analysis.', '13.', 'The non-transitory, computer-readable medium of claim 12, wherein determining the distance comprises calculating a modified Hausdorff distance between a first segment of the plurality of subject well segments and a second segment of the plurality of offset well segments, the first and second segments having corresponding depths.']

['FIG. 1 illustrates an example of a system that includes various management components to manage various aspects of a geologic environment, according to an embodiment.; FIG.', '2 illustrates a flowchart of a method for offset well analysis, according to an embodiment.; FIG.', '3 illustrates a flowchart of a distance calculation process, according to an embodiment.; FIG.', '4 illustrates a plot of a subject well and an offset well, according to an embodiment.; FIG.', '5 illustrates a plot of two segments and a process of calculating one type of “distance” (e.g., a similarity value) therebetween, according to an embodiment.; FIG.', '6 illustrates a visualization a subject well and several offset wells, according to an embodiment.; FIG.', '7 illustrates a plot of inclination versus measured depth in a subject well and several similar offset wells, according to an embodiment.; FIG.', '8 illustrates a schematic view of a computing system, according to an embodiment.; FIG.', '1 illustrates an example of a system 100 that includes various management components 110 to manage various aspects of a geologic environment 150 (e.g., an environment that includes a sedimentary basin, a reservoir 151, one or more faults 153-1, one or more geobodies 153-2, etc.).', 'For example, the management components 110 may allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 150.', 'In turn, further information about the geologic environment 150 may become available as feedback 160 (e.g., optionally as input to one or more of the management components 110).; FIG.', '1 also shows an example of a framework 170 that includes a model simulation layer 180 along with a framework services layer 190, a framework core layer 195 and a modules layer 175.', 'The framework 170 may include the commercially available OCEAN® framework where the model simulation layer 180 is the commercially available PETREL® model-centric software package that hosts OCEAN® framework applications.', 'In an example embodiment, the PETREL® software may be considered a data-driven application.', 'The PETREL® software can include a framework for model building and visualization.; FIG. 1 also shows the geologic environment 150 as optionally including equipment 157 and 158 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 159.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop a laterally extensive reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 157 and/or 158 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG.', '2 illustrates a flowchart of a method 200 for offset well analysis, according to an embodiment.', 'The method 200 employs the concept of “distance” between two wells.', 'As the term is used herein, “distance” means the difference in shape and/or orientation of two wells, e.g., if they were considered to start at the same location (or shared another point in common), and not the physical, geographical distance between the drilling locations of two wells.', 'The distance calculation is thus a measurement that represents a similarity between two wells.; FIG.', '3 illustrates a flowchart of the process for determining the distance representing the similarity at 206 (hereinafter, “the process 206”), according to an embodiment.', 'The process 206 may include partitioning a subject well into a plurality of subject well depth segments based on depth, as at 300.', 'Further, one of the offset wells from the offset well data may be selected, as at 302; FIG.', '4 illustrates a plot of a subject well 400 and an offset well 402, illustrating the partitioning discussed above.', 'In particular, as shown, the subject well 400 and the offset well 402 are considered to originate at the surface (depth value, represented on the vertical axis, is 0) at a common point 404, as the subject and offset wells 400, 402 are considered to start at the same point on the surface.', 'The trajectories of the wells 400, 402 are divergent as extending downward and along different azimuths (rotated apart, as indicated) and different inclinations.', 'For example, the offset well 402 may turn toward the negative x-axis, as will be described in greater detail below.', 'Further, lines 408 (four are shown) conceptually demark segments (e.g., segments 412 and 414 are indicated) of the wells 400, 402.', 'Segments 412, 414 representing the same depth interval (e.g., between two of the same lines 408) may be considered to correspond to one another.; FIG. 5 illustrates a basic example of calculating the modified Hausdorff distance, in this case, between two line segments.', 'This calculation may be applied to wellbore trajectories in any one of several ways, e.g., on a segment-by-segment basis, or considering the wellbores as a whole, or in any other manner.', 'Referring to the specific example of FIG.', '5, a first line segment Li may be defined between the points sj and ej, and may proceed at an angle θ, in relation to a second line segment Lj, which may extend between points si and ei.; FIG.', '7 illustrates a comparison of inclination and measured depth.', 'Here again, this visualization may allow a user to apply a more subjective approach to finding wellbore similarities.', 'For example, the calculated similarity metric may be employed to winnow down the number of possible, similar wellbores, e.g., from thousands to dozens or fewer.', 'Next, the wells or metrics thereof, may be displayed, e.g., as shown in FIGS.', '6 and 7, and may allow a user to factor in other relevant considerations, as discussed above.']

US11892579

Crosswell microseismic system

Sep 30, 2016

Leah Hogarth, Joel Herve Le Calvez, Herve Denaclara

SCHLUMBERGER TECHNOLOGY CORPORATION

Ajayi, et al., “Using Microseismic Monitoring as a Real Time Completions Diagnostic Tool in Unconventional Reservoirs: Field Case Studies,” SPE Eastern Regional Meeting, 2011.; Cipolla, et al., “A Practical Guide to Interpreting Microseismic Measurements,” Society of Petroleum Engineers 2011.; Daniels, et al., “Contacting more of the Barnett Shale through an integration of real-time microseismic monitoring, petrophysics and hydraulic fracture design,” SPE Annual Technical Conference and Exhibition 2007 Anaheim, SPE 110562.; Eisner, et al., “Borehole deviation surveys are necessary for hydraulic fracture monitoring,” 76th Annual International Meeting, 2006, SEG Expanded Abstracts, pp. 359-362.; Erwemi, et al., “Anisotropic velocity modeling for microseismic processing, Part 3: Borehole sonic calibration case study,” SEG Annual Meeting 2010, Expanded Abstract.; Jocker, et al., “Seismic Anisotropy Characterization in Heterogeneous Formations Using Borehole Sonic Data,” SPE Annual Technical Conference and Exhibition 2013.; Jones, et al., “Microseismic event location accuracy improvement from the use of anisotropic velocity models,” GeoCanada 2010 Abstract.; Le Calvez, et al, “Real-time microseismic monitoring of hydraulic fracture treatment: a tool to improve completion and reservoir managements,” SPE Hydraulic Fracturing Technology Conference 2007 College Station, SPE 106159.; Le Calvez, et al., “Hydraulic Fracturing Insights from Microseismic Monitoring,” Oilfield Review, 2016, 28(2).; Le Calvez, et al., “Tool and velocity model calibration for downhole-based hydraulic fracture monitoring of induced microseismicity,” 83rd Annual Meeting, 2013, SEG, Expanded Abstracts.; Leiceaga, eta l., “Crosswell seismic applications for improved reservoir understanding,” The Leading Edge 2015, vol. 34, pp. 422-428.; Maxwell, “Microseismic: Growth born of success,” The Leading Edge, 2010, vol. 29, No. 3, pp. 338-343.; Maxwell, et al., “Anisotropic Velocity Modeling for Microseismic Processing, Part I—Impact of Velocity model uncertainty,” presented at the 80th Annual International Meeting, 2010, SEG, Expanded Abstracts.; Thomsen, “Weak elastic anisotropy,” Geophysics 1986, vol. 51, pp. 1954-1966.; Waters, et al., “Use of Horizontal Well Image Tools to Optimize Barnett Shale,” In Proceedings of Reservoir Exploitation, SPE Annual Technical Conference and Exhibition, San Antonio, Texas, USA, Sep. 24-27, 2006.; Woerpel, “Anisotropic velocity modeling for microseismic processing: Part 2—Fast and accurate model calibration with a cross-well source,” SEG Annual Meeting 2010, Expanded Abstract.; Zakhour, et al., “Real-Time Use of Microseismic Monitoring for Horizontal Completion Optimization Across a Major Fault in the Eagle Ford Formation,” SPE Hydraulic Fracturing Technology Conference 2015, Woodlands, Texas, SPE-173353.; Extended Search Report for the equivalent European patent application 17193923.4 dated Feb. 12, 2018.; Zhang, et al., “Velocity modeling and inversion techniques for locating microseismic events in unconventional reservoirs,” Journal of Earth Science, China University of Geosciences, Heidelberg, vol. 26, No. 4, Jul. 25, 2015, pp. 495-501.; Yaskevich, et al., “Processing microseismic monitoring data, considering seismic anisotropy of rocks,” Journal of Mining Science, SP Maik Nauka/Interperiodica, Dordrecht, vol. 51, No. 3, Jan. 13, 2016, pp. 477-486.; Neuhaus, et al., “Utilization of Anisotropic Velocity Models in Surface Microseismic Monitoring to Improve Hydraulic Fracturing Event Location Accuracy in Shale Plays,” SPE Canadian Unconventional Resources Conference, Nov. 1, 2012, pp. 1-7.; Communication Pursuant to Article 94(3) issued in European Patent Application 17193923.4 dated Jul. 28, 2021, 7 pages.; Craig Woerpel., Anisotropic velocity modeling for microseismic processing: Part 2—Fast and accurate model calibration with a cross-well source, SEG Technical Program Expanded Abstracts 2010, Jan. 1, 2010, pp. 2135-2139.

6462672; October 8, 2002; Besson; 6891477; May 10, 2005; Aronstam; 20040093163; May 13, 2004; Reshef; 20050280419; December 22, 2005; Chen; 20060023567; February 2, 2006; Uhl; 20080159075; July 3, 2008; Underhill; 20080316860; December 25, 2008; Muyzert; 20090010104; January 8, 2009; Leaney; 20100195436; August 5, 2010; Kamata; 20120051178; March 1, 2012; Zhang et al.; 20130128693; May 23, 2013; Geiser; 20130235693; September 12, 2013; Ball; 20130245953; September 19, 2013; Gonzales; 20140119159; May 1, 2014; Le Calvez; 20150330211; November 19, 2015; Kabatek; 20160299246; October 13, 2016; Minto

WO-2014105086; July 2014; WO; WO 2014205162; December 2014; WO; 2015187136; December 2015; WO

['A method can include receiving seismic data responsive to stimulation of an anisotropic formation via a well disposed in the formation; receiving crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locating a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and rendering the located microseismic event to a display with respect to one or more dimensions of the anisotropic formation.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nReflection seismology finds use in geophysics, for example, to estimate properties of subsurface formations.', 'As an example, reflection seismology may provide seismic data representing waves of elastic energy (e.g., as transmitted by P-waves and S-waves, in a frequency range of approximately 1 Hz to approximately 100 Hz).', 'Seismic data may be processed and interpreted, for example, to understand better composition, fluid content, extent and geometry of subsurface rocks.', 'SUMMARY', 'In accordance with some embodiments, a method includes receiving seismic data responsive to stimulation of an anisotropic formation via a well disposed in the formation; receiving crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locating a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and rendering the located microseismic event to a display with respect to one or more dimensions of the anisotropic formation.', 'In accordance with some embodiments, a system includes a processor; memory accessible by the processor; processor-executable instructions stored in the memory that include instructions to instruct the system to: receive seismic data responsive to stimulation of an anisotropic formation via a well disposed in the anisotropic formation; receive crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locate a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and render the located microseismic event to a display with respect to one or more dimensions of the formation.', 'In accordance with some embodiments, one or more computer-readable storage media include computer-executable instructions to instruct a system to: receive seismic data responsive to stimulation of an anisotropic formation via a well disposed in the formation; receive crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locate a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and render the located microseismic event to a display with respect to one or more dimensions of the anisotropic formation.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFeatures and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.\n \nFIG.', '1\n illustrates an example of a geologic environment and an example of a technique;\n \nFIG.', '2\n illustrates examples of multiple reflections and examples of techniques;\n \nFIG.', '3\n illustrates examples of survey techniques;\n \nFIG.', '4\n illustrates an example of a portion of a method;\n \nFIG.', '5\n illustrates an example of a portion of the method of \nFIG.', '4\n;\n \nFIG.', '6\n illustrates examples of techniques and equipment associated with microseismicity;\n \nFIG.', '7\n illustrates an example of a method, an example of a model and an example of a system;\n \nFIG.', '8\n illustrates examples of plots;\n \nFIG.', '9\n illustrates an example of a plot;\n \nFIG.', '10\n illustrates examples of plots;\n \nFIG.', '11\n illustrates an example of a method; and\n \nFIG.', '12\n illustrates example components of a system and a networked system.', 'DETAILED DESCRIPTION', 'The following description includes the best mode presently contemplated for practicing the described implementations.', 'This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.', 'As mentioned, reflection seismology finds use in geophysics, for example, to estimate properties of subsurface formations.', 'As an example, reflection seismology may provide seismic data representing waves of elastic energy (e.g., as transmitted by P-waves and S-waves, in a frequency range of approximately 1 Hz to approximately 100 Hz or optionally less than 1 Hz and/or optionally more than 100 Hz).', 'Seismic data may be processed and interpreted, for example, to understand better composition, fluid content, extent and geometry of subsurface rocks.', 'FIG.', '1\n shows an example of a geologic environment \n100\n (e.g., an environment that includes a sedimentary basin, a reservoir \n101\n, a fault \n103\n, one or more fractures \n109\n, etc.)', 'and an example of an acquisition technique \n140\n to acquire seismic data.', 'As an example, a system may process data acquired by the technique \n140\n, for example, to allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment \n100\n.', 'In turn, further information about the geologic environment \n100\n may become available as feedback (e.g., optionally as input to the system).', 'As an example, an operation may pertain to a reservoir that exists in the geologic environment \n100\n such as, for example, the reservoir \n101\n.', 'As an example, a technique may provide information (e.g., as an output) that may specifies one or more location coordinate of a feature in a geologic environment, one or more characteristics of a feature in a geologic environment, etc.\n \nAs an example, a system may include features of a commercially available simulation framework such as the PETREL® seismic to simulation software framework (Schlumberger Limited, Houston, Texas).', 'The PETREL® framework provides components that allow for optimization of exploration and development operations.', 'The PETREL® framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, and reservoir engineers) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of simulating a geologic environment, decision making, operational control, etc.).', 'As an example, a system may include add-ons or plug-ins that operate according to specifications of a framework environment.', 'For example, a commercially available framework environment marketed as the OCEAN® framework environment (Schlumberger Limited, Houston, Texas) allows for integration of add-ons (or plug-ins) into a PETREL® framework workflow.', 'The OCEAN® framework environment leverages .NET® tools (Microsoft Corporation, Redmond, Washington) and offers stable, user-friendly interfaces for efficient development.', 'In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'In the example of \nFIG.', '1\n, the geologic environment \n100\n may include layers (e.g., stratification) that include the reservoir \n101\n and that may be intersected by a fault \n103\n (see also, e.g., the one or more fractures \n109\n, which may intersect a reservoir).', 'As an example, a geologic environment may be or include an offshore geologic environment, a seabed geologic environment, an ocean bed geologic environment, etc.', 'As an example, the geologic environment \n100\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n102\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n105\n.', 'Such information may include information associated with downhole equipment \n104\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n106\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n105\n that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n100\n as optionally including equipment \n107\n and \n108\n associated with a well that includes a substantially horizontal portion that may intersect with one or more of the one or more fractures \n109\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n107\n and/or \n108\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.', 'As an example, a system may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a system may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable in the PETREL® software, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, a workflow may be a process implementable in the OCEAN® framework.', 'As an example, a workflow may include one or more worksteps that access a module such as a plug-in (e.g., external executable code, etc.).', 'As an example, a workflow may include rendering information to a display (e.g., a display device).', 'As an example, a workflow may include receiving instructions to interact with rendered information, for example, to process information and optionally render processed information.', 'As an example, a workflow may include transmitting information that may control, adjust, initiate, etc. one or more operations of equipment associated with a geologic environment (e.g., in the environment, above the environment, etc.).', 'In \nFIG.', '1\n, the technique \n140\n may be implemented with respect to a geologic environment \n141\n.', 'As shown, an energy source (e.g., a transmitter) \n142\n may emit energy where the energy travels as waves that interact with the geologic environment \n141\n.', 'As an example, the geologic environment \n141\n may include a bore \n143\n where one or more sensors (e.g., receivers) \n144\n may be positioned in the bore \n143\n.', 'As an example, energy emitted by the energy source \n142\n may interact with a layer (e.g., a structure, an interface, etc.) \n145\n in the geologic environment \n141\n such that a portion of the energy is reflected, which may then be sensed by one or more of the sensors \n144\n.', 'Such energy may be reflected as an upgoing primary wave (e.g., or “primary” or “singly” reflected wave).', 'As an example, a portion of emitted energy may be reflected by more than one structure in the geologic environment and referred to as a multiple reflected wave (e.g., or “multiple”).', 'For example, the geologic environment \n141\n is shown as including a layer \n147\n that resides below a surface layer \n149\n.', 'Given such an environment and arrangement of the source \n142\n and the one or more sensors \n144\n, energy may be sensed as being associated with particular types of waves.', 'As an example, a “multiple” may refer to multiply reflected seismic energy or, for example, an event in seismic data that has incurred more than one reflection in its travel path.', 'As an example, depending on a time delay from a primary event with which a multiple may be associated, a multiple may be characterized as a short-path or a peg-leg, for example, which may imply that a multiple may interfere with a primary reflection, or long-path, for example, where a multiple may appear as a separate event.', 'As an example, seismic data may include evidence of an interbed multiple from bed interfaces (see also, e.g., \nFIG. \n2\n), evidence of a multiple from a water interface (e.g., an interface of a base of water and rock or sediment beneath it) or evidence of a multiple from an air-water interface, etc.', 'As shown in \nFIG.', '1\n, acquired data \n160\n can include data associated with downgoing direct arrival waves, reflected upgoing primary waves, downgoing multiple reflected waves and reflected upgoing multiple reflected waves.', 'The acquired data \n160\n is also shown along a time axis and a depth axis.', 'As indicated, in a manner dependent at least in part on characteristics of media in the geologic environment \n141\n, waves travel at velocities over distances such that relationships may exist between time and space.', 'Thus, time information, as associated with sensed energy, may allow for understanding spatial relations of layers, interfaces, structures, etc. in a geologic environment.\n \nFIG.', '1\n also shows various types of waves as including P, SV an SH waves.', 'As an example, a P-wave may be an elastic body wave or sound wave in which particles oscillate in the direction the wave propagates.', 'As an example, P-waves incident on an interface (e.g., at other than normal incidence, etc.) may produce reflected and transmitted S-waves (e.g., “converted” waves).', 'As an example, an S-wave or shear wave may be an elastic body wave, for example, in which particles oscillate perpendicular to the direction in which the wave propagates.', 'S-waves may be generated by a seismic energy sources (e.g., other than an air gun).', 'As an example, S-waves may be converted to P-waves.', 'S-waves tend to travel more slowly than P-waves and do not travel through fluids that do not support shear.', 'In general, recording of S-waves involves use of one or more receivers operatively coupled to earth (e.g., capable of receiving shear forces with respect to time).', "As an example, interpretation of S-waves may allow for determination of rock properties such as fracture density and orientation, Poisson's ratio and rock type, for example, by crossplotting P-wave and S-wave velocities, and/or by other techniques.", 'As an example of parameters that may characterize anisotropy of media (e.g., seismic anisotropy), consider the Thomsen parameters ε, δ and γ.', 'The Thomsen parameter δ describes depth mismatch between logs (e.g., actual depth) and seismic depth.', 'As to the Thomsen parameter ε, it describes a difference between vertical and horizontal compressional waves (e.g., P or P-wave or quasi compressional wave qP or qP-wave).', 'As to the Thomsen parameter γ, it describes a difference between horizontally polarized and vertically polarized shear waves (e.g., horizontal shear wave SH or SH-wave and vertical shear wave SV or SV-wave or quasi vertical shear wave qSV or qSV-wave).', 'Thus, the Thomsen parameters ε and γ may be estimated from wave data while estimation of the Thomsen parameter δ may involve access to additional information.', 'As an example, seismic data may be acquired for a region in the form of traces.', 'In the example of \nFIG. \n1\n, the technique \n140\n may include the source \n142\n for emitting energy where portions of such energy (e.g., directly and/or reflected) may be received via the one or more sensors \n144\n.', 'As an example, energy received may be discretized by an analog-to-digital converter that operates at a sampling rate.', 'For example, acquisition equipment may convert energy signals sensed by a sensor to digital samples at a rate of one sample per approximately 4 ms.', 'Given a speed of sound in a medium or media, a sample rate may be converted to an approximate distance.', 'For example, the speed of sound in rock may be of the order of around 5 km per second.', 'Thus, a sample time spacing of approximately 4 ms would correspond to a sample “depth” spacing of about 10 meters (e.g., assuming a path length from source to boundary and boundary to sensor).', 'As an example, a trace may be about 4 seconds in duration; thus, for a sampling rate of one sample at about 4 ms intervals, such a trace would include about 1000 samples where latter acquired samples correspond to deeper reflection boundaries.', 'If the 4 second trace duration of the foregoing example is divided by two (e.g., to account for reflection), for a vertically aligned source and sensor, the deepest boundary depth may be estimated to be about 10 km (e.g., assuming a speed of sound of about 5 km per second).', 'FIG.', '2\n shows an example of a technique \n240\n, examples of signals \n262\n associated with the technique \n240\n, examples of interbed multiple reflections \n250\n and examples of signals \n264\n and data \n266\n associated with the interbed multiple reflections \n250\n.', 'As an example, the technique \n240\n may include emitting energy with respect to time where the energy may be represented in a frequency domain, for example, as a band of frequencies.', 'In such an example, the emitted energy may be a wavelet and, for example, referred to as a source wavelet which has a corresponding frequency spectrum (e.g., per a Fourier transform of the wavelet).', 'As an example, a geologic environment may include layers \n241\n-\n1\n, \n241\n-\n2\n and \n241\n-\n3\n where an interface \n245\n-\n1\n exists between the layers \n241\n-\n1\n and \n241\n-\n2\n and where an interface \n245\n-\n2\n exists between the layers \n241\n-\n2\n and \n241\n-\n3\n.', 'As illustrated in \nFIG.', '2\n, a wavelet may be first transmitted downward in the layer \n241\n-\n1\n; be, in part, reflected upward by the interface \n245\n-\n1\n and transmitted upward in the layer \n241\n-\n1\n; be, in part, transmitted through the interface \n245\n-\n1\n and transmitted downward in the layer \n241\n-\n2\n; be, in part, reflected upward by the interface \n245\n-\n2\n (see, e.g., “i”) and transmitted upward in the layer \n241\n-\n2\n; and be, in part, transmitted through the interface \n245\n-\n1\n (see, e.g., “ii”) and again transmitted in the layer \n241\n-\n1\n.', 'In such an example, signals (see, e.g., the signals \n262\n) may be received as a result of wavelet reflection from the interface \n245\n-\n1\n and as a result of wavelet reflection from the interface \n245\n-\n2\n.', 'These signals may be shifted in time and in polarity such that addition of these signals results in a waveform that may be analyzed to derive some information as to one or more characteristics of the layer \n241\n-\n2\n (e.g., and/or one or more of the interfaces \n245\n-\n1\n and \n245\n-\n2\n).', 'For example, a Fourier transform of signals may provide information in a frequency domain that can be used to estimate a temporal thickness (e.g., Δzt) of the layer \n241\n-\n2\n (e.g., as related to acoustic impedance, reflectivity, etc.).', 'As to the data \n266\n, they illustrate further transmissions of emitted energy, including transmissions associated with the interbed multiple reflections \n250\n.', 'For example, while the technique \n240\n is illustrated with respect to interface related events i and ii, the data \n266\n further account for additional interface related events, denoted iii, that stem from the event ii.', 'Specifically, as shown in \nFIG.', '2\n, energy is reflected downward by the interface \n245\n-\n1\n where a portion of that energy is transmitted through the interface \n245\n-\n2\n as an interbed downgoing multiple and where another portion of that energy is reflected upward by the interface \n245\n-\n2\n as an interbed upgoing multiple.', 'These portions of energy may be received by one or more receivers \n244\n (e.g., disposed in a well \n243\n) as signals.', 'These signals may be summed with other signals, for example, as explained with respect to the technique \n240\n.', 'For example, such interbed multiple signals may be received by one or more receivers over a period of time in a manner that acts to “sum” their amplitudes with amplitudes of other signals (see, e.g., illustration of signals \n262\n where interbed multiple signals are represented by a question mark “?”).', 'In such an example, the additional interbed signals may interfere with an analysis that aims to determine one or more characteristics of the layer \n241\n-\n2\n (e.g., and/or one or more of the interfaces \n245\n-\n1\n and \n245\n-\n2\n).', 'For example, interbed multiple signals may interfere with identification of a layer, an interface, interfaces, etc. (e.g., consider an analysis that determines temporal thickness of a layer, etc.).', 'FIG.', '3\n shows some examples of data acquisition techniques or “surveys” that include a zero-offset vertical seismic profile (VSP) technique \n301\n, a deviated well vertical seismic profile technique \n302\n, an offset vertical seismic profile technique \n303\n and a walkaway vertical seismic profile technique \n304\n.', 'In each of the examples, a geologic environment \n341\n with a surface \n349\n is shown along with at least one energy source (e.g., a transmitter) \n342\n that may emit energy where the energy travels as waves that interact with the geologic environment \n341\n.', 'As an example, the geologic environment \n341\n may include a bore \n343\n where one or more sensors (e.g., receivers) \n344\n may be positioned in the bore \n343\n.', 'As an example, energy emitted by the energy source \n342\n may interact with a layer (e.g., a structure, an interface, etc.) \n345\n in the geologic environment \n341\n such that a portion of the energy is reflected, which may then be sensed by at least one of the one or more of the sensors \n344\n.', 'Such energy may be reflected as an upgoing primary wave (e.g., or “primary” or “singly” reflected wave).', 'As an example, a portion of emitted energy may be reflected by more than one structure in the geologic environment and referred to as a multiple reflected wave.', 'As to the example techniques \n301\n, \n302\n, \n303\n and \n304\n, these are described briefly below, for example, with some comparisons.', 'As to the technique \n301\n, given the acquisition geometry, with no substantial offset between the source \n342\n and bore \n343\n, a zero-offset VSP may be acquired.', 'In such an example, seismic waves travel substantially vertically down to a reflector (e.g., the layer \n345\n) and up to the receiver \n344\n, which may be a receiver array.', 'As to the technique \n302\n, this may be another so-called normal-incidence or vertical-incidence technique where a VSP may be acquired in, for example, a deviated bore \n243\n with one or more of the source \n342\n positioned substantially vertically above individual receivers \n344\n (e.g., individual receiver shuttles).', 'The technique \n302\n may be referred to as a deviated-well or a walkabove VSP.', 'As to the offset VSP technique \n303\n, in the example of \nFIG.', '3\n, an array of seismic receivers \n344\n may be clamped in a bore \n343\n and a seismic source \n342\n may be placed a distance away.', 'In such an example, non-vertical incidence can give rise to P- to S-wave conversion.', 'As to the walkaway VSP technique \n304\n, as an example, a seismic source \n342\n may be activated at numerous positions along a line on the surface \n349\n.', 'The techniques \n301\n, \n302\n, \n303\n and \n304\n may be implemented as onshore and/or offshore surveys.', 'As may be appreciated from the examples of \nFIG.', '3\n, a borehole seismic survey may be categorized by a survey geometry, which may be determined by source offset, borehole trajectory and receiver array depth.', 'For example, a survey geometry may determine dip range of interfaces and the subsurface volume that may be imaged.', 'As an example, a survey may define a region, for example, a region about a borehole (e.g., via one or more dimensions that may be defined with respect to the borehole).', 'As an example, positions of equipment may define, at least in part, a survey geometry (e.g., and a region associated with a borehole, wellbore, etc.).', 'The example techniques \n301\n, \n302\n, \n303\n and \n304\n of \nFIG.', '3\n may be applied, for example, to provide information and/or images in one or two dimensions (e.g., or optionally three-dimensions, depending on implementation).', 'As an example, a data acquisition technique may be implemented to help understand a fracture, fractures, a fracture network, etc.', 'As an example, a fracture may be a natural fracture, a hydraulic fracture, a fracture stemming from production, etc.', 'As an example, seismic data may help to characterize direction and magnitude of anisotropy that may arise from aligned natural fractures.', 'As an example, a survey may include use of offset source locations that may span, for example, a circular arc to probe a formation (e.g., from a wide range of azimuths).', 'As an example, a hydraulically induced fracture or fractures may be monitored using one or more borehole seismic methods.', 'For example, while a fracture is being created in a treatment well, a multicomponent receiver array in a monitor well may be used to record microseismic activity generated by a fracturing process.', 'As mentioned, equipment may include fracturing equipment where such equipment may be employed to generate one or more fractures in a geologic environment.', 'As an example, a method to generate fractures can include a delivery block for delivering fluid to a subterranean environment, a monitor block for monitoring fluid pressure and a generation block for generating fractures via fluid pressure.', 'As an example, the generation block may include activating one or more fractures.', 'As an example, the generation block may include generating and activating fractures.', 'As an example, activation may occur with respect to a pre-existing feature such as a fault or a fracture.', 'As an example, a pre-existing fracture network may be at least in part activated via a method that includes applying fluid pressure in a subterranean environment.', 'The foregoing method may be referred to as a treatment method or a “treatment”.', 'Such a method may include pumping an engineered fluid (e.g., a treatment fluid) at high pressure and rate into a reservoir via one or more bores, for example, to one or more intervals to be treated, which may cause a fracture or fractures to open (e.g., new, pre-existing, etc.).', 'As an example, a fracture may be defined as including “wings” that extend outwardly from a bore.', 'Such wings may extend away from a bore in opposing directions, for example, according in part to natural stresses within a formation.', 'As an example, proppant may be mixed with a treatment fluid to keep a fracture (or fractures) open when a treatment is complete.', 'Hydraulic fracturing may create high-conductivity communication with an area of a formation and, for example, may bypass damage that may exist in a near-wellbore area.', 'As an example, stimulation treatment may occur in stages.', 'For example, after completing a first stage, data may be acquired and analyzed for planning and/or performance of a subsequent stage.', "Size and orientation of a fracture, and the magnitude of the pressure to create it, may be dictated at least in part by a formation's in situ stress field.", 'As an example, a stress field may be defined by three principal compressive stresses, which are oriented perpendicular to each other.', 'The magnitudes and orientations of these three principal stresses may be determined by the tectonic regime in the region and by depth, pore pressure and rock properties, which determine how stress is transmitted and distributed among formations.', 'Where fluid pressure is monitored, a sudden drop in pressure can indicate fracture initiation of a stimulation treatment, as fluid flows into the fractured formation.', 'As an example, to break rock in a target interval, fracture initiation pressure exceeds a sum of the minimum principal stress plus the tensile strength of the rock.', 'To determine fracture closure pressure, a process may allow pressure to subside until it indicates that a fracture has closed.', 'A fracture reopening pressure may be determined by pressurizing a zone until a leveling of pressure indicates the fracture has reopened.', 'The closure and reopening pressures tend to be controlled by the minimum principal compressive stress (e.g., where induced downhole pressures exceed minimum principal stress to extend fracture length).', 'After performing fracture initiation, a zone may be pressurized for furthering stimulation treatment.', 'As an example, a zone may be pressurized to a fracture propagation pressure, which is greater than a fracture closure pressure.', 'The difference may be referred to as the net pressure, which represents a sum of frictional pressure drop and fracture-tip resistance to propagation (e.g., further propagation).', 'As an example, a method may include seismic monitoring during a treatment operation (e.g., to monitor fracture initiation, growth, etc.).', 'For example, as fracturing fluid forces rock to crack and fractures to grow, small fragments of rock break, causing tiny seismic emissions, called microseisms.', 'Equipment may be positioned in a field, in a bore, etc. to sense such emissions and to process acquired data, for example, to locate microseisms in the subsurface (e.g., to locate hypocenters).', 'Information as to direction of fracture growth may allow for actions that can “steer” a fracture into a desired zone(s) or, for example, to halt a treatment before a fracture grows out of an intended zone.', 'Seismic information (e.g., information associated with microseisms) may be used to plan one or more stages of fracturing operations (e.g., location, pressure, etc.).', 'FIGS.', '4\n and \n5\n show an example of a method \n400\n that includes generating fractures.', 'As shown, the method \n400\n can include various operational blocks such as one or more of the blocks \n401\n, \n402\n, \n403\n, \n404\n, \n405\n and \n406\n.', 'The block \n401\n may be a drilling block that includes drilling into a formation \n410\n that includes layers \n412\n, \n414\n and \n416\n to form a bore \n430\n with a kickoff \n432\n to a portion defined by a heel \n434\n and a toe \n436\n, for example, within the layer \n414\n.', 'As illustrated with respect to the block \n402\n, the bore \n430\n may be at least partially cased with casing \n440\n into which a string or line \n450\n may be introduced that carries a perforator \n460\n.', 'As shown, the perforator \n460\n can include a distal end \n462\n and charge positions \n465\n associated with activatable charges that can perforate the casing \n440\n and form channels \n415\n-\n1\n in the layer \n414\n.', 'Next, per the block \n403\n, fluid may be introduced into the bore \n430\n between the heel \n434\n and the toe \n436\n where the fluid passes through the perforations in the casing \n440\n and into the channels \n415\n-\n1\n.', 'Where such fluid is under pressure, the pressure may be sufficient to fracture the layer \n414\n, for example, to form fractures \n417\n-\n1\n.', 'In the block \n403\n, the fractures \n417\n-\n1\n may be first stage fractures, for example, of a multistage fracturing operation.', 'Per the block \n404\n, additional operations are performed for further fracturing of the layer \n414\n.', 'For example, a plug \n470\n may be introduced into the bore \n430\n between the heel \n434\n and the toe \n436\n and positioned, for example, in a region between first stage perforations of the casing \n440\n and the heel \n434\n.', 'Per the block \n405\n, the perforator \n460\n may be activated to form additional perforations in the casing \n440\n (e.g., second stage perforations) as well as channels \n415\n-\n2\n in the layer \n414\n (e.g., second stage channels).', 'Per the block \n406\n, fluid may be introduced while the plug \n470\n is disposed in the bore \n430\n, for example, to isolate a portion of the bore \n430\n such that fluid pressure may build to a level sufficient to form fractures \n417\n-\n2\n in the layer \n414\n (e.g., second stage fractures).', 'In a method such as the method \n400\n of \nFIGS.', '4\n and \n5\n, it may be desirable that a plug (e.g., the plug \n470\n) includes properties suited to one or more operations.', 'Properties of a plug may include mechanical properties (e.g., sufficient strength to withstand pressure associated with fracture generation, etc.) and may include one or more other types of properties (e.g., chemical, electrical, etc.).', 'As an example, it may be desirable that a plug degrades, that a plug seat degrades, that at least a portion of a borehole tool degrades, etc.', 'For example, a plug may be manufactured with properties such that the plug withstands, for a period of time, conditions associated with an operation and then degrades (e.g., when exposed to one or more conditions).', 'In such an example, where the plug acts to block a passage for an operation, upon degradation, the passage may become unblocked, which may allow for one or more subsequent operations.', 'FIG.', '6\n shows an example of a microseismic survey \n610\n, which may be considered to be a method that implements equipment for sensing elastic wave emissions of microseismic events (e.g., elastic wave energy emissions caused directly or indirectly by a treatment).', 'As shown, the survey \n610\n is performed with respect to a geologic environment \n611\n that may include a reflector \n613\n.', 'The survey \n610\n includes an injection bore \n620\n and a monitoring bore \n630\n.', 'Fluid injected via the injection bore \n620\n generates a fracture \n622\n that is associated with microseismic events such as the event \n624\n.', 'As shown in the example of \nFIG.', '6\n, energy of a microseismic event may travel through a portion of the geologic environment \n611\n, optionally interacting with one or more reflectors \n613\n, and pass to the monitoring bore \n630\n where at least a portion of the energy may be sensed via a sensing unit \n634\n, which may include a shaker, three-component geophone accelerometers isolated from a sensing unit body (e.g., via springs, etc.), coupling contacts, etc.', 'In the example of \nFIG. \n6\n, the sensed energy includes compressional wave energy (P-wave) and shear wave energy (S-wave).', 'Sensed energy may be analyzed, for example, to determine one or more of distance and azimuth from a sensor to a source of an elastic wave emission and depth of a source of an elastic wave emission (e.g., to determine location information, etc.).', 'In a fracturing operation, a source of an elastic wave emission may be registered as an event, which can include a time, a location and one or more acquired signals (e.g., traces).', 'Information associated with an event may be analyzed to determine one or more of location and magnitude.', 'As an example, distance (d) to an event may be derived by measuring a time difference (ΔT) between arrival times for a P-wave (TP) and an S-wave (TS).', 'The value of the distance d may depend on use of a velocity model that characterizes velocity of elastic wave energy (e.g., elastic waves) with respect to depth.', 'A velocity model may describe P-wave velocity and S-wave velocity with respect to depth (e.g., variation in material, pressures, etc. of a geologic environment).', 'Azimuth to a microseismic event may be determined by analyzing particle motion of P-waves, for example, using hodograms.', 'FIG.', '6\n shows an example of a hodogram \n660\n as a plot of sensed energy along at least two geophone axes as a function of time.', 'A hodogram may be a graph or curve that displays time versus distance of motion.', 'For example, a hodogram may be a crossplot of two components of particle motion over a time window.', 'Hodograms may be part of a borehole seismologic survey where they may be used to determine arrival directions of waves and to detect shear-wave splitting.', 'As to determination of depth of a microseismic event, as illustrated in a plot \n680\n, P-wave and S-wave arrival delays between sensors, or moveout, at the monitoring bore \n630\n may be analyzed.', 'Microseismicity recorded during multistage fracture treatments may provide disperse “clouds” of events (e.g., located at individual event hypocenters).', 'As an example, a method can include analyzing clouds of events to extract planar-type features, which may be indicative of fracture location, directions of stresses, etc.\n \nEffectiveness of hydro-fracturing, as a stimulation method, can depend on multiple variables and competing effects.', 'For instance, a hydraulic fracture, or stage-fracture, may be expected to propagate deeply into a pay zone and increase surface area through which hydrocarbons can be drained from a formation to a well.', 'As to predicting behavior, for example, via modeling, various variables (e.g., local stress, natural fracture network, injection rate, fluid viscosity, etc.) can act together to determine the size, orientation, aperture and geometry of the resulting stage-fracture values, for such variables may be not be known a priori, may be known with some uncertainty, etc.', 'During creation or propagation, a hydraulic fracture introduces changes in a stress field around it.', 'For example, an increase in the minimum horizontal stress, S\nhmin \n(e.g., “stress shadow effect”), can affect pressure to open a fracture (e.g., a subsequent fracture) and its shape, thus potentially affecting in a negative way effectiveness of a hydraulic-fracturing job.', 'On the other hand, these stress changes may also “reactivate” pre-existing natural fractures thorough phenomena such as shearing and dilatation, which potentially could have a positive effect of increasing permeability within an Estimated Stimulation Volume (ESV).', 'As an example, a stimulation process may reactivate a number of natural fractures to increase permeability within a region of interest, which may be, post-stimulation, an ESV.', 'As an example, a natural fracture may be considered to be active at some time or times during its existence and may be considered to be reactivated in response to an intervention such as a stimulation treatment (e.g., hydraulic fracturing, etc.).', 'Stress shadows, microseismicity, stimulated rock volume and production tend to be related in a complex manner.', 'It may be desirable to understand better such processes, for example, to help predict magnitude and consequences of a stress shadow and ESV.', 'As an example, a method may include establishing one or more linkages between fracture geometry, microseismicity, stress shadow, ESV and permeability.', 'As an example, a method can include defining total reactivated fracture volume (RFV) in a manner where it may be estimated by calculations based at least in part on an elasto-plastic solution to a problem of opening and shearing of one or more fractures under given stress conditions.', 'Such an approach can establish one or more links between factors such as, for example, dynamic stress changes, micro-seismic activity, effective changes in fracture aperture, and permeability.', 'As an example, a method may be a workflow that may include worksteps.', 'As an example, a method can include receiving input information from a multidimensional mechanical earth model (e.g., consider a 3D MEM) and receiving input information as to fracture geometry (e.g., consider geometry of a discrete fracture network (DFN)).', 'In such an example, the method may be formulated numerically where one or more numerical techniques may be applied to solve equations for output values (e.g., results).', 'As an example, starting from a 3D MEM and guidelines on fracture geometry, a numerical solution may be output for permeability enhancements, microseismicity and RFV.', 'Microseismic monitoring can be utilized for evaluating effectiveness of reservoir stimulation, for example, in unconventional reservoirs.', 'As an example, results of microseismic monitoring of hydraulic fractures can allow engineers to understand better various aspects of one or more of fracture networks, production, and geohazards (e.g., fracturing induced water production from adjacent formations or fault-related fluid loss).', 'Microseismic results can be integrated with and used to calibrate a mechanical earth model (MEM) and/or a fracture model, which may be used, for example, to predict fracture geometry and conductivity from stimulation operations.', 'As an example, real-time microseismic monitoring can facilitate making of timely decisions, which may, for example, help to reduce or prevent problems such as those related to geohazards, treatment overlap, poor coverage of the formation, poor cement, or completion hardware failure.', 'Microseismic monitoring can aim to provide event locations with a desired amount of accuracy as to such locations.', 'A desired amount of accuracy may depend on various factors such as, for example, equipment available, offset wells available, etc.', 'Accuracy and precision of microseismic results can depend on various factors such as, for example, quality of microseismic signals, suitability of survey geometry, accuracy of treatment and monitor wellbore locations, accuracy of a velocity model, and/or workflow used to map microseismic events.', 'Various aspects of a velocity model can influence accuracy of mapped hypocenter locations.', 'For example, an inaccurate velocity model can result in location errors of the order of hundreds of feet (e.g., 30 meters or more).', 'A velocity model can account for how seismic energy travels within a geologic environment.', 'Velocity, as a property of a geologic environment, can be a medium-distance divided by a traveltime of seismic energy.', 'Velocity can be determined via one or more techniques (e.g., laboratory measurements, acoustic logs, vertical seismic profiles, velocity analysis of seismic data, etc.).', 'Velocity may vary vertically, laterally and azimuthally in anisotropic media such as rocks; noting that velocity tends to increase with depth in the Earth because compaction reduces porosity.', 'Velocity may vary as a function of how it is derived from data.', 'For example, stacking velocity derived from normal moveout (NMO) measurements of common depth point (CDP) gathers can differ from the average velocity measured vertically from a check-shot or vertical seismic profile (VSP).', 'In a homogeneous medium, velocity would be expected to be the same, regardless of direction.', 'Various techniques can determine velocity in one or more types of anisotropic medium or media of a geologic environment, which may be a basis or bases for a velocity model or velocity models.', 'In seismology, seismic data, vertical seismic profiles and/or well log data may be used to perform an inversion that can generate a model as a result where the model can model layers, for example, including their thickness (e.g., h), density (e.g., p) and P- and S-wave velocities (e.g., Vp and Vs or V\nSH \nand V\nSV\n).', 'As an example, a method can include surface wave analysis (SWA).', 'For example, a method may include SWA modeling and inversion (SWAMI).', 'As an example, a framework may be provided that can perform SWA associated calculations (e.g., SWAMI calculations).', 'As an example, consider the SWAMI velocity modeling framework marketed by Schlumberger Limited (Houston, Texas), which may optionally be utilized at least in part with one or more other frameworks (e.g., PETREL®, OCEAN™, OMEGA™, etc.).', 'The SWAMI framework includes an inversion module that allows measurements from analysis of surface waves to be converted into a near-surface velocity model.', 'Such a velocity model may be added to geological information and geophysical measurements to provide a more accurate representation of the near-surface structure.', 'Such a framework may be utilized, for example, to initiate tomographic analysis, for example, as part of a prestack depth migration process.', 'As an example, a method can include modeling and inversion.', 'For example, information may be acquired in a geologic environment and analyzed to characterize at least a portion of the geologic environment as including various types of material (e.g., media such as rocks.).', 'As an example, a method can include acquiring data (e.g., or receiving data), which may be rendered as time with respect to offset (e.g., distance), can include data processing, which may include generating phase velocity versus wavelength data (e.g., a relationship between phase velocity and wavelength) and can include performing an inversion (e.g., inverting), which may include generating a relationship between velocity and depth.', 'Velocity may vary with respect to depth, for example, where velocity may generally increase with respect to depth and where in a near surface region a relationship or relationships between velocity and depth may differ from those at greater depths.', 'As an example, in a graphical form, a velocity model may be presented as velocity versus depth.', 'As an example, where a medium is anisotropic, a velocity model may optionally account for anisotropy and may be presented as a multidimensional model, which graphically may be, for example, a graphic represented with respect to three axes.', 'As survey design and event location workflows may be limited in flexibility, as an example, a method can include enhancing a velocity model.', 'Such a method can include processing information that can enhance accuracy in an effort to help minimize uncertainty associated with one or more mapped event locations.', 'Microseismic monitoring results can be generated via use of a velocity model.', 'As an example, a velocity model may be based on vertical velocities derived from sonic logs and, for example, one or more known-location source shots to orient geophones and calibrate the velocity model for anisotropy.', 'One type of isotropy is referred to as vertical transverse isotropy (VTI) or transverse isotropy (TI), which includes an axis of rotational symmetry (e.g., vertical or another direction).', 'As an example, for VTI, in layered rocks, properties can be substantially uniform horizontally within a layer, but vary vertically and from layer to layer.', 'Velocity model calibration can aim to account for at least some amount of TI, for example, consider accounting for VTI as may exist in unconventional shales.', 'Another type of TI is horizontal transverse isotropy (HTI).', 'As an example, velocity model calibration may aim to account for at least some amount of HTI where a series of shots are available at variable azimuths.', 'As an example, for VTI, anisotropy can be modeled by adding Thomsen anisotropy parameters epsilon, delta, and gamma until modeled arrival times fit observed arrival times for calibration shots.', 'In such an example, accuracy of the calibrated model may be further verified if the modeled calibration shot locations match their expected locations.', 'Various parameters may be used to characterize anisotropy, which can include one or more of the Thomsen parameters ε, δ and γ (see, e.g., Thomsen, “Weak elastic anisotropy”, Geophysics, Vol. 51, No. 10, pp. 1954-1966, October 1986).', 'The Thomsen parameter δ can describe offset effects (e.g., short offset).', 'As to the Thomsen parameter ε, it can describe offset effects (e.g., a long offset) and can relate to a difference between vertical and horizontal compressional waves (e.g., P or P-wave or quasi compressional wave qP or qP-wave).', 'As to the Thomsen parameter γ, it can describe a shear wave effect.', 'For example, consider an effect as to a horizontal shear wave with horizontal polarization to a vertical shear wave.', 'The Thomsen parameters ε and γ may be estimated from wave data while estimation of the Thomsen parameter δ involves access to additional information.', 'As noted by Thomsen (1986), the parameter δ controls most anisotropic phenomena of a medium of interest in geophysics, some phenomena of which are non-negligible even when anisotropy is considered to be weak.', 'Thomsen (1986) presents the following velocity equations (e.g., velocity model equations) for weak anisotropy and normal moveout (NMO), listed below for P-wave, SV-wave and SH-wave: \n \nV\nNMO\n(\nP\n)=α\n0\n(1+δ) \n \nV\nNMO\n(\nSV\n)=β\n0\n(1+(α\n0\n2\n/β\n0\n2\n)(ε−δ)) \n \nV\nNMO\n(\nSH\n)=β\n0\n(1+γ) \n where α\n0 \nis the vertical P wave velocity (e.g., ˜(C\n33\n/ρ)\n0.5\n) and where β\n0 \nis the vertical S wave velocity (e.g., ˜(C\n44\n/ρ)\n0.5\n).', 'As illustrated in the examples of \nFIGS.', '4\n and \n5\n, hydraulic fracturing may be performed via horizontal completions.', 'Horizontal completions stem from horizontal drilling, which can be a subset of directional drilling.', 'As an example, horizontal drilling may be classified based on departure of a bore from vertical, for example, where the bore exceeds about 80 degrees.', 'In some instances, after reaching a portion at about 90 degrees (horizontal), drilling of the bore may optionally occur in a slight upward manner.', 'In such cases, the angle past 90 degrees may be continued (e.g., as in about 95 degrees); rather than reporting it as deviation from vertical (e.g., which would be about 85 degrees).', 'As a horizontal well may penetrates a greater length of a reservoir, it may offer production improvement over a vertical well.', 'As to microseismic monitoring, as explained with respect to \nFIG.', '6\n, geophones may be positioned in an offset well, which may be, for example, a lateral well (e.g., an offset horizontal well that is offset to a well in which stimulation is being applied).', 'As an example, a source of uncertainty in such an example can be that the depths of calibration are somewhat limited.', 'As an example, monitoring can include positioning equipment in one or more wells where such equipment may be positioned via wireline or other type of line, cable, coil, etc.', 'In various monitoring operations, equipment is moved up a bore to various positions (e.g., TP\n1\n as a most distal to TPN as a most proximate to a surface opening of a bore).', 'As an example, a source may deliver both P-wave and S-wave energy via delivery in one or more axes.', 'As an example, various types of equipment may be utilized in a field operation.', 'For example, consider sliding sleeve completions or coiled tubing triggered systems.', 'As an example, a completion technique may be of a type that does not have perforations.', 'As to sliding sleeves, balls can be dropped to isolate each subsequent stage of a series of stages where such ball-seating events can be somewhat difficult to identify in real-time without pumping pressure data.', 'As an example, a sliding sleeve completions approach may utilize a coiled tubing triggered system, which may not create a known-location seismic source(s).', 'As an example, a method for seismic monitoring can include leveraging a downhole controlled source that pulses (e.g., fires) at controlled (i) time and (ii) depth and with a (iii) controlled radiation pattern within a (iv) controlled frequency range.', 'In such an example, acquired data can be utilized to refine an initial log-derived velocity model for microseismic monitoring, which may be real-time seismic monitoring.', 'As an example, velocity model calibration may be performed based on perforation shots along a treatment well for an individual stage of stimulation.', 'Perforation shots can provide representations of raypaths between microseismic events and monitoring geophones.', 'Where perforation shots are not available, other options may be available such as, for example, string shots in an adjacent well, ball-seating events in sliding-sleeve completions, a vibrator source at the surface, and an early treatment event.', 'As an example, a method can include utilizing one or more types of seismic data for microseismic monitoring.', 'As an example, microseismic monitoring can include velocity model calibration using perforation shots, string shots, surface shots, and/or first events by making use of a downhole controlled source that pulses (e.g., fires) at a controlled (i) time and (ii) depth, and with a (iii) controlled radiation pattern within a (iv) controlled frequency range where data acquired may be utilized to refine an initial log-derived velocity model.', 'As an example, a refined calibrated velocity model can allow for increased accuracy of mapped microseismic event locations (hypocenters).', 'In such an example, one or more locations can optionally be analyzed as part of a workflow for real-time decision making, fracture geometry estimates, and/or model integration.', 'As to real-time, such a term can include processing times and transmission times for information (e.g., data).', 'As an example, real-time may be of the order of a few minutes.', 'For example, via use of a refined velocity model in the form of stored information (e.g., stored in memory of a storage device), a microseismic event may be located in a time period that is of the order of a few minutes after acquisition of seismic energy associated with the microseismic event.', 'In such an example, the refined velocity mode (e.g., as stored information) can be a velocity model that is based at least in part on seismic energy generated by a controlled source; such an approach may be referred to as a velocity model calibration technique (e.g., a controlled source velocity calibration (CSVC) technique).', 'As an example, a CSVC approach may provide for robust calibration source (e.g., where perforations may not be available), may provide for improvement over perforation shots due to a more accurate time of origin signal (e.g., TO as a signal origin time), may provide a directional source to reliably generate P and/or S phases (e.g., optionally on request), may provide more suitable coverage than provided by vibrator (e.g., vibe) and string shot sources, and/or may provide more flexibility in depth coverage compared to one or more other techniques alone (e.g., consider >>>vibe, >>string shot, >perforations), as may depend on survey/', 'well configuration.', 'As an example, a CSVC approach may provide an ability to capture data over a wider depth range for horizontal arrays and/or may provide a finer resolution due to flexible receiver and source spacing, which may be tailored to focus on a specific zone of interest.', 'As an example, where desired, a layer-by-layer calibration approach may be implemented with a relatively small amount of advanced planning.', 'As an example, stimulation can include hydraulic fracturing, which can include perforating.', 'As an example, stimulation can include steam flooding.', 'As an example, stimulation may alter velocity in a formation.', 'As an example, a method can include performing crosswell monitoring with respect to one or more types of stimulations.\n \nFIG.', '7\n shows examples of method \n710\n and \n730\n, an approximated example of a velocity model \n745\n and an example of a system \n750\n.', 'As shown, the method \n710\n includes a reception block \n712\n for receiving crosswell shot data, an identification block \n714\n for identifying P-wave and S-wave arrivals (e.g., SH and/or SV), an identification block \n716\n for identifying time or times of one or more individual shots (e.g., which may be origin times that may be associated with controlled shots), a calibration block \n718\n for calibrating a velocity model (e.g., refining an initial velocity model), and a storage block \n720\n for storing information based at least in part on the calibrated velocity model.', 'As to the identification block \n714\n and the calibration block \n718\n, a velocity model can provide for modeling of P and S velocities.', 'As shown in \nFIG.', '7\n, the method \n730\n includes a reception block \n732\n for receiving fracturing data (e.g., sensed microseismic signals), a reception block \n734\n for receiving at least a portion of the stored information and/or revising the stored information based at least in part on a portion of the fracturing data (e.g., generating new information), a location block \n736\n for locating one or more microseismic events based at least in part on the received fracturing data and the at least a portion of the stored information, an assessment block \n738\n for assessing the one or more microseismic event locations and an optional continuation block \n740\n for continuing a workflow.', 'For example, a workflow may include one or more actions associated with stimulation, production, reporting, etc.', 'As shown in the example of \nFIG.', '7\n, the method \n730\n can include looping per a loop block \n742\n, for example, to receive data and/or process data for one or more additional stages of a multistage stimulation.', 'As an example, a workflow can include modeling stimulation, for example, via a framework such as the MANGROVE™ framework (Schlumberger Limited, Houston, Texas).', 'As an example, a workflow can include executing a framework such as, for example, the MISTRAL™ framework (Schlumberger Limited, Houston, Texas).', 'As an example, the storage block \n720\n may store information in the form of a look-up table (LUT) and/or in one or more other forms (e.g., as a data structure).', 'As an example, the reception block \n734\n may include receiving information from a LUT and/or one or more other types of data structures.', 'As an example, the reception block \n734\n can include revising the stored information, for example, by generating revised information, which may include new information based at least in part on a portion of the received data of the reception block \n732\n.', 'For example, information may be revised and/or generated based on data acquired during a fracturing operation (e.g., hydraulic fracturing).', 'As an example, the method \n730\n can include making one or more calls to a system that can access the stored information and that can return information germane to locating one or more microseismic events.', 'As an example, the stored information may be loadable in memory of a computing system such that the information can be received (e.g., loaded) and then accessed from memory during performance of the method \n730\n where one or more loops may exist as to handling of data to locate one or more microseismic events.', 'As an example, the stored information may be in the form of one or more models with various model parameter values determined via the calibration block \n718\n.', 'In such an example, received information may be based at least in part on one or more of the one or more models.', 'As an example, one or more models and associated parameter values may be loaded into memory of a computing system such that the parameter values are received (e.g., loaded) and then utilized in a model-based approach during performance of the method \n730\n to locate one or more microseismic events.', 'As mentioned, the method \n730\n can include revising information based at least in part on data acquired during a fracturing operation (e.g., a stimulation operation, which may be a treatment operation).', 'The methods \n710\n and \n730\n may be associated with various computer-readable storage media (CRM) blocks \n713\n, \n715\n, \n717\n, \n719\n, \n721\n, \n733\n, \n735\n, \n737\n, \n739\n and \n741\n.', 'Such blocks may include instructions suitable for execution by one or more processors (or processor cores) to instruct a computing device or system to perform one or more actions (e.g., processor-executable instructions).', 'As an example, a single medium may be configured with instructions to allow for, at least in part, performance of various actions of the method \n710\n and/or the method \n730\n.', 'As an example, a computer-readable medium (CRM) may be a computer-readable storage medium.', 'A computer-readable storage medium is not a carrier wave, is not a signal and is non-transitory.', 'As shown in \nFIG.', '7\n, a velocity model \n745\n can account for one or more layers of a geologic environment (e.g., one or more types of media).', 'As an example, a velocity model may account for anisotropy and/or one or more types of symmetry (e.g., TI medium).', 'As an example, a velocity model can include one or more equations (see, e.g., equations such as the weak anisotropy equations given by Thomsen).', 'As shown in \nFIG.', '7\n, a system \n750\n may include one or more information storage devices \n752\n, one or more computers \n754\n, one or more network interfaces \n760\n and instructions \n770\n.', 'As to the one or more computers \n754\n, each computer may include one or more processors (e.g., or processing cores) \n756\n and memory \n758\n for storing instructions (e.g., the instructions \n770\n), for example, executable by at least one of the one or more processors \n756\n.', 'As an example, a computer may include one or more network interfaces (e.g., wired or wireless), one or more graphics cards, a display interface (e.g., wired or wireless), etc.', 'As an example, the system \n750\n may be configured to perform one or more methods.', 'As an example, one or more features of the system \n750\n may be implemented to perform one or more portions of the method \n710\n and/or one or more portions of the method \n730\n.\n \nFIG.', '8\n shows sets of example plots \n810\n (including a top view \n812\n along z direction and a side view \n814\n along y direction) and \n830\n (including a top view \n832\n along z direction and a side view \n834\n along y direction) for a geologic environment that includes a monitoring well \n816\n and a stimulation well \n818\n (e.g., a treatment well).', 'As shown, operations associated with the plots \n810\n include positioning one or more tools (e.g., \n822\nh\n1\n, \n822\nh\n2\n, and \n822\nh\n3\n) in a horizontal portion \n816\nH of the monitoring well \n816\n to acquire information associated with perforation shots \n820\nh \npositioned along a horizontal section \n818\nH of the stimulation well \n818\n; whereas, operations associated with the plots \n830\n include positioning the one or more tools (e.g., \n822\nh\n1\n, \n822\nh\n2\n, and \n822\nh\n3\n) in the horizontal section \n816\nH and the one or more tools (e.g., \n822\nv\n1\n, and \n822\nv\n2\n) in a vertical section \n816\nV of the monitoring well \n816\n to acquire information associated with crosswell shots \n850\nh \npositioned along the horizontal section \n818\nH and the crosswell shots \n850\nv \npositioned along the vertical section \n816\nV using a controlled crosswell shot source.', 'As indicated, the depth range as shown in the side view \n814\n) of the operations in the plots \n810\n is about 300 ft (e.g., about 100 meters); whereas, the depth range as shown in the side view \n844\n) of the operations in the plots \n830\n is about 1270 ft (e.g., about 400 meters).', 'As shown, a method can include increasing depth coverage for horizontal monitoring and treatment well configuration.', 'Again, the plots \n810\n show a setup with perforations where the monitor and treatment wells \n816\n and \n818\n are located at a similar depth.', 'In such a case, the depths across which the velocity model can be calibrated are limited by the range of perforations as may be expected to be positioned within a layer of a reservoir (e.g., shale reservoir).', 'In the example operations of the plots \n810\n, the vertical depth range is approximately 300 ft (e.g., about 100 m); however, the portion of the velocity model is even smaller due to the wells following dipping beds.', 'In contrast, in the example operations of the plots \n830\n, the vertical depth range that can be calibrated is increased to nearly about 1000 ft (e.g., about 300 m) due to the ability to place crosswell source shots (e.g., the crosswell shots \n850\nv\n) and receivers (e.g., the \n822\nv\n1\n and \n822\nv\n2\n) in the vertical sections \n818\nV and \n816\nV of the treatment and monitoring wells \n818\n and \n816\n, respectively.', 'In example operations of the plots \n830\n, the receivers and crosswell source shots have about 50 ft (e.g., about 15 m) spacing in the vertical sections \n818\nV and \n816\nV of the treatment and monitoring wells \n818\n and \n816\n, respectively.\n \nFIG.', '9\n shows an example plot \n900\n of an arrangement of a monitoring well \n902\n and a stimulation well \n906\n (e.g., a treatment well) where a receiver array \n904\n is positioned in the monitoring well \n902\n, where perforation locations \n908\n are indicated in the stimulation well \n906\n and where uncalibrated event locations (filled circles) and calibrated event locations (open circles) are shown.', 'In such an example, the calibrated event locations are calibrated using crosswell source information.', 'Thus, the example shown in the plots \n830\n can increase depth coverage and provide for a reduction in source spacing for a vertical treatment and monitor well configuration.', 'As an example, crosswell sources may be spaced at about 20 ft (e.g., about 7 m); whereas, perforations may be expected to have variable spacing, for example, with one or more relatively large gaps between adjacent perforation shots.', 'As an example, perforations can be monitored from a particular tool position; whereas, crosswell shots may be monitored from tool positions (e.g., a plurality of tool positions), which can allow for greater depth coverage as to velocity model calibration.', 'As an example, a depth offset between crosswell shots and tools can be selected to account for formation dip.', 'As an example, a workflow may proceed as follows:\n \nPrior to job: \n \n \n \n1.', 'Project setup\n \n2.', 'Crosswell survey planning\n \n \n \n \n \nImmediately prior to real-time: \n \n \n \n1.', 'Add crosswell shot data to project\n \n2.', 'Add a new stage to the survey \n \na. Input shot depths\n \n \n \n3.', 'Receiver orientation \n \na. Detect crosswell shots and pick P-wave arrivals\n \nb.', 'Select subset of shots (e.g., depends on project)\n \ne. QC P-wave arrival picks\n \nd. Orient receivers\n \n \n \nRepeat 1, 2 and 3 for each crosswell (CW) fan\n \n4.', 'Velocity model calibration \n \na. Pick SH-wave arrivals (and SV-wave arrivals, if clear)\n \nb. Pick TO time (T\n0\n) for each shot\n \nc. Calibrate velocity model\n \nd. Generate information (e.g., lookup table, etc.)', 'e. Locate crosswell shots\n \nf. QC P-wave and S-wave picks \n \nre-pick and re-locate if desired\n \n \n \ng.', 'If locations are acceptable, continue \n \nif not, redo calibration\n \n \n \n \n \n5.', 'Orient tools using vibe or other source\n \n \n \n \n \nIn real-time: \n \n \n \n6.', 'Process a fracturing stage \n \na. Generate new information (e.g., a new lookup table)\n \nb.', 'Locate fracturing events (e.g., microseismic events)\n \nc. QC events, re-pick and re-locate if necessary\n \n \n \n \n \n \n \nAs an example, a workflow or workflows may be performed in a tiered manner.', 'For example, a first tier may be a real-time tier that includes a few stations with the source, used in a one-dimensional manner.', 'Such a tier may be implemented when a velocity calibration method may not be readily available.', 'As an example, a second tier may optionally be a real-time tier.', 'Such a tier can include several stations in 1D, for example, as to a complex formation where perforation shots might not be sufficient to derive a proper velocity model.', 'As an example, a third tier can be an off-line tier where, for example, acquisition may be planned over a day or days before a fracturing operation.', 'As an example, such a tier may be performed for a complex formation/structure/geology that can benefit from a high-resolution velocity model (2D/3D).', 'As an example, as to a first tier, such a tier can include real-time microseismic monitoring where crosswell measurements can be taken prior to a fracture treatment and used to calibrate a velocity model for real-time event locations.', 'In such an example, the tier may provide a versatile calibration source in cases where no perforation shots are available or other calibration sources are suboptimal and/or may extend depth coverage for velocity model calibration in a horizontal monitoring configuration.', 'In such instances, using crosswell sources can provide a means to reduce uncertainty in the velocity model and improve subsequent event location accuracy.', 'As an example, sources used in crosswell surveys can be used for microseismic monitoring and can be types of sources that can be triggered at known locations and create acoustic signals within the rock that are recorded at the receiver array.', 'Such sources can provide information for calibrating a velocity model used in microseismic monitoring.', 'As an example, a controlled or controllable source can be an omnidirectional source.', 'As an example, a controlled or controllable source can be a piezoelectric type of source or can be a sparker type of source.', 'As an example, a controlled or controllable source can be a directional source.', 'As an example, a controlled or controllable source can include one or more features of the DEEPLOOK-CS™ source (Schlumberger Limited, Houston, Texas).', 'For example, consider a piezoelectric source that can emit seismic energy over one or more frequencies as may be selected from a range of frequencies (e.g., from about 100 Hz to about 2,000 Hz).', 'As an example, a treatment well may be utilized as a seismic source well prior to performing fracturing.', 'For example, a monitoring well may include receivers where seismic sources are positioned in a treatment well prior to one or more treatment operations.', 'As an example, a well may include one or more sources and one or more receivers (e.g., a source and a receiver in a common well).', 'As mentioned, calibration can account for vertical transverse isotropy (VTI) and may also account for horizontal transverse isotropy (HTI) where, for example, a series of shots are available at variable azimuths.', 'As an example, anisotropy can be modeled by adding Thomsen anisotropy parameters epsilon, delta, and gamma (Thomsen, 1986) until (1) modeled arrival times fit observed arrival times for calibration shots and (2) modeled locations for calibration shots align well with their expected locations.', 'As an example, a method can implement one or more different calibration methods to model anisotropy.', 'For example, consider using one or more of: (1) inversion for homogeneous anisotropy (e.g., single values across all depths); (2) inversion for variable anisotropy scaled by 1/Vp; and (3) manual selection of layers and application of variable anisotropy.', 'In a trial, a first dataset provided for comparing velocity model calibrations based on crosswell sources to another method based on perforations (e.g., perforation shots).', 'For a second dataset, for which no perforation shots were available, use of crosswell sources for calibration in a horizontal monitor well scenario is shown with enhancement of microseismic event locations.', 'Accuracy of a velocity model can be assessed by measuring the modeled offsets of the calibration sources (e.g., perforations and crosswell shots) from their expected locations.', 'As mentioned, the first dataset allowed for a comparison of accuracy of events located with a velocity model calibrated with perforations (perforation shots) to accuracy of events located with a model calibrated with crosswell sources in a project containing a vertical treatment well and a vertical monitor well, for example, as shown in \nFIG. \n9\n.', 'As illustrated in \nFIG.', '9\n, a crosswell source-derived model calibration reduced the average offset of perforations by nearly half that of the uncalibrated model (from about 78 ft (e.g., about 25 m) to about 45 ft (e.g., about 15 m)).', 'In this example, relatively little variability exists in the accuracy of perforation locations from models calibrated with the crosswell shots versus those calibrated with perforations, as shown in Table 1, below.', 'TABLE 1\n \n \n \n \n \n \n \n \nAverage offsets for perforation and crosswell shot locations using\n \n \n \nmodels without calibration, calibrated with perforations, and calibrated\n \n \n \nwith crosswell (CW) sources.', 'For the calibrated models, anisotropy was\n \n \n \nmodeled either by single Thomsen parameter values across all depths\n \n \n \nor by variable anisotropy scaled by 1/Vp.\n \n \n \n \n \n \n \n \n \n \n \n \nStandard\n \n \n \nCalibration Type\n \nAverage Offset (ft)\n \nDeviation (ft)\n \n \n \n \n \n \nPerforation Shots (n = 24)', 'No Calibration\n \n77.9 (~24 m)\n \n20.1 (~6 m)\n \n \n \nPerf Based, 1/Vp\n \n45.5 (~14 m)\n \n16.4 (~5 m)\n \n \n \nPerf Based, Single Value\n \n42.2 (~13 m)\n \n15.5 (~5 m)\n \n \n \nCW Source Based, 1/Vp\n \n48.4 (~15 m)\n \n19.8 (~6 m)\n \n \n \nCW Source Based, Single Value\n \n45.6 (~14 m)\n \n19.4 (~6 m)\n \n \n \nCrosswell Shots (n = 41)', 'No Calibration\n \n67.8 (~21 m)\n \n27.3 (~8 m)\n \n \n \nPerf Based, 1/Vp\n \n35.2 (~11 m)\n \n20.9 (~6 m)\n \n \n \nPerf Based, Single Value\n \n38.2 (~12 m)\n \n22.1 (~7 m)\n \n \n \nCW Source Based, 1/Vp\n \n39.1 (~12 m)\n \n20.9 (~6 m)', 'CW Source Based, Single Value\n \n35.5 (~11 m)\n \n19.1 (~6 m)', 'As to the data of Table 1, the perforation shots offset range is about 42 ft to 48 ft (e.g., about 12.8 m to about 14.6 m) and the crosswell shots offset range is about 35 ft to 39 ft (e.g., about 10.6 m to about 11.9 m).', 'The smaller offsets for the crosswell shots stems from high quality of the data; whereas, the perforation shot quality tended to be more variable, leading to inconsistency in arrival time picks.', 'As indicated in Table 1, the type of inversion method (single value or 1/Vp scaling) appears to have a relatively small effect on the accuracy of the shot locations for the dataset, with a single value of anisotropy across the model being slightly better for the perforation locations.', 'Such results may be due to the relatively uniform formation velocities in the geologic environment examined.', 'As an example, crosswell shots can benefit a horizontal monitoring configuration.', 'As an example, crosswell source-derived velocity models can be formed in both the horizontal and the vertical sections of a horizontal monitor well that can be used to monitor a horizontal treatment (e.g., a formation such as the Austin Chalk of the Eagle Ford).', 'FIG.', '10\n shows example plots \n1010\n and \n1030\n that allow for a comparison of crosswell source shot locations using an uncalibrated model (filled circles) and a model calibrated with crosswell sources (open circles).', 'Locations for the horizontal array as shown in the plot \n1010\n and the vertical array as shown in the plot \n1030\n demonstrated an improvement when calibrated using the crosswell sources.', 'Although the formation in the depth range of the laterals had relatively low anisotropy (e.g., about 0 percent to about 5 percent), a model calibrated with crosswell shots in just the lateral improved crosswell source locations compared to the locations from an isotropic model.', 'The average offset reduced from about 116 ft (e.g., about 38 m) without calibration to about 83 ft (e.g., about 27 m) to about 102 ft (e.g., about 33 m), depending on the calibration method.', 'Both the monitor well and treatment well laterals were at about the same depth, which limited the calibration to a narrow depth range.', 'The crosswell survey conducted in the heel and vertical portions of the wells indicated more anisotropy was present in layers above the laterals.', 'As to calibration of a velocity model, shear signal from the piezoelectric source deteriorated approximately 300 ft (e.g., about 100 m) above the laterals, a depth corresponding to a very large velocity contrast, but also where the inclination of the lateral containing the source decreased to less than about 15 degrees.', 'Poor shear may be possibly due to one or more of properties of the formation, poor treatment well conditions, or a failure of the source to generate shear while nearly vertical.', 'Automated inversions using the crosswell shot data resulted in lesser quality shot locations when compared to use of the isotropic model.', 'As an example, a method can include enhancing a model by using shots with good shear, for example, in the formation of \nFIG. \n10\n, within about the first 300 ft (e.g., about 100 m) above the laterals for the model calibration and location comparisons.', 'As an example, a method can include manual calibration (e.g., selecting individual layers and applying variable anisotropy with depth), which may improve shot locations.', 'For example, referring again to the example of \nFIG. \n10\n, about 80 ft (e.g., about 26 m) average offset resulted compared to about 119 ft (e.g., about 39 m) with the uncalibrated model.', 'Such results may be due to the properties of a formation at such depths.', 'As an example, a method can include manual and/or automated model calibration, for example, a method can include using a manually calibrated model for better locations for controlled source shots in a heel section than when compared to models calibrated from sources in a lateral.', 'As an example, crosswell sources can be used for calibration of a velocity model.', 'As an example, in a horizontal monitoring configuration, using crosswell sources in the vertical portion of the treatment well can provide calibration information for additional depth coverage in an area where fracture events are likely to occur.', 'Results show that crosswell seismic sources are a viable option when other calibration sources are not available or when monitoring geometry limits the information available from one or more other calibration sources.\n \nFIG.', '11\n shows an example of a method \n1100\n that includes a reception block \n1102\n for receiving crosswell seismic data associated with an anisotropic formation, a generation block \n1104\n for generating a calibrated crosswell velocity model and a storage block \n1106\n for storing calibrated crosswell velocity model information for the anisotropic formation.', 'In such an example, the crosswell seismic data can be acquired receivers (e.g., geophones) that sense emissions generated by controlled or controllable sources.', 'Such sources can be or include controlled or controllable direction sources.', 'As an example, a method can include triggering sources that are directional with controllable direction.', 'As an example, a method can include triggering sources that emit over a frequency range where the frequency range is controllable.', 'As an example, a source can be of controlled directionality, controlled timing of actuation of the source (e.g., triggering, TO or T\n0\n) and controlled frequency content of energy emitted by the source (e.g., frequency sweep of the energy emitted by the source).', 'As to calibration of a velocity model, data stemming from sources that are controllable in time (e.g., shot time), directionality (e.g., direction(s) of emission of energy) and frequency (e.g., frequency content).', 'As an example, the frequency may be selected to boost signal to noise for a particular anisotropic formation (e.g., a reservoir region of the anisotropic formation).', 'In the example of \nFIG. \n11\n, the method \n1100\n can also include a reception block \n1110\n for receiving seismic data responsive to stimulation of an anisotropic formation via a well disposed in the anisotropic formation; a reception block \n1120\n for receiving crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; a location block \n1130\n for locating a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and a render block \n1140\n for rendering the located microseismic event to a display with respect to one or more dimensions of the anisotropic formation.', 'As shown, a loop block \n1150\n may direct the method \n1100\n to one or more prior blocks, for example, for locating one or more additional microseismic events, optionally associated with another stage of a multistage stimulation.', 'The method \n1100\n may be associated with various computer-readable storage media (CRM) blocks \n1103\n, \n1105\n, \n1107\n, \n1111\n, \n1121\n, \n1131\n, and \n1141\n.', 'Such blocks may include instructions suitable for execution by one or more processors (or processor cores) to instruct a computing device or system to perform one or more actions (e.g., processor-executable instructions).', 'As an example, a single medium may be configured with instructions to allow for, at least in part, performance of various actions of the method \n1100\n.', 'As an example, the method \n1100\n can include receiving crosswell microseismic data per the reception block \n1102\n that corresponds to sources and receivers in a substantially vertical portion of a well or substantially vertical portions of wells.', 'In such an example, a depth range may be extended for calibration of a velocity model that can be used to locate microseismic events associated with hydraulic fracturing.', 'For example, such events may be located at a distance from a well bore where data from vertical portion or portions can be used to calibrate a velocity model at such distances from the well bore.', 'As an example, a vertical well can include a lateral leg where information may be acquired for a portion of the vertical well above the lateral leg and for a portion of the vertical well below the lateral leg.', 'As an example, a vertical well may span a region above a lateral well and a region below a lateral well.', 'In such an example, information may be acquired for one or more of the regions.', 'Such information may be utilized to extend calibration of a velocity model to regions above and/or below the lateral well were hydraulic fracturing is performed using the lateral well (e.g., a horizontal well).', 'As an example, a method can be applied to an anisotropic formation.', 'As an example, a crosswell calibrated velocity model can model vertical and horizontal velocities.', 'For example, a TI model may be utilized and calibrated.', 'As an example, a crosswell calibrated velocity model can be calibrated based at least in part on crosswell seismic data.', 'For example, such a calibrated model can be calibrated based at least in part on seismic data associated with one or more perforation shots (e.g., where such information may be available).', 'As an example, a crosswell calibrated velocity model can span a depth range in an anisotropic formation where the depth range may overlap with a depth range of expected hydraulic fractures generated in response to stimulation delivered via a well (e.g., a lateral portion of a well).', 'As an example, a method may be implemented at least in part via the MISTRAL® technology (Schlumberger Limited, Houston, Texas).', 'As an example, a method may be part of a workflow that may be implemented as least in part via the PETREL® framework.', 'As an example, a method can include receiving seismic data responsive to stimulation of an anisotropic formation via a well disposed in the formation; receiving crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locating a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and rendering the located microseismic event to a display with respect to one or more dimensions of the anisotropic formation.', 'In such an example, the method can include generating the crosswell calibrated velocity model information.', 'For example, such generating can include controlled triggering of a source in the well where, for example, the controlled triggering of the source can include triggering of the source prior to the stimulation.', 'Controlled triggering can include triggering that occurs at a known time or known times.', 'As an example, a method can include receiving seismic energy via receivers in an offset well that is offset from a stimulation well.', 'As an example, a source disposed in a well can be a piezoelectric source where a piezoelectric effect generates seismic energy that can travel into a formation.', 'As an example, a source can be a directional source.', 'As an example, a source can have a planned emission frequency or range of frequencies.', 'For example, a workflow can include pre-determining an emission frequency or range of frequencies and selecting a source and/or adjusting a source to emit energy at the pre-determined emission frequency or range of frequencies.', 'As an example, a crosswell calibrated velocity model information can be calibrated based at least in part on seismic data associated with a horizontal well portion of a well.', 'As an example, a crosswell calibrated velocity model information can be calibrated based at least in part on seismic data associated with a horizontal well portion and a vertical well portion of a well.', 'In such an example, the vertical portion may be in material (e.g., rock) that is substantially the same as material about a horizontal portion of the well and/or that differs from material about a horizontal portion of the well.', 'As an example, crosswell calibrated velocity model information can include information based a velocity model that includes at least one Thomsen parameter.', 'As an example, a stimulation can be a first stage of a multistage stimulation.', 'In such an example, for a second stage of the multistage stimulation, a method can include repeating receiving of seismic data, receiving of crosswell calibrated velocity model information and locating a microseismic event generated by the second stage.', 'As an example, a method can include receiving crosswell calibrated velocity model information at least in part by receiving information from a stored data structure such as, for example, a look-up table.', 'In such an example, a storage device or a storage system can include stored crosswell calibrated velocity model information that can be accessed in an on-demand manner, for example, responsive to a transmission and receipt of a request.', 'As an example, a method can include locating a plurality of microseismic events serially.', 'Such a method may optionally be performed in real-time, where locating of a microseismic event occurs within a time period of the order of minutes after occurrence of the microseismic event.', 'For example, consider locating an event within a time period of less than about 10 minutes after occurrence of the event.', 'As an example, in a real-time scenario, location of an event or locations of events may be utilized to adjust a stimulation treatment.', 'For example, consider adjusting one or more parameters of a hydraulic fracturing operation based at least in part on location of an event or locations of events during performance of the hydraulic fracturing operation.', 'As an example, a method can include modeling stimulation of a formation to generate at least one modeled fracture where such modeling can be based at least in part on a determined location of a microseismic event or determined locations of microseismic events as associated with a stimulation operation (e.g., one or more stages).', 'As an example, a system can include a processor; memory accessible by the processor; processor-executable instructions stored in the memory that include instructions to instruct the system to: receive seismic data responsive to stimulation of an anisotropic formation via a well disposed in the anisotropic formation; receive crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locate a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and render the located microseismic event to a display with respect to one or more dimensions of the formation.', 'In such an example, the system can include instructions to generate the crosswell calibrated velocity model information.', 'As an example, one or more computer-readable storage media can include computer-executable instructions to instruct a system to: receive seismic data responsive to stimulation of an anisotropic formation via a well disposed in the formation; receive crosswell calibrated velocity model information that spans a depth range of the anisotropic formation; locate a microseismic event generated by the stimulation based at least in part on a portion of the received seismic data and based at least in part on the crosswell calibrated velocity model information; and render the located microseismic event to a display with respect to one or more dimensions of the anisotropic formation.', 'As an example, a system may include instructions, which may be provided to analyze data, control a process, perform a task, perform a workstep, perform a workflow, etc.\n \nFIG. \n12\n shows components of an example of a computing system \n1200\n and an example of a networked system \n1210\n.', 'The system \n1200\n includes one or more processors \n1202\n, memory and/or storage components \n1204\n, one or more input and/or output devices \n1206\n and a bus \n1208\n.', 'In an example embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components \n1204\n).', 'Such instructions may be read by one or more processors (e.g., the processor(s) \n1202\n) via a communication bus (e.g., the bus \n1208\n), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device \n1206\n).', 'In an example embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc. (e.g., a computer-readable storage medium).', 'In an example embodiment, components may be distributed, such as in the network system \n1210\n.', 'The network system \n1210\n includes components \n1222\n-\n1\n, \n1222\n-\n2\n, \n1222\n-\n3\n, . . .', '1222\n-N.', 'For example, the components \n1222\n-\n1\n may include the processor(s) \n1202\n while the component(s) \n1222\n-\n3\n may include memory accessible by the processor(s) \n1202\n.', 'Further, the component(s) \n1222\n-\n2\n may include an I/O device for display and optionally interaction with a method.', 'The network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.', 'As an example, a device may be a mobile device that includes one or more network interfaces for communication of information.', 'For example, a mobile device may include a wireless network interface (e.g., operable via IEEE 802.11, ETSI GSM, BLUETOOTH®, satellite, etc.).', 'As an example, a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM slot, audio/video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery.', 'As an example, a mobile device may be configured as a cell phone, a tablet, etc.', 'As an example, a method may be implemented (e.g., wholly or in part) using a mobile device.', 'As an example, a system may include one or more mobile devices.', 'As an example, a system may be a distributed environment, for example, a so-called “cloud” environment where various devices, components, etc. interact for purposes of data storage, communications, computing, etc.', 'As an example, a device or a system may include one or more components for communication of information via one or more of the Internet (e.g., where communication occurs via one or more Internet protocols), a cellular network, a satellite network, etc.', 'As an example, a method may be implemented in a distributed environment (e.g., wholly or in part as a cloud-based service).', 'As an example, information may be input from a display (e.g., consider a touchscreen), output to a display or both.', 'As an example, information may be output to a projector, a laser device, a printer, etc. such that the information may be viewed.', 'As an example, information may be output stereographically or holographically.', 'As to a printer, consider a 2D or a 3D printer.', 'As an example, a 3D printer may include one or more substances that can be output to construct a 3D object.', 'For example, data may be provided to a 3D printer to construct a 3D representation of a subterranean formation.', 'As an example, layers may be constructed in 3D (e.g., horizons, etc.), geobodies constructed in 3D, etc.', 'As an example, holes, fractures, etc., may be constructed in 3D (e.g., as positive structures, as negative structures, etc.).', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words “means for” together with an associated function.']

['1.', 'A method comprising:\nreceiving a velocity model derived via compressional (P) wave signals versus depth in a geologic environment that comprises an anisotropic formation comprising one or more subsurface layers;\nreceiving compressional (P) wave signals and shear (S) wave signals that span a depth range of the anisotropic formation, wherein the compressional (P) wave signals and the shear (S) wave signals are generated using a first controlled electric source disposed in a first kickoff portion of a first well and a second controlled electric source disposed in a first toe portion of the first well, wherein the first well is drilled from a surface layer into the anisotropic formation to form a first bore, wherein the first bore comprises the first kickoff portion spanned from the surface layer to the anisotropic formation and connected to the first toe portion spanned along the one or more subsurface layers via a first heel portion, and wherein the compressional (P) wave signals and the shear (S) wave signals are acquired via a first receiver array disposed in a second toe portion and a second receiver array disposed in a second heel portion and a second kickoff portion of a second well, wherein the second well is drilled from the surface layer into the anisotropic formation to form a second bore, wherein the second bore comprises the second kickoff portion spanned from the surface layer to the anisotropic formation and connected to the second toe portion spanned along the one or more subsurface layers via the second heel portion;\ncalibrating vertical and horizontal velocities of the velocity model using the compressional (P) wave signals and the shear (S) wave signals generated by the first controlled electric source and the second controlled electric source;\ngenerating a crosswell calibrated velocity model based on the calibrated vertical and horizontal velocities;\nreceiving first seismic data responsive to a first stage of stimulation of the anisotropic formation via a first perforation in the first toe portion of the first well disposed in the anisotropic formation, wherein the first seismic data comprise seismic data received by the receiver array;\nrevising information stored in a look-up table based at least in part on the first seismic data; locating a first microseismic event generated by the first stage of stimulation using at least a portion of the received first seismic data, the revised information, and the crosswell calibrated velocity model, wherein the crosswell calibrated velocity model is generated without using the first seismic data generated by the first perforation;\nrendering the located first microseismic event generated by the first stage of stimulation with respect to one or more dimensions of the anisotropic formation via a display;\nadjusting one or more parameters of a second stage of stimulation of the anisotropic formation based at least in part on the first microseismic event;\nreceiving second seismic data responsive to the second stage of stimulation of the anisotropic formation via a second perforation in the first toe portion of the first well disposed in the anisotropic formation, wherein the second seismic data comprise seismic data received by the receiver array;\nlocating a second microseismic event generated by the second stage of stimulation using at least a portion of the received second seismic data and using the crosswell calibrated velocity model, wherein the crosswell calibrated velocity model is generated without using the second seismic data generated by the second perforation; and rendering the second microseismic event generated by the second stage of stimulation with respect to the one or more dimensions of the anisotropic formation via the display, and transmitting information from the first microseismic event and second microseismic event to control, adjust, or initiate one or more operations of equipment associated with the geologic environment.', '2.', 'The method of claim 1 comprising generating the shear (S) wave signals that span a depth range of the anisotropic formation.', '3.', 'The method of claim 2 wherein the generating comprises controlled triggering of at least one of the at least one controlled electric source in the first well or an offset well.', '4.', 'The method of claim 3 wherein the receiver array is in the offset well or the first well, respectively.', '5.', 'The method of claim 3 wherein the triggering occurs at a known time.', '6.', 'The method of claim 1 wherein the at least one controlled electric source comprises at least one piezoelectric source.', '7.', 'The method of claim 1 wherein the at least one controlled electric source comprises at least one directional source.', '8.', 'The method of claim 1 wherein at least one of the at least one controlled electric source comprises a planned emission frequency or range of frequencies.', '9.', 'The method of claim 1 wherein the crosswell calibrated velocity model comprises information based on at least one Thomsen parameter.', '10.', 'The method of claim 1 wherein the crosswell calibrated velocity model comprises a look-up table.', '11.', 'The method of claim 1 comprising locating a plurality of microseismic events serially.\n\n\n\n\n\n\n12.', 'The method of claim 1 comprising modeling at least one of the first stage of stimulation and the second stage of stimulation to generate at least one modeled fracture.\n\n\n\n\n\n\n13.', 'The method of claim 1 comprising selecting at least a portion of the compressional (P) wave signals and shear (S) wave signals that span the depth range of the anisotropic formation based on a shear criterion that accounts for shear signal quality of controlled source seismic energy received by the receiver array.', '14.', 'The method of claim 1 wherein the first and second controlled electric sources emit seismic energy at a frequency of 100 Hz to 2,000 Hz.\n\n\n\n\n\n\n15.', 'The method of claim 1 comprising generating the shear (S) wave signals that span a depth range of the anisotropic formation, wherein the generating comprises controlled triggering of at least one of the first controlled electric source and the second controlled electric source in an offset well.', '16.', 'The method of claim 1 comprising generating the shear (S) wave signals that span a depth range of the anisotropic formation, wherein the generating comprises controlled triggering of at least one of the first controlled electric source and the second controlled electric source in an offset well, and wherein the receiver array is in the first well.', '17.', 'The method of claim 1 wherein at least one of the first controlled electric source and the second controlled electric source is located on an upper surface of the geologic environment.', '18.', 'A system comprising: a processor; memory accessible by the processor;\nprocessor-executable instructions stored in the memory that comprise instructions to instruct the system to: receive a velocity model derived via compressional (P) wave signals versus depth in a geologic environment that comprises an anisotropic formation comprising one or more subsurface layers; receive compressional (P) wave signals and shear (S) wave signals that span a depth range of the anisotropic formation, wherein the compressional (P) wave signals and the shear (S) wave signals are generated using a first controlled electric source disposed in a first kickoff portion of a first well and a second controlled electric source disposed in a first toe portion of the first well, wherein the first well is drilled from a surface layer into the anisotropic formation to form a first bore, wherein the first bore comprises the first kickoff portion spanned from the surface layer to the anisotropic formation and connected to the first toe portion spanned along the one or more subsurface layers via a first heel portion, and wherein the compressional (P) wave signals and the shear (S) wave signals are acquired via a first receiver array disposed in a second toe portion and a second receiver array disposed in a second heel portion and a second kickoff portion of a second well, wherein the second well is drilled from the surface layer into the anisotropic formation to form a second bore, wherein the second bore comprises the second kickoff portion spanned from the surface layer to the anisotropic formation and connected to the second toe portion spanned along the one or more subsurface layers via the second heel portion; calibrate vertical and horizontal velocities of the velocity model using the compressional (P) wave signals and the shear (S) wave signals generated by the first controlled electric source and the second controlled electric source; generate a crosswell calibrated velocity model based on the calibrated vertical and horizontal velocities; receive first seismic data responsive to a first stage of stimulation of the anisotropic formation via a first perforation in the first toe portion of the first well disposed in the anisotropic formation, wherein the first seismic data comprise seismic data received by the receiver array; revise information stored in a look-up table based at least in part on the first seismic data; locate a first microseismic event generated by the first stage of stimulation using at least a portion of the received first seismic data, the revised information, and the crosswell calibrated velocity model, wherein the crosswell calibrated velocity model is generated without using the first seismic data generated by the first perforation; render the located first microseismic event generated by the first stage of stimulation with respect to one or more dimensions of the anisotropic formation via a display; adjust one or more parameters of a second stage of stimulation of the anisotropic formation based at least in part on the first microseismic event; receive second seismic data responsive to the second stage of stimulation of the anisotropic formation via a second perforation in the first toe portion of the first well disposed in the anisotropic formation, wherein the second seismic data comprise seismic data received by the receiver array; locate a second microseismic event generated by the second stage of stimulation using at least a portion of the received second seismic data and using the crosswell calibrated velocity model, wherein the crosswell calibrated velocity model is generated without using seismic data generated by the second perforation; and render the located second microseismic event generated by the second stage of stimulation with respect to the one or more dimensions of the anisotropic formation.', '19.', 'One or more non-transitory computer readable medium containing computer instructions stored therein for causing a computer processor to:\nreceive a velocity model derived via compressional (P) wave signals versus depth in a geologic environment that comprises an anisotropic formation comprising one or more subsurface layers;\nreceive compressional (P) wave signals and shear (S) wave signals that span a depth range of the anisotropic formation, wherein the compressional (P) wave signals and the shear (S) wave signals are generated using a first controlled electric source disposed in a first kickoff portion of a first well and a second controlled electric source disposed in a first toe portion of the first well, wherein the first well is drilled from a surface layer into the anisotropic formation to form a first bore, wherein the first bore comprises the first kickoff portion spanned from the surface layer to the anisotropic formation and connected to the first toe portion spanned along the one or more subsurface layers via a first heel portion, and wherein the compressional (P) wave signals and the shear (S) wave signals are acquired via a first receiver array disposed in a second toe portion and a second receiver array disposed in a second heel portion and a second kickoff portion of a second well, wherein the second well is drilled from the surface layer into the anisotropic formation to form a second bore, wherein the second bore comprises the second kickoff portion spanned from the surface layer to the anisotropic formation and connected to the second toe portion spanned along the one or more subsurface layers via the second heel portion;\ncalibrate vertical and horizontal velocities of the velocity model using the compressional (P) wave signals and the shear (S) wave signals generated by the first controlled electric source and the second controlled electric source;\ngenerate and store a crosswell calibrated velocity model based on the calibrated vertical and horizontal velocities;\nreceive first seismic data responsive to a first stage of stimulation of the anisotropic formation via a first perforation in the first toe portion of the first well disposed in the anisotropic formation, wherein the first seismic data comprise seismic data received by the receiver array;\nrevise information stored in a look-up table based at least in part on the first seismic data;\nlocate a first microseismic event generated by the first stage of stimulation using at least a portion of the received first seismic data, the revised information, and the crosswell calibrated velocity model, wherein the crosswell calibrated velocity model is generated without using seismic data generated by the first perforation;\nrender the located first microseismic event generated by the first stage of stimulation with respect to one or more dimensions of the anisotropic formation via a display; adjust one or more parameters of a second stage of stimulation of the anisotropic formation based at least in part on the first microseismic event;\nreceive second seismic data responsive to the second stage of stimulation of the anisotropic formation via a second perforation in the first toe portion of the first well disposed in the anisotropic formation, wherein the second seismic data comprise seismic data received by the receiver array;\nlocate a second microseismic event generated by the second stage of stimulation using at least a portion of the received second seismic data and using the crosswell calibrated velocity model, wherein the crosswell calibrated velocity model is generated without using seismic data generated by the second perforation;\nand render the located second microseismic event generated by the second stage of stimulation with respect to the one or more dimensions of the anisotropic formation via the display, and transmitting information from the first microseismic event and second microseismic event to control, adjust, or initiate one or more operations of equipment associated with the geologic environment.']

['FIG. 1 illustrates an example of a geologic environment and an example of a technique;; FIG. 2 illustrates examples of multiple reflections and examples of techniques;; FIG.', '3 illustrates examples of survey techniques;; FIG.', '4 illustrates an example of a portion of a method;; FIG.', '5 illustrates an example of a portion of the method of FIG. 4;; FIG.', '6 illustrates examples of techniques and equipment associated with microseismicity;; FIG.', '7 illustrates an example of a method, an example of a model and an example of a system;; FIG. 8 illustrates examples of plots;; FIG.', '9 illustrates an example of a plot;; FIG.', '10 illustrates examples of plots;; FIG.', '11 illustrates an example of a method; and; FIG.', '12 illustrates example components of a system and a networked system.; FIG.', '1 shows an example of a geologic environment 100 (e.g., an environment that includes a sedimentary basin, a reservoir 101, a fault 103, one or more fractures 109, etc.)', 'and an example of an acquisition technique 140 to acquire seismic data.', 'As an example, a system may process data acquired by the technique 140, for example, to allow for direct or indirect management of sensing, drilling, injecting, extracting, etc., with respect to the geologic environment 100.', 'In turn, further information about the geologic environment 100 may become available as feedback (e.g., optionally as input to the system).', 'As an example, an operation may pertain to a reservoir that exists in the geologic environment 100 such as, for example, the reservoir 101.', 'As an example, a technique may provide information (e.g., as an output) that may specifies one or more location coordinate of a feature in a geologic environment, one or more characteristics of a feature in a geologic environment, etc.; FIG. 1 also shows the geologic environment 100 as optionally including equipment 107 and 108 associated with a well that includes a substantially horizontal portion that may intersect with one or more of the one or more fractures 109.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 107 and/or 108 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, etc.; FIG. 1 also shows various types of waves as including P, SV an SH waves.', 'As an example, a P-wave may be an elastic body wave or sound wave in which particles oscillate in the direction the wave propagates.', 'As an example, P-waves incident on an interface (e.g., at other than normal incidence, etc.) may produce reflected and transmitted S-waves (e.g., “converted” waves).', 'As an example, an S-wave or shear wave may be an elastic body wave, for example, in which particles oscillate perpendicular to the direction in which the wave propagates.', 'S-waves may be generated by a seismic energy sources (e.g., other than an air gun).', 'As an example, S-waves may be converted to P-waves.', 'S-waves tend to travel more slowly than P-waves and do not travel through fluids that do not support shear.', 'In general, recording of S-waves involves use of one or more receivers operatively coupled to earth (e.g., capable of receiving shear forces with respect to time).', "As an example, interpretation of S-waves may allow for determination of rock properties such as fracture density and orientation, Poisson's ratio and rock type, for example, by crossplotting P-wave and S-wave velocities, and/or by other techniques.; FIG.", '2 shows an example of a technique 240, examples of signals 262 associated with the technique 240, examples of interbed multiple reflections 250 and examples of signals 264 and data 266 associated with the interbed multiple reflections 250.', 'As an example, the technique 240 may include emitting energy with respect to time where the energy may be represented in a frequency domain, for example, as a band of frequencies.', 'In such an example, the emitted energy may be a wavelet and, for example, referred to as a source wavelet which has a corresponding frequency spectrum (e.g., per a Fourier transform of the wavelet).', '; FIG.', '3 shows some examples of data acquisition techniques or “surveys” that include a zero-offset vertical seismic profile (VSP) technique 301, a deviated well vertical seismic profile technique 302, an offset vertical seismic profile technique 303 and a walkaway vertical seismic profile technique 304.', 'In each of the examples, a geologic environment 341 with a surface 349 is shown along with at least one energy source (e.g., a transmitter) 342 that may emit energy where the energy travels as waves that interact with the geologic environment 341.', 'As an example, the geologic environment 341 may include a bore 343 where one or more sensors (e.g., receivers) 344 may be positioned in the bore 343.', 'As an example, energy emitted by the energy source 342 may interact with a layer (e.g., a structure, an interface, etc.)', '345 in the geologic environment 341 such that a portion of the energy is reflected, which may then be sensed by at least one of the one or more of the sensors 344.', 'Such energy may be reflected as an upgoing primary wave (e.g., or “primary” or “singly” reflected wave).', 'As an example, a portion of emitted energy may be reflected by more than one structure in the geologic environment and referred to as a multiple reflected wave.; FIGS. 4 and 5 show an example of a method 400 that includes generating fractures.', 'As shown, the method 400 can include various operational blocks such as one or more of the blocks 401, 402, 403, 404, 405 and 406.', 'The block 401 may be a drilling block that includes drilling into a formation 410 that includes layers 412, 414 and 416 to form a bore 430 with a kickoff 432 to a portion defined by a heel 434 and a toe 436, for example, within the layer 414.; FIG.', '6 shows an example of a microseismic survey 610, which may be considered to be a method that implements equipment for sensing elastic wave emissions of microseismic events (e.g., elastic wave energy emissions caused directly or indirectly by a treatment).', 'As shown, the survey 610 is performed with respect to a geologic environment 611 that may include a reflector 613.', 'The survey 610 includes an injection bore 620 and a monitoring bore 630.', 'Fluid injected via the injection bore 620 generates a fracture 622 that is associated with microseismic events such as the event 624.', 'As shown in the example of FIG.', '6, energy of a microseismic event may travel through a portion of the geologic environment 611, optionally interacting with one or more reflectors 613, and pass to the monitoring bore 630 where at least a portion of the energy may be sensed via a sensing unit 634, which may include a shaker, three-component geophone accelerometers isolated from a sensing unit body (e.g., via springs, etc.), coupling contacts, etc.', 'In the example of FIG.', '6, the sensed energy includes compressional wave energy (P-wave) and shear wave energy (S-wave).', '; FIG.', '7 shows examples of method 710 and 730, an approximated example of a velocity model 745 and an example of a system 750.', 'As shown, the method 710 includes a reception block 712 for receiving crosswell shot data, an identification block 714 for identifying P-wave and S-wave arrivals (e.g., SH and/or SV), an identification block 716 for identifying time or times of one or more individual shots (e.g., which may be origin times that may be associated with controlled shots), a calibration block 718 for calibrating a velocity model (e.g., refining an initial velocity model), and a storage block 720 for storing information based at least in part on the calibrated velocity model.', 'As to the identification block 714 and the calibration block 718, a velocity model can provide for modeling of P and S velocities.; FIG.', '8 shows sets of example plots 810 (including a top view 812 along z direction and a side view 814 along y direction) and 830 (including a top view 832 along z direction and a side view 834 along y direction) for a geologic environment that includes a monitoring well 816 and a stimulation well 818 (e.g., a treatment well).', 'As shown, operations associated with the plots 810 include positioning one or more tools (e.g., 822h1, 822h2, and 822h3) in a horizontal portion 816H of the monitoring well 816 to acquire information associated with perforation shots 820h positioned along a horizontal section 818H of the stimulation well 818; whereas, operations associated with the plots 830 include positioning the one or more tools (e.g., 822h1, 822h2, and 822h3) in the horizontal section 816H and the one or more tools (e.g., 822v1, and 822v2) in a vertical section 816V of the monitoring well 816 to acquire information associated with crosswell shots 850h positioned along the horizontal section 818H and the crosswell shots 850v positioned along the vertical section 816V using a controlled crosswell shot source.', 'As indicated, the depth range as shown in the side view 814) of the operations in the plots 810 is about 300 ft (e.g., about 100 meters); whereas, the depth range as shown in the side view 844) of the operations in the plots 830 is about 1270 ft (e.g., about 400 meters).', '; FIG.', '9 shows an example plot 900 of an arrangement of a monitoring well 902 and a stimulation', 'well 906 (e.g., a treatment well) where a receiver array 904 is positioned in the monitoring well 902, where perforation locations 908 are indicated in the stimulation well 906 and where uncalibrated event locations (filled circles) and calibrated event locations (open circles) are shown.', 'In such an example, the calibrated event locations are calibrated using crosswell source information.', '; FIG.', '10 shows example plots 1010 and 1030 that allow for a comparison of crosswell source shot locations using an uncalibrated model (filled circles) and a model calibrated with crosswell sources (open circles).', 'Locations for the horizontal array as shown in the plot 1010 and the vertical array as shown in the plot 1030 demonstrated an improvement when calibrated using the crosswell sources.; FIG.', '11 shows an example of a method 1100 that includes a reception block 1102 for receiving crosswell seismic data associated with an anisotropic formation, a generation block 1104 for generating a calibrated crosswell velocity model and a storage block 1106 for storing calibrated crosswell velocity model information for the anisotropic formation.', 'In such an example, the crosswell seismic data can be acquired receivers (e.g., geophones) that sense emissions generated by controlled or controllable sources.', 'Such sources can be or include controlled or controllable direction sources.; FIG.', '12 shows components of an example of a computing system 1200 and an example of a networked system 1210.', 'The system 1200 includes one or more processors 1202, memory and/or storage components 1204, one or more input and/or output devices 1206 and a bus 1208.', 'In an example embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components 1204).', 'Such instructions may be read by one or more processors (e.g., the processor(s) 1202) via a communication bus (e.g., the bus 1208), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device 1206).', 'In an example embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc. (e.g., a computer-readable storage medium).']

US11828117

High-pressure drilling assembly

May 5, 2020

Eric Johnson, Phillip Bailey, Daniel Nobre, Nalin Weerasinghe

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent application PCT/US2020/031494 dated Aug. 20, 2020, 12 pages.; International Preliminary Report on Patentability issued in International Patent application PCT/US2020/031494, dated Nov. 18, 2021, 6 pages.; Extended Search Report issued in European Patent Application No. 20801890.3 dated Nov. 11, 2022, 8 pages.

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89011581; November 1989; WO; 2008136883; November 2008; WO; 2016137667; September 2016; WO

['A drilling assembly includes a hydraulic amplifier assembly, a driver, a bearing housing, and a shaft.', 'The hydraulic amplifier assembly is configured to increase a pressure of a drilling fluid so as to produce a pressurized drilling fluid.', 'The driver is driven by the pressure of the drilling fluid and is configured to rotate a drill bit.', 'The bearing housing is coupled to the driver.', 'The shaft extends through the bearing housing and is configured to be coupled to the drill bit.', 'The shaft is driven to rotate by the driver.', 'The hydraulic amplifier is configured to deliver the pressurized drilling fluid to the drill bit.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is the U.S. national phase of International Patent Application No. PCT/US2020/031494, filed May 5, 2020, and entitled “High-pressure Drilling Assembly,” which claims the benefit of, and priority to, U.S. Patent Application No. 62/843,653 filed on May 6, 2019, which is incorporated herein by this reference in its entirety.', 'BACKGROUND\n \nDrill bits are used to bore holes into the earth in order to reach a fluid, e.g., hydrocarbon, reservoir.', 'In a drilling assembly, the drill bit is positioned at the distal end of a drill string and rotated in order to advance into the rock formation.', 'Drilling mud is typically circulated through the drill string and out through the drill bit to remove cuttings, maintain a desired pressure and temperature in the well, etc.', 'A mud motor can be used to produce rotation of the drill bit that is localized at the distal end of the drill string, which allows for the creation of non-vertical sections of a well.', 'Mud motors typically rely on energy stored as pressure in the drilling mud, which the mud motors convert to mechanical rotational energy.', 'Further, other devices are sometimes used instead of mud motors in the bottom hole assembly, such as turbines, agitators, rotary steerable systems (RSS), to provide additional or alternative functionality to rotating the drill bit without rotating the entire drill string above the device.', 'Some rock formations can be difficult to drill through and can cause rapid wear of the drill bit as a consequence.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings.', 'In the figures:\n \nFIG.', '1\n illustrates a schematic view of an example of a wellsite system, according to an embodiment.\n \nFIG.', '2\n illustrates a side, cross-sectional view of a high-pressure drilling assembly, according to an embodiment.\n \nFIG.', '3\n illustrates a side, cross-sectional view of another high-pressure drilling assembly, according to an embodiment.\n \nFIG.', '4\n illustrates a side, cross-sectional view of another high-pressure drilling assembly, according to an embodiment.\n \nFIG.', '5\n illustrates a side, cross-sectional view of another high-pressure drilling assembly, according to an embodiment.', 'DETAILED DESCRIPTION\n \nReference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures.', 'In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention.', 'However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details.', 'In other instances, well-known methods, procedures, components, circuits and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms are only used to distinguish one element from another.', 'For example, a first object could be termed a second object, and, similarly, a second object could be termed a first object, without departing from the scope of the invention.', 'The first object and the second object are both objects, respectively, but they are not to be considered the same object.', 'The terminology used in the description of the invention herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention.', 'As used in the description of the invention and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will also be understood that the term “and/or” as used herein refers to and encompasses any possible combinations of one or more of the associated listed items.', 'It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.', 'Attention is now directed to processing procedures, methods, techniques and workflows that are in accordance with some embodiments.', 'Some operations in the processing procedures, methods, techniques and workflows disclosed herein may be combined and/or the order of some operations may be changed.\n \nFIG.', '1\n illustrates a wellsite system according to an embodiment.', 'The wellsite can be onshore or offshore.', 'In this example system, a borehole is formed in subsurface formations by rotary drilling in a manner that is well known.', 'A drill string \n125\n is suspended within a borehole \n136\n and has a bottom hole assembly (BHA) \n140\n which includes a drill bit \n146\n at its lower end.', 'A surface system \n120\n includes platform and derrick assembly positioned over the borehole \n136\n, the assembly including a rotary table \n124\n, kelly (not shown), hook \n121\n, and rotary swivel \n122\n.', 'The drill string \n125\n is rotated by the rotary table \n124\n energized by means not shown, which engages the kelly (not shown) at the upper end of the drill string \n125\n.', 'The drill string \n125\n is suspended from the hook \n121\n, attached to a traveling block (also not shown), through the kelly (not shown) and the rotary swivel \n122\n which permits rotation of the drill string \n125\n relative to the hook \n121\n.', 'As is well known, a top drive system could be used instead of the rotary table system shown in \nFIG.', '1\n.', 'In the illustrated example, the surface system further includes drilling fluid or mud \n132\n stored in a pit \n131\n formed at the well site.', 'A pump \n133\n delivers the drilling fluid to the interior of the drill string \n125\n via a port (not shown) in the swivel \n122\n, causing the drilling fluid to flow downwardly through the drill string \n125\n as indicated by the directional arrow \n134\n.', 'The drilling fluid exits the drill string via ports (not shown) in the drill bit \n146\n, and then circulates upwardly through an annulus region \n135\n between the outside of the drill string \n125\n and the wall of the borehole \n136\n, as indicated by the directional arrows \n135\n and \n135\nA.', 'In this manner, the drilling fluid lubricates the drill bit \n146\n and carries formation cuttings up to the surface as it is returned to the pit \n131\n for recirculation.', 'The BHA \n140\n of the illustrated embodiment may include a measuring-while-drilling (MWD) tool \n141\n, a logging-while-drilling (LWD) tool \n144\n, a rotary steerable directional drilling system \n145\n and motor, and the drill bit \n146\n.', 'It will also be understood that more than one LWD tool and/or MWD tool can be employed, e.g. as represented at \n143\n.', 'Furthermore, a mud motor may be provided in lieu of the rotary steerable drilling system \n145\n.', 'The LWD tool \n144\n is housed in a special type of drill collar, as is known in the art, and can contain one or a plurality of known types of logging tools.', 'The LWD tool \n144\n may include capabilities for measuring, processing, and storing information, as well as for communicating with the surface equipment.', 'In the present example, the LWD tool \n144\n may any one or more well logging instruments known in the art, including, without limitation, electrical resistivity, acoustic velocity or slowness, neutron porosity, gamma-gamma density, neutron activation spectroscopy, nuclear magnetic resonance and natural gamma emission spectroscopy.', 'The MWD tool \n141\n is also housed in a special type of drill collar, as is known in the art, and can contain one or more devices for measuring characteristics of the drill string and drill bit.', 'The MWD tool \n141\n further includes an apparatus \n142\n for generating electrical power to the downhole system.', 'This may typically include a mud turbine generator powered by the flow of the drilling fluid, it being understood that other power and/or battery systems may be employed.', 'In the present embodiment, the MWD tool \n141\n may include one or more of the following types of measuring devices: a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device.', 'The power generating apparatus \n142\n may also include a drilling fluid flow modulator for communicating measurement and/or tool condition signals to the surface for detection and interpretation by a logging and control unit (e.g., a “controller”) \n126\n.', 'As discussed herein, the BHA \n140\n may have a hydraulic amplifier assembly \n202\n.', 'The hydraulic amplifier assembly \n202\n may be configured to increase a pressure of at least a portion of the drilling fluid that is received through the drill string and provided to the assembly \n200\n.', 'Although the hydraulic amplifier assembly \n202\n is illustrated in \nFIG.', '1\n as coupled to the drill bit \n146\n, it is appreciated that the embodiments below describe various arrangements of the BHA \n140\n with the hydraulic amplifier assembly \n202\n in different positions within the BHA \n140\n.', 'The hydraulic amplifier assembly \n202\n increases the pressure of a portion of the drilling fluid downhole to pressures above about 650 bar, 2500 bar, 3500 bar, or 4500 bar, thereby reducing the components of the drill string that convey the pressurized drilling fluid to the drill bit.', 'Through reducing the quantity of components and the length of lines conveying the pressurized drilling fluid to the drill bit, wear from the pressurized drilling fluid through the drill string may be reduced.', 'Additionally, pressurizing a portion of the drilling fluid above a base pressure of the remainder may facilitate use of the remainder of the drilling fluid for other purposes (e.g., tool activation, hole cleaning) with reduced or eliminated modifications to other components of the BHA \n140\n.\n \nFIG.', '2\n illustrates a simplified, side, cross-sectional view of a high pressure drilling assembly \n200\n, according to an embodiment.', 'The assembly \n200\n may generally include a hydraulic amplifier assembly \n202\n, a top sub \n204\n, a driver \n206\n, a transmission section \n208\n, a bearing assembly \n210\n, and a shaft \n212\n.', 'As shown, the hydraulic amplifier assembly \n202\n may be directly coupled to an uphole end of the top sub \n204\n, which is in turn uphole of the driver \n206\n, although this is merely one example of the position of this assembly \n202\n among many contemplated herein, and several other examples are described below.', 'The hydraulic amplifier assembly \n202\n may be configured to increase a pressure of a portion of the drilling fluid that is received through the drill string to the assembly \n200\n.', 'For example, the hydraulic amplifier assembly \n202\n may include a hydraulic-over-hydraulic, master-slave cylinders.', 'As such, fluid pressure may be used to drive a relatively large, master cylinder, which may drive a relatively small, slave cylinder that increases the pressure in a portion of the drilling fluid.', 'The pressurized drilling fluid is routed through the assembly \n200\n and delivered to a drill bit coupled to the downhole end of the shaft \n212\n.', 'The pressurized drilling fluid may be delivered at a pressure sufficient to water-jet cut a rock formation in which the drill bit is located.', 'For example, the pressurized drilling fluid may be delivered at a pressure of from about 650 bar, about 1300 bar, about 2000 bar to about 2500 bar, about 3500 bar, or about 4500 bar.', 'The pressurized drilling fluid may be routed from the hydraulic amplifier assembly \n202\n through the remainder of the assembly \n200\n, in one or more of several manners.', 'For example, as indicated by lines in \nFIG.', '2\n, the fluid may be routed through a line \n218\n (e.g., high pressure tubing or pipe) extending along the centerline of the top sub \n204\n.', 'In the illustrated embodiment, the driver \n206\n is a mud motor, but in other embodiments, the driver \n206\n may be a rotary steerable system (RSS), turbine, agitator, combinations thereof, etc.', 'In the illustrated mud-motor embodiment, the driver \n206\n includes a rotor \n220\n and a stator \n222\n.', 'The rotor \n220\n is rotatable relative to the stator \n222\n, as well as relative to the top sub \n204\n, by converting pressure from the drilling fluid flowing therethrough into rotation.', 'Accordingly, the line \n218\n may extend through the rotor \n220\n, and may include a hydraulic coupling \n214\n to connect the portion of the line \n218\n in the stationary top sub \n204\n with the portion of the line \n218\n in the rotating rotor \n220\n.', 'The line \n218\n may extend through a drive shaft \n216\n (e.g., including universal coupling(s)) of the transmission section \n208\n, and through the shaft \n212\n extending through the bearing housing \n210\n.', 'The shaft \n212\n may be connected to the drill bit (not shown), and thus the line \n218\n may be configured to feed the drilling fluid that is pressurized in the hydraulic amplifier assembly \n202\n to the drill bit from within the shaft \n212\n.', 'In turn, the drill bit may include nozzles that direct the pressurized drilling fluid into the rock formation.', 'In another embodiment, as also depicted in \nFIG.', '2\n, a line \n230\n may extend from the hydraulic amplifier assembly \n202\n through the remainder of the high-pressure drilling assembly \n200\n.', 'The line \n230\n may initially extend through the outer wall \n224\n of the top sub \n204\n, and through the stator \n222\n of the driver \n206\n.', 'The line \n230\n may then turn radially inwards from an outer wall \n226\n of the transmission section \n208\n, e.g., at the bearing housing \n210\n, and proceed through an internal wall of the shaft \n212\n.', 'For example, a keyway slot may be formed in the outside surface of the top sub \n204\n and the driver \n206\n, and a tubing or pipe positioned therein or a cover formed thereon to provide the conduit.', 'In another embodiment, in the driver \n206\n, the line \n230\n may extend through the rubber of the stator \n222\n, be formed as a gunhole through the stator \n222\n, or the like.', 'Where the line \n230\n turns radially inwards at the bearing housing \n210\n, the line \n230\n may, like the line \n218\n, include a hydraulic coupling that allows the line \n218\n to extend from a relatively stationary structure (the stator \n222\n) to a relatively rotating structure (the shaft \n212\n).\n \nFIG.', '3\n illustrate a simplified, side, cross-sectional view of another high-pressure drilling assembly \n300\n, according to an embodiment.', 'The high-pressure drilling assembly \n300\n may be similar to the assembly \n200\n, except that the hydraulic amplifier assembly \n202\n is positioned at the downhole end of the shaft \n212\n, interposed between the shaft \n212\n and the drill bit.', 'In some embodiments, the hydraulic amplifier assembly \n202\n is directly coupled to the drill bit \n146\n.', 'As such, the hydraulic amplifier assembly \n202\n may deliver pressurized drilling fluid directly to the drill bit, with the pressurized fluid line \n218\n and/or \n230\n being internal to the hydraulic amplifier assembly \n202\n.\n \nFIG.', '4\n illustrates a simplified, side, cross-sectional view of another high-pressure drilling assembly \n400\n, according to an embodiment.', 'The high-pressure drilling assembly \n400\n may be similar to the assembly \n200\n, except that the hydraulic amplifier assembly \n202\n is not directly coupled to the uphole end of the top sub \n204\n, but rather is integrated with the driver \n206\n.', 'The high-pressure drilling assembly \n400\n may include the line \n218\n or the line \n230\n in order to deliver pressurized fluid through a portion of the drilling assembly \n400\n to the drill bit.', 'Accordingly, in this example, rather than directly converting pressure of a portion of drilling fluid into energy to pressurize another portion of the drilling fluid, the hydraulic amplifier assembly \n202\n may be powered mechanically via a shaft \n402\n connected to the rotor \n220\n of the driver \n206\n.', 'Thus, the rotor \n220\n rotating may be configured, in addition to rotating the drill bit, to drive the hydraulic amplifier assembly \n202\n to increase the pressure in the drilling fluid that is routed through line \n218\n or line \n230\n.', 'The line \n218\n may, for example, extend through the shaft \n402\n.', 'In another embodiment, the hydraulic amplifier assembly \n202\n may use pressure in a portion of the drilling fluid to increase the pressure of the drilling fluid delivered through the line \n218\n or \n230\n, similar to the high-pressure drilling assembly \n200\n of \nFIG.', '2\n.', 'FIG.', '5\n illustrates a simplified, side, cross-sectional view of another high-pressure drilling assembly \n500\n, according to an embodiment.', 'The high-pressure drilling assembly \n500\n may be similar to the assembly \n200\n, except that the hydraulic amplifier assembly \n202\n is not directly coupled to the uphole end of the top sub \n204\n, but rather is integrated with the driver \n206\n and positioned downhole thereof.', 'The assembly \n500\n may include the line \n218\n or the line \n230\n in order to deliver pressurized fluid through a portion of the drilling assembly \n500\n to the drill bit.', 'The hydraulic amplifier assembly \n202\n may be positioned in either of two general locations, as depicted and labeled as \n202\nA, \n202\nB, respectively.', 'For example, the hydraulic amplifier assembly \n202\nA may be positioned between the driver \n206\n and the transmission section \n208\n, and/or the hydraulic amplifier assembly \n202\nB may be positioned in or coupled to the bearing assembly \n210\n.', 'As both of these locations may be rotated by the driver \n206\n, the hydraulic amplifier assembly \n202\n may operate using the rotational energy to pressurize the drilling fluid in the line \n218\n or \n230\n, as mentioned above, or the drilling fluid in the line \n218\n or \n230\n may be pressurized using the pressure in the remaining drilling fluid.', 'Furthermore, in the embodiment in which the hydraulic amplifier assembly \n202\n is located in the bearing housing \n210\n, the lines \n218\n or \n230\n may omit hydraulic couplings, as the location of the hydraulic amplifier assembly \n202\n is in a rotating structure.', 'Similarly, in an embodiment in which the hydraulic amplifier assembly \n202\n is between the transmission section \n208\n and the driver \n206\n and the line \n218\n is employed, the line \n218\n may likewise omit hydraulic couplings \n214\n shown in \nFIG. \n2\n.', 'The foregoing description, for purpose of explanation, references specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or to limit the invention to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'Moreover, the order in which the elements of the methods are illustrated and described may be re-arranged, and/or two or more elements may occur simultaneously.', 'The embodiments were chosen and described in order to best explain the principals of the invention and its practical applications, to thereby enable others skilled in the art to best utilize the invention and various embodiments with various modifications as are suited to the particular use contemplated.']

['1.', 'A drilling assembly, comprising:\na hydraulic amplifier assembly configured to increase a pressure of a drilling fluid so as to produce a pressurized drilling fluid;\na driver that is driven by the pressure of the drilling fluid and configured to rotate a drill bit;\na bearing housing coupled to the driver; and\na shaft extending through the bearing housing and configured to be coupled to the drill bit, wherein the shaft is driven to rotate by the driver,\nwherein the hydraulic amplifier assembly is configured to deliver the pressurized drilling fluid to the drill bit, and\nwherein the hydraulic amplifier assembly is coupled to the driver, such that the driver is configured to drive the hydraulic amplifier assembly.', '2.', 'The drilling assembly of claim 1, wherein the hydraulic amplifier assembly is positioned uphole of the driver, the drilling assembly further comprising a line extending from the hydraulic amplifier assembly, through the driver, through the bearing housing, and through the shaft, wherein the line is configured to conduct the pressurized fluid from the hydraulic amplifier assembly to the drill bit.\n\n\n\n\n\n\n3.', 'The drilling assembly of claim 2, wherein the line extends along a centerline of the driver and through a rotor of the driver.', '4.', 'The drilling assembly of claim 2, wherein the line extends through a stator of the driver, radially inward to the shaft, and within the shaft.', '5.', 'The drilling assembly of claim 1, wherein the hydraulic amplifier assembly is positioned downhole of the driver.', '6.', 'The drilling assembly of claim 5, further comprising a transmission section extending between the driver and the shaft, wherein the hydraulic amplifier assembly is positioned between the driver and the transmission section.', '7.', 'The drilling assembly of claim 5, wherein the hydraulic amplifier assembly is coupled to the bearing housing.', '8.', 'The drilling assembly of claim 1, wherein the pressurized drilling fluid is delivered to the drill bit above 650 bar.', '9.', 'The drilling assembly of claim 1, wherein the pressurized drilling fluid is delivered to the drill bit above 2500 bar.', '10.', 'A method of delivering a pressurized drilling fluid to a drill bit comprising:\ndirecting a drilling fluid through a driver configured to rotate a shaft;\nrotating the drill bit coupled to the shaft;\nproviding a portion of the drilling fluid to a hydraulic amplifier assembly configured to increase a pressure of the portion of the drilling fluid above 650 bar;\ndriving the hydraulic amplifier assembly via the driver; and\ndelivering the pressurized drilling fluid to the drill bit.', '11.', 'The method of claim 10, wherein delivering the pressurized drilling fluid to the drill bit comprises routing the pressurized drilling fluid through the driver.', '12.', 'The method of claim 11, wherein delivering the pressurized drilling fluid to the drill bit further comprises routing the pressurized drilling fluid through the shaft.', '13.', 'The method of claim 10, wherein the hydraulic amplifier assembly is positioned downhole of the driver.', '14.', 'The method of claim 10, wherein the hydraulic amplifier assembly is positioned uphole of the driver.', '15.', 'The method of claim 10, wherein the driver includes a rotor and a stator.', '16.', 'A method of delivering a pressurized drilling fluid to a drill bit comprising:\ndirecting a drilling fluid through a driver configured to rotate a shaft;\nrotating the drill bit coupled to the shaft;\nproviding a portion of the drilling fluid to a hydraulic amplifier assembly configured to increase a pressure of the portion of the drilling fluid above 650 bar; and\ndelivering the pressurized drilling fluid to the drill bit, wherein delivering the pressurized drilling fluid to the drill bit comprises routing the pressurized drilling fluid through the driver.', '17.', 'The method of claim 16, wherein the hydraulic amplifier assembly is positioned downhole of the driver.', '18.', 'The method of claim 16, wherein the hydraulic amplifier assembly is positioned uphole of the driver.', '19.', 'The method of claim 16, wherein delivering the pressurized drilling fluid to the drill bit further comprises routing the pressurized drilling fluid through the shaft.', '20.', 'The method of claim 16, wherein the hydraulic amplifier assembly is coupled to the drill bit.']

['FIG. 1 illustrates a schematic view of an example of a wellsite system, according to an embodiment.; FIG.', '2 illustrates a side, cross-sectional view of a high-pressure drilling assembly, according to an embodiment.; FIG.', '3 illustrates a side, cross-sectional view of another high-pressure drilling assembly, according to an embodiment.; FIG.', '4 illustrates a side, cross-sectional view of another high-pressure drilling assembly, according to an embodiment.; FIG.', '5 illustrates a side, cross-sectional view of another high-pressure drilling assembly, according to an embodiment.; FIG.', '1 illustrates a wellsite system according to an embodiment.', 'The wellsite can be onshore or offshore.', 'In this example system, a borehole is formed in subsurface formations by rotary drilling in a manner that is well known.', 'A drill string 125 is suspended within a borehole 136 and has a bottom hole assembly (BHA) 140 which includes a drill bit 146 at its lower end.', 'A surface system 120 includes platform and derrick assembly positioned over the borehole 136, the assembly including a rotary table 124, kelly (not shown), hook 121, and rotary swivel 122.', 'The drill string 125 is rotated by the rotary table 124 energized by means not shown, which engages the kelly (not shown) at the upper end of the drill string 125.', 'The drill string 125 is suspended from the hook 121, attached to a traveling block (also not shown), through the kelly (not shown) and the rotary swivel 122 which permits rotation of the drill string 125 relative to the hook 121.', 'As is well known, a top drive system could be used instead of the rotary table system shown in FIG.', '1.; FIG. 2 illustrates a simplified, side, cross-sectional view of a high pressure drilling assembly 200, according to an embodiment.', 'The assembly 200 may generally include a hydraulic amplifier assembly 202, a top sub 204, a driver 206, a transmission section 208, a bearing assembly 210, and a shaft 212.', 'As shown, the hydraulic amplifier assembly 202 may be directly coupled to an uphole end of the top sub 204, which is in turn uphole of the driver 206, although this is merely one example of the position of this assembly 202 among many contemplated herein, and several other examples are described below.', '; FIG.', '3 illustrate a simplified, side, cross-sectional view of another high-pressure drilling assembly 300, according to an embodiment.', 'The high-pressure drilling assembly 300 may be similar to the assembly 200, except that the hydraulic amplifier assembly 202 is positioned at the downhole end of the shaft 212, interposed between the shaft 212 and the drill bit.', 'In some embodiments, the hydraulic amplifier assembly 202 is directly coupled to the drill bit 146.', 'As such, the hydraulic amplifier assembly 202 may deliver pressurized drilling fluid directly to the drill bit, with the pressurized fluid line 218 and/or 230 being internal to the hydraulic amplifier assembly 202.; FIG.', '4 illustrates a simplified, side, cross-sectional view of another high-pressure drilling assembly 400, according to an embodiment.', 'The high-pressure drilling assembly 400 may be similar to the assembly 200, except that the hydraulic amplifier assembly 202 is not directly coupled to the uphole end of the top sub 204, but rather is integrated with the driver 206.', 'The high-pressure drilling assembly 400 may include the line 218 or the line 230 in order to deliver pressurized fluid through a portion of the drilling assembly 400 to the drill bit.', 'Accordingly, in this example, rather than directly converting pressure of a portion of drilling fluid into energy to pressurize another portion of the drilling fluid, the hydraulic amplifier assembly 202 may be powered mechanically via a shaft 402 connected to the rotor 220 of the driver 206.', 'Thus, the rotor 220 rotating may be configured, in addition to rotating the drill bit, to drive the hydraulic amplifier assembly 202 to increase the pressure in the drilling fluid that is routed through line 218 or line 230.', 'The line 218 may, for example, extend through the shaft 402.', 'In another embodiment, the hydraulic amplifier assembly 202 may use pressure in a portion of the drilling fluid to increase the pressure of the drilling fluid delivered through the line 218 or 230, similar to the high-pressure drilling assembly 200 of FIG.', '2.; FIG.', '5 illustrates a simplified, side, cross-sectional view of another high-pressure drilling assembly 500, according to an embodiment.', 'The high-pressure drilling assembly 500 may be similar to the assembly 200, except that the hydraulic amplifier assembly 202 is not directly coupled to the uphole end of the top sub 204, but rather is integrated with the driver 206 and positioned downhole thereof.', 'The assembly 500 may include the line 218 or the line 230 in order to deliver pressurized fluid through a portion of the drilling assembly 500 to the drill bit.']

US11918942

In process screen parameter measurement and control

Oct 31, 2018

Chase Cox, Michael Victor Robbins, Jared Joseph Stackman, Luis Porras, Jiawei Dong

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in the PCT Application PCT/US2018/058353, dated Apr. 17, 2019 (10 pages).; International Preliminary Report on Patentabitlity issued in the PCT Application PCT/US2018/058353, dated May 14, 2020 (7 pages).; First Office Action issued in Chinese Patent Application No. 201880073351.1 dated Jun. 29, 2021, 15 pages with English translation.

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['A technique facilitates construction of a wire-wrapped screen.', 'A wrapping machine is operated with a sensor, e.g. a camera, positioned adjacent the wrapping machine while wire is wrapped to create the wire-wrapped screen.', 'The sensor is used to obtain data on at least one parameter of the wire-wrapped screen during creation of the wire-wrapped screen.', 'Data is provided to a controller in communication with the wrapping machine to improve the quality of the wire-wrapped screen.', 'For example, data from the images obtained via the camera may be provided to the controller which is configured to determine slot width as the wire is wrapped.', 'The controller is then able to provide feedback in real time to the wrapping machine so as to adjust the wrapping machine for maintaining a desired slot width.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'The present document is a National Stage Entry of International Application No. PCT/US2018/058353, filed Oct. 31, 2018, which is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/579,451, filed Oct. 31, 2017, which is incorporated herein by reference in its entirety.', 'BACKGROUND', 'In a variety of well applications, well completion tools are installed in a well for production of oil and gas.', 'The well completion tools may be positioned along a tubing string having a series of tubulars with various tools including screens, valves, actuators, and/or other tools installed to perform operations related to the production of fluids from a formation.', 'However, the flowing formation fluid may carry undesirable components, e.g. sand and other particulates, at extreme pressures and this can cause erosion of the tools positioned along the tubing string.', 'Sand screens may be installed along the tubing string and may be combined with gravel packs to help prevent the inflow of sand from the formation while maintaining efficient production of formation fluid, e.g. oil and gas.', 'The sand screen may comprise a wire wrapped filter manufactured by wrapping wire in a helical fashion around a base pipe having longitudinal rib wires spaced along the exterior surface of the base pipe.', 'The helically wrapped wire is welded to the rib wires to secure the wires in place.', 'The spacing between sequential helical wraps of the wire effectively forms a continuous slot through which hydrocarbons may flow as the particulates are filtered out and deposited in the surrounding annulus region.', 'The slot width determines the size of particles filtered from the inflowing fluid.', 'However, many difficulties can arise in maintaining a desired slot width during the screen manufacturing process.', 'SUMMARY', 'In general, a methodology and system facilitate construction of a wire-wrapped screen.', 'A wrapping machine is operated with a sensor, e.g. a camera, positioned adjacent the wrapping machine while wire is wrapped to create the wire-wrapped screen.', 'The sensor is used to obtain data on at least one parameter of the wire-wrapped screen during creation of the wire-wrapped screen.', 'For example, a camera may be utilized in capturing images of the wire-wrapped screen as wire is wrapped about a base pipe.', 'Data is provided to a controller in communication with the wrapping machine to improve the quality of the wire-wrapped screen.', 'For example, data from the images obtained via the camera may be provided to the controller which is configured to determine slot width as the wire is wrapped.', 'The controller is then able to provide feedback in real time to the wrapping machine so as to adjust operational parameters of the wrapping machine for maintaining a desired slot width.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is a schematic cross-sectional illustration of an example of a wire-wrapped screen which may be used to filter particulates during production of hydrocarbon fluid, according to an embodiment of the disclosure;\n \nFIG.', '2\n is a schematic side view of the wire-wrapped screen illustrated in \nFIG.', '1\n, according to an embodiment of the disclosure;\n \nFIG.', '3\n is a close-up illustration of wrapped wire and the resulting slot located between wraps of the wire during construction of a wire-wrapped screen, according to an embodiment of the disclosure;\n \nFIG.', '4\n is a schematic illustration of an example of a feedback system utilized during manufacture of the wire-wrapped screen, according to an embodiment of the disclosure;\n \nFIG.', '5\n is a schematic illustration of another example of a feedback system utilized during manufacture of the wire-wrapped screen, according to an embodiment of the disclosure;\n \nFIG.', '6\n is an illustration of an example of a slot width measurement chart, according to an embodiment of the disclosure;\n \nFIG.', '7\n is a diagrammatic illustration of a feedback control implemented via the feedback system during manufacture of the wire-wrapped screen, according to an embodiment of the disclosure;\n \nFIG.', '8\n is a flow chart illustrating an example of a flow diagram for operation of a feedback system during manufacture of a wire-wrapped screen, according to an embodiment of the disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'The present disclosure generally relates to a well methodology and system which facilitate construction of high quality, wire-wrapped screens.', 'According to an embodiment, a wrapping machine is operated with a sensor positioned adjacent the wrapping machine while wire is wrapped to create the wire-wrapped screen.', 'The sensor is used to obtain data on at least one parameter of the wire-wrapped screen during creation of the wire-wrapped screen.', 'The data is then processed so as to enable adjustment of the wrapping machine to improve the quality of the wire-wrapped screen.', 'The data may be used in real time.', 'In one example, the sensor is in the form of a camera.', 'The camera may be utilized in capturing images of the wire-wrapped screen as wire is wrapped about a base pipe.', 'Data from the images obtained via the camera may be provided to a controller which is configured to determine slot width between wraps of the wire as the wire is wrapped about the base pipe, e.g. a ribbed base pipe.', 'The controller is then able to provide feedback in real time to the wrapping machine so as to adjust operational parameters of the wrapping machine for maintaining a desired slot width.', 'Maintenance of the desired slot width along the screen enhances the ability of the wire-wrapped screen to filter particulates of a desired size from inflowing fluid during, for example, hydrocarbon fluid production.', 'Referring generally to \nFIGS.', '1\n and \n2\n, an embodiment of a sand screen \n30\n is illustrated in a cross-sectional view and a side view, respectively.', 'In this example, the sand screen \n30\n comprises a base pipe \n32\n, rib wires \n34\n, and an outer wire wrap \n36\n formed by a wire \n38\n wrapped around the rib wires \n34\n.', 'By way of example, the wire \n38\n may be helically wrapped around the rib wires \n34\n and the base pipe \n32\n to create the wire wrap \n36\n as illustrated in \nFIG.', '2\n.', 'The sand screen \n30\n may be manufactured using industry-standard materials and sizes or other suitable materials and sizes.', 'For a variety of applications, the base pipe \n32\n, rib wires \n34\n, and wire wrap \n36\n may be constructed in suitable sizes—with dimensions and materials conventionally used in the manufacture of sand screens.', 'The sand screen \n30\n may be manufactured via a wrapping machine \n40\n, such as a variety of commercially available wrapping machines.', 'Commercial wrapping machines are manufactured and/or sold by a variety of companies, including Schlumberger and ARC Specialties Inc.\n \nA suitable manufacturing process may include initially obtaining a base pipe \n32\n of a suitable length and attaching the rib wires \n34\n to the base pipe \n32\n in a longitudinal direction.', 'The rib wires \n34\n may be attached to the base pipe \n32\n by welding, fusing, or other suitable attachment techniques.', 'In some embodiments, a pulsing current may be used to weld or fuse the material in a non-additive manner.', 'Once the rib wires \n34\n are secured to the base pipe \n32\n, the ribbed base pipe is passed through the wrapping machine \n40\n which wraps the wire \n38\n around the rib wires \n34\n and base pipe \n32\n.', 'During wrapping, the base pipe \n32\n may be rotated about its longitudinal axis as it undergoes relative lengthwise movement through the wrapping machine \n40\n.', 'For example, the base pipe \n32\n may be rotated as the wrapping machine \n40\n moves lengthwise along the base pipe \n32\n or as the base pipe \n32\n is moved lengthwise through a stationary wrapping machine \n40\n.', 'The wire \n38\n is wrapped about the rib wires \n34\n and the base pipe \n32\n as the base pipe \n32\n rotates and moves linearly with respect to the wrapping machine \n40\n so as to create a filter \n42\n via the wire wrap \n36\n.', 'The filter \n42\n is able to filter out particulates from inflowing fluid during, for example, a hydrocarbon production operation.', 'It should be noted the base pipe \n32\n may be perforated or have another type of inflow control opening or openings to enable flow of fluid from the exterior of the wire wrap \n36\n to the interior of the base pipe \n32\n.', 'When the wire \n38\n is wrapped via the wrapping machine \n40\n, the wire \n38\n may be welded, fused, or otherwise attached to the rib wires \n34\n to secure the wire \n38\n in place.', 'For example, the wire \n38\n may be secured to the rib wires \n34\n as it is wrapped onto the ribbed base pipe (rib wires \n34\n and base pipe \n32\n) in a helical pattern.', 'With additional reference to \nFIG.', '3\n, a close up view of the wrapped wire \n38\n is provided to show a slot \n44\n between each successive wrap of the wire \n38\n.', 'Although the slot \n44\n may be a continuous slot, \nFIG.', '3\n shows that the slot \n44\n functions effectively as a plurality of slots located between the successive wraps of wire \n38\n.', 'The quality of the filter \n42\n provided by the wire wrap \n36\n is determined by the consistency and quality of the slot \n44\n.', 'In the example illustrated in \nFIGS.', '1\n-\n3\n, the width of slot \n44\n has been accurately controlled via a feedback system as discussed in greater detail below.', 'Generally, the more consistent the width \n46\n of slot \n44\n and the more closely the slot width \n46\n is maintained within a desired range of widths or distribution of widths, the higher the quality of the slot \n44\n and overall sand screen \n30\n.', 'Referring generally to \nFIG.', '4\n, an example of a feedback system \n48\n is illustrated.', 'The feedback system \n48\n may be positioned adjacent to the wrapping machine \n40\n where the wraps of wire \n38\n are applied over the rib wires \n34\n.', 'In some embodiments, the feedback system \n48\n may be attached to or integral with the wrapping machine \n40\n.', 'The feedback system \n48\n may be configured to monitor at least one parameter with respect to construction of the sand screen \n30\n.', 'For example, the feedback system \n48\n may be used to monitor slot width \n46\n as the wire \n38\n is wrapped about the rib wires \n34\n and base pipe \n32\n.', 'The feedback system \n48\n utilizes data acquired on the at least one parameter and provides corresponding instructions to the wrapping machine \n40\n so as to adjust operation of the wrapping machine.', 'As illustrated in \nFIG.', '4\n, the feedback system \n48\n may comprise a sensor \n50\n located adjacent the wrapping machine \n40\n.', 'The sensor \n50\n may be selected to monitor at least one parameter with respect to positioning of the wire \n38\n as it is wrapped about the ribbed base pipe.', 'The sensor \n50\n may comprise an individual sensor or a plurality of sensors positioned at a predetermined distance \n52\n from the wire \n38\n which has been wrapped about the rib wires \n34\n and base pipe \n32\n.', 'The feedback system \n48\n further comprises a controller \n54\n, e.g. a computer-based controller, programmed with logic to determine deviations of the at least one parameter from, for example, a reference parameter.', 'The controller \n54\n is in communication with the wrapping machine \n40\n so as to provide instructions to the wrapping machine \n40\n to ensure proper placement of the wire \n38\n.', 'In some embodiments, the controller \n54\n may be configured to provide instructions to wrapping machine \n40\n in real time so as to cause real-time adjustments based on deviations of the at least one parameter from the reference parameter.', 'Real-time adjustment of the wrapping process improves the quality of the wire-wrapped sand screen \n30\n and reduces costs otherwise associated with post-manufacture treatment.', 'According to an embodiment, the feedback system \n48\n is configured to obtain raw data measured from the wraps of wire \n38\n and/or additional data to enable determination of adjustment parameters.', 'The adjustment parameters may be provided to wrapping machine \n40\n so as to modify the manner in which the wraps of wire \n38\n are being applied over the rib wires \n34\n.', 'For example, the feedback system \n48\n may provide instructions to wrapping machine \n40\n with respect to pitch adjustment during wrapping of wire \n38\n.', 'The pitch adjustment instructions may be provided as a percentage or degree adjustment to be made with respect to the pitch of the wire \n38\n as it is wrapped about the rib wires \n34\n.', 'In some embodiments, the instruction data communicated by the feedback system \n48\n to the wrapping machine \n40\n may include a particular pitch setting value representing the pitch value at which it should operate.', 'The instruction data also may include instructions regarding the speed at which the wrapping machine \n40\n should operate, e.g. instructions regarding the speed of rotation of the base pipe \n32\n and/or the speed at which the wrapping machine \n40\n moves linearly with respect to the base pipe \n32\n during wrapping.', 'However, the feedback system \n48\n may be used to obtain data on a variety of parameters and to provide a variety of corresponding instructions to the wrapping machine \n40\n.', 'According to one example, the sensor \n50\n of feedback system \n48\n is in the form of a camera \n56\n mounted on an actuator \n58\n which, in turn, may be attached to a backplane \n60\n or other suitable structure.', 'The camera \n56\n may be mounted at the predetermined distance \n52\n which, in this case, is the focal length of the camera \n56\n.', 'It should be noted that in some embodiments the focal length may be adjusted through manipulation of a lens or lenses of the camera \n56\n or through digital software manipulation.', 'Using this predetermined distance \n52\n between the camera \n56\n and the wraps of wire \n38\n/slot(s) \n44\n enables the camera \n56\n to obtain clear images suitable for measurement and analysis.', 'The camera \n56\n may comprise a variety of digital type cameras or other suitable cameras.', 'In some embodiments, a full-color image may be obtained at a suitable resolution.', 'In other embodiments, however, the camera \n56\n may be selected for capturing a monochromatic image or other suitable type of image which allows determination of the desired parameter, e.g. slot width \n46\n.', 'The camera \n56\n/sensor \n50\n also may utilize other technologies to determine the desired parameter, e.g. slot width \n46\n.', 'Examples of other technologies include ultrasonic technologies, laser technologies, infrared imaging, or other technologies able to obtain images which enable determination of slot width \n46\n (and/or other desired parameters).', 'In a variety of embodiments, the camera \n56\n may operate together with the wrapping machine \n40\n to measure the slot width \n46\n and slot quality in real time as the layer \n38\n is wrapped to form the filter \n42\n.', 'The measurements of slot width \n46\n may be determined from the images obtained by camera \n56\n and those images may be obtained concurrently with operation of the wrapping machine \n40\n as the wrapping machine \n40\n wraps the wire \n38\n about the rib wires \n34\n and base pipe \n32\n.', 'The controller \n54\n processes the data obtained via camera \n56\n and provides feedback to wrapping machine \n40\n so as to make adjustments in real time.', 'Real-time adjustments to the wrapping process helps ensure manufacture of a high quality, wire-wrapped sand screen \n30\n.', 'For example, if the wrapping machine \n40\n is producing slot widths that are at or near a threshold width, a pitch at which wire \n38\n is wrapped may be adjusted during operation of the wrapping machine \n40\n.', 'The adjustment may be made to effectively alter the width of the slots \n44\n so they are no longer at or near the threshold width.', 'This capability of making operational adjustments on-the-fly during wrapping of the wire \n38\n ensures consistent construction quality.', 'The resulting sand screens \n30\n perform substantially better with respect to consistent filtering of the desired particulates.', 'Referring again to \nFIG.', '4\n, the actuator \n58\n is constructed to aid in maintaining the predetermined distance \n52\n.', 'Various types of actuators \n58\n may be used in maintaining the predetermined distance \n52\n, e.g. focal length, between the camera \n56\n/sensor \n50\n and the wraps of wire \n38\n separated by slots \n46\n.', 'For example, the actuator \n58\n may utilize pressurized air, springs, hydraulics, or other mechanisms to achieve desired positioning and functionality.', 'Various hydraulic actuators, electro-mechanical actuators, and other suitable actuators \n58\n may be mounted to control positioning of camera \n56\n, e.g. mounted between backplane \n60\n and camera \n56\n.', 'The backplane \n60\n also may have various suitable forms.', 'In some embodiments, the backplane \n60\n may be mechanically coupled to the wrapping machine \n40\n.', 'For example, the backplane \n60\n may be in the form of a flange or plate extending from the wrapping machine \n40\n.', 'Such mechanical coupling may aid in maintaining the predetermined distance \n52\n between the sensor \n50\n/camera \n56\n and the wraps of wire \n38\n.', 'In other embodiments, the backplane \n60\n may be mechanically independent from the wrapping machine \n40\n.', 'Due to large variations in spot weld parameters and also due to large tolerance variations between dimensions of base pipe \n32\n, rib wires \n34\n, and wrapped wire \n38\n, it may be desirable to continuously adjust the position of camera \n56\n.', 'The position of camera \n56\n may be adjusted automatically to account for these variations and to maintain the predetermined distance/focal length \n52\n during construction of the sand screen \n30\n.', 'By way of example, the actuator \n58\n may be operated to provide continuous adjustment of the position of camera \n56\n.', 'In some embodiments, the actuator \n58\n also may be used to automatically compensate for vibrations.', 'Referring generally to \nFIG.', '5\n, another embodiment of feedback system \n48\n is illustrated.', 'In this embodiment, a distance member \n62\n is used to set the predetermined distance \n52\n.', 'By way of example, the distance member \n62\n may comprise a wheel \n64\n coupled to a rigid arm \n66\n extending from the camera \n56\n (or a suitable camera mounting) to aid in maintaining the desired, predetermined distance/focal length \n52\n.', 'The wheel \n64\n may be placed in contact with the surface of the wraps of wire \n38\n at a location at or near the location from which images of the wraps of wire \n38\n are obtained.', 'The wheel \n64\n may be configured to roll along the surface of the wire wrap \n36\n as the sand screen \n30\n is rotated and moved linearly outward from the wrapping machine \n40\n as the sand screen is rotated and as the wrapping machine \n40\n and the sand screen \n30\n are moved linearly with respect to each other.', 'In some embodiments, a light \n68\n may be positioned to help obtain high quality and consistent images via camera \n56\n.', 'The light \n68\n may be positioned to illuminate the location on the wraps of wire \n38\n where the camera \n56\n captures the images.', 'In some embodiments, the light \n68\n may be positioned at a low angle to brighten the images without washing out the image and/or without providing undesirable glare.', 'Additionally, the light \n68\n may have a variety of types and forms, e.g. single LED, multiple LEDs, a circular LED array, or other suitable lighting tools.', 'The light \n68\n also may be coupled to the camera \n56\n or with a suitable camera mount.', 'This ensures that the light \n68\n moves with the camera \n56\n and maintains a fixed position relative to the camera \n56\n.', 'In some embodiments, the light \n68\n may extend from the same arm \n66\n as wheel \n64\n.', 'When a wire wrapping process starts, the actuator \n58\n may initially be operated to move the camera \n56\n towards the sand screen \n30\n being manufactured so that the camera \n56\n is positioned at the desired, predetermined distance \n52\n.', 'According to an embodiment, the contact between wheel \n64\n and the wire wrap \n36\n may be used to determine when the appropriate, predetermined distance \n52\n has been achieved.', 'In some embodiments, other forms of distance measurement may be implemented.', 'For example, a laser sensor or ultrasonic sensor may be provided and used to determine the desired distance \n52\n between the camera \n56\n and the sand screen \n30\n.', 'As the sand screen \n30\n is rotated and moved outward from the wrapping machine \n40\n, the camera \n56\n obtains images which are used to determine the desired parameter, e.g. slot width \n46\n.', 'According to one embodiment, the camera \n56\n may be triggered to capture an image between each weld joint of the rib wire \n34\n and the wire wrap \n36\n.', 'In this example, the camera \n56\n may be synced with a welder, e.g. a spot welder forming spot welds between wire \n38\n and rib wires \n34\n, so as to capture an image for each of the welds.', 'Each image captured by the camera \n56\n may be used to obtain data on one or more slots \n44\n on a single plane (see \nFIG.', '3\n).', 'As wrapping continues via the wrapping machine \n40\n, images may be obtained in multiple planes or along the entire length of slot \n44\n to obtain desired measurement data.', 'The measurement data may be logged in a suitable memory, e.g. a database or file, of controller \n54\n.', 'The measurement data may be indexed along desired directions, e.g. axial and radial directions, of the wire-wrap filter \n42\n for post wrapping data analytics.', 'The measurement data also may be utilized in performing a closed-loop feedback control of the wrapping machine \n40\n so as to adjust the monitored parameter, e.g. slot width \n46\n.', 'Each type of sand screen \n30\n being manufactured may have predefined, desired parameters, e.g. a predefined nominal value and a predefined tolerance for slot width \n46\n.', 'These predefined parameters may arise from a desired performance of sand screens \n30\n and/or characteristics of a particular well into which the sand screens \n30\n may be deployed.', 'An example of a potential slot width specification for slots \n44\n between successive wraps of wire \n38\n in a given sand screen \n30\n is provided in Table', 'I:\n \n \n \n \n \n \n \n \nTABLE I\n \n \n \n \n \n \n \n \nSand Screen Quality Control Specification\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nX %', 'Y %\n \nZ %\n \n \n \n \n \n \n \n \nLevel 1\n \n±A\n1\n \n±B\n1\n \n±C\n1\n \n \n \n \nLevel 2\n \n±A\n2\n \n±B\n2\n \n±C\n2\n \n \n \n \n. .', '.\n \n. .', '.\n \n. .', '.\n \n. .', '.', 'Level N\n \n±A\nn\n \n±B\nn\n \n±C\nn', 'In this example, the specification provides that a given sand screen \n30\n is to have a minimum of X % of the slots \n44\n within (nominal−A, nominal+A), a minimum of Y % of the slots \n44\n within (nominal−B, nominal+B), and a minimum of Z % of the slots \n44\n within (nominal−C, nominal+C).', '(See also \nFIG.', '6\n which shows an example of a slot width measurement chart in terms of slot width measured relative to nominal−A, nominal+A, nominal−B, nominal+B, nominal−C, nominal+C.)', 'As may be appreciated, in some cases a specification also may establish that no slot width \n46\n exceed a certain width or deviate from a desired width by more than a certain distance or percentage.', 'In such cases, a single slot exceeding such width may cause the entire screen \n30\n to fall out of specification.', 'However, there may be multiple specification levels for the sand screen inspection.', 'An example slot width measurement charting for one plane is illustrated in \nFIG.', '6\n.', 'The measurement data obtained from sensor \n50\n/camera \n56\n may be utilized via controller \n54\n in performing a closed-loop feedback control on the wrapping machine \n40\n.', 'As the slot width \n46\n is monitored, for example, a control loop may be utilized in which in-process data (e.g. slot width, pitch of wire \n38\n, speed) is fed back to controller \n54\n.', 'The controller \n54\n outputs control signals to adjust the wrapping machine \n40\n so as to produce slots \n44\n which are closer to a nominal width (or within the sand screen specification width distribution) before completing the wrapping.', 'Referring generally to \nFIG.', '7\n, an example feedback control diagram is illustrated.', 'In this example, a control algorithm is programmed into the controller \n54\n and is utilized to minimize the difference between a measured parameter and a reference parameter, e.g. between a measured slot width \n46\n and a pre-defined nominal value.', 'Certain traditional feedback control algorithms, such as Proportional-Integral-Differentiate (PID) and State Space Feedback, are suitable for the feedback control loop in some applications.', 'Other more advanced predictive models also may be suitable for providing the desired control, e.g. Smith Predictor, for compensating pure time delay in the measuring process.', 'Neural Network also can be utilized, after analyzing homogeneous data, to predict the performance of the wrapping machine \n40\n and the trending of slot width \n46\n.', 'By way of example, the camera \n56\n may be applied as a data acquisition mechanism in the feedback system \n48\n.', 'The camera \n56\n acquires images which are a data source to the controller \n54\n which may be used, for example, to measure and analyze slot width \n46\n based on those images.', 'In this embodiment, the camera \n56\n also serves as the data source for data in providing feedback to the wrapping machine \n40\n for improved wrapping performance.', 'Depending on the operation, the wrapping machine may perform a more dynamic non-machine feedback loop or a more static off-machine feedback loop.', 'The data obtained via camera \n56\n also may be used to design and fine-tune control algorithms, e.g. PID, State Space Feedback, Smith Protector, or other suitable control algorithms.', 'Then, the fine-tuned control algorithm may be applied to the wrapping machine \n40\n.', 'New data acquired from the wrapping machine \n40\n may be used as part of the implementation of the control algorithm and may be constantly fed back to the control algorithm in the controller \n54\n to enable calculation of new machine parameters which guarantee wrapping performance and screen quality.', 'New data acquired from the wrapping machine \n40\n also may be applied as training datasets to train and validate an on-machine learning control algorithm for the wrapping machine \n40\n.', 'Such algorithms are capable of identifying and categorizing different sets of control parameters to their correlated machine wrapping performance data.', 'Thus, in real-time, the feedback system \n48\n is able to select desirable control parameters to govern performance of wrapping machine \n40\n.', 'The camera \n56\n in cooperation with the controller \n54\n enables feedback system \n48\n to operate with a variety of traditional wrapping machines \n40\n.', 'The controller \n54\n is able to analyze and retrieve, for example, slot width information from the raw format data, e.g. from images from the camera or from direct reading of data from other sensors, such as ultrasonic sensors or laser sensors.', 'The controller \n54\n is able to organize the gathered data into the correct format for later control algorithm calculation.', 'Referring again to \nFIG.', '7\n, reference data such as startup machine settings and parameters may initially be input.', 'Based on these initial machine settings and parameters, the operating parameters for the wrapping machine \n40\n and the feedback system \n48\n may be set.', 'The controller \n54\n receives the reference data and initiates operation of the feedback system \n48\n by providing the operating parameters, e.g. wire pitch, to wrapping machine \n40\n.', 'Wrapping machine \n40\n then wraps the wire \n38\n to create the filter \n42\n with a desired slot width \n46\n.', 'The sensor \n50\n, e.g. camera \n56\n, obtains sensor data, e.g. images, and the controller \n54\n determines the parameters related to the filter \n42\n, e.g. slot width \n46\n.', 'These parameters are then compared with the reference parameters and a measured error is provided.', 'The controller \n54\n is then able to adjust the operating parameters, e.g. wire pitch, for the wrapping machine \n40\n.', 'In other words, the controller \n54\n is able to adjust the desired parameter on-the-fly as the wire wrapping occurs in wrapping machine \n40\n.', 'Consequently, the wire wrapping process may be controlled to tight tolerances and the quality of the sand screen \n30\n is substantially improved during manufacture of the sand screen \n30\n rather than by implementing post manufacture adjustments.', 'Referring generally to \nFIG.', '8\n, a flowchart is illustrated which shows an example of a slot width measuring process.', 'It should be appreciated that the slot width measuring process may provide data used by the control loop (see \nFIG.', '7\n) to adjust and fine-tune the wrapping process.', 'In some embodiments, the slot width measuring process may be initiated upon initiation of the wrapping machine \n40\n.', 'In other embodiments, the slot width measuring process may be initiated upon receiving user input or upon sensing a wrapped screen filter exiting the wrapping machine \n40\n.', 'The illustrated example of the slot width measuring process comprises initially positioning the camera \n56\n relative to the wire wrap \n36\n (filter \n42\n) to achieve a desired focal length, as represented by block \n70\n.', 'Slot images are then captured via camera \n56\n, as represented by block \n72\n.', 'The slot width \n46\n is then measured based on data in the captured image, as represented by block \n74\n.', 'Suitable image processing and/or boundary or shape determining software may be implemented to aid in the measurement process.', 'For example, measurement data with plane index data may be logged, as represented by block \n76\n.', 'This process may involve real-time measurement charting, as represented by block \n78\n.', 'Controller \n54\n utilizes the appropriate algorithm to process the new data obtained via camera \n56\n and to provide new measurement data with respect to the slot width \n46\n, as represented by block \n80\n.', 'The controller \n54\n may be programmed to check whether the new measurement data is greater than a predetermined reference value, e.g. above a threshold, as represented by decision block \n82\n.', 'If yes, a decision is made via controller \n54\n as to whether the new measurement data is above a non-acceptable threshold, as represented by decision block \n84\n.', 'If yes, the wrapping machine \n40\n may be stopped, as represented by block \n86\n.', 'On the other hand, if the new measurement data is within the desired threshold, the settings of wrapping machine \n40\n are maintained, as represented by block \n88\n.', 'If the new data is within the non-acceptable threshold at decision block \n84\n, the settings of wrapping machine \n40\n may be adjusted during the wrapping operation, as represented by block \n90\n.', 'The controller \n54\n may then determine whether control of the wrapping machine \n40\n is on its last cycle, as represented by decision block \n92\n.', 'If not, the cycles are continued by acquiring additional images, as represented by block \n94\n.', 'Once the wrapping machine reaches its last cycle or is otherwise stopped, the measurement data file may be locked for providing suitable reports, as represented by block \n96\n.', 'It should be appreciated that alternate techniques, measurements, metrics, and specifications may be utilized in other implementations of feedback system \n48\n.', 'In some embodiments, for example, limitations may include a threshold percentage of slot widths \n46\n which do not exceed a specified width.', 'In some embodiments, the controller \n54\n may be programmed to control slot width \n46\n according to an average slot width.', 'Regardless of the programmed parameters, the feedback system \n48\n may be used in making appropriate adjustments on-the-fly so as to output the desired sand screen \n30\n in compliance with the desired specification.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A method of manufacturing a screen, comprising:\noperating a wrapping machine to wrap a wire about a base pipe in a manner which creates a slot between wraps of the wire during creation of a wire-wrapped screen; and\nduring operation of the wrapping machine: rotating the base pipe along a longitudinal axis of the base pipe; capturing images of the wire wrapped about the base pipe using a camera positioned adjacent the wrapping machine at a predetermined distance from the wire wrapped about the base pipe, wherein: the predetermined distance is set according to a distance member; capturing the images of the wire wrapped about the base pipe includes using the distance member to automatically adjust a position of the camera, during operation of the wrapping machine, to maintain the predetermined distance; the distance member comprises a wheel coupled to a rigid arm, the rigid arm extending from the camera to the wire wrapped about the base pipe; and the wheel is in contact with a surface of the wire and configured to roll along the surface of the wire as the base pipe rotates; using a controller to process the images for determining a width of the slot between wraps; providing feedback in real-time, via the controller, to the wrapping machine regarding the width of the slot; and adjusting operating parameters of the wrapping machine based on the feedback regarding the width of the slot.', '2.', 'The method as recited in claim 1, wherein the predetermined distance corresponds to a focal length of the camera.', '3.', 'The method as recited in claim 1, wherein the base pipe comprises a ribbed base pipe, and wherein the operating comprises:\nmoving the wrapping machine lengthwise along the ribbed base pipe; and\nwelding the wire to ribbing of the ribbed base pipe to form the wire into a continuous helical wire wrap about the ribbed base pipe.', '4.', 'The method as recited in claim 1, further comprising positioning and focusing a lens of the camera.', '5.', 'The method as recited in claim 1, wherein adjusting operating parameters comprises adjusting a pitch of the wire.', '6.', 'A system for wrapping a screen, comprising:\na wrapping machine configured to receive a ribbed base pipe, the wrapping machine comprising mechanisms to: rotate the ribbed base pipe along a longitudinal axis of the ribbed base pipe; wrap a wire about the ribbed base pipe in a helical pattern while welding the wire to ribs of the ribbed base pipe to create a slot between wraps of the wire during creation of a wire-wrapped screen; and\na feedback system having: a camera adjacent the wrapping machine, the camera monitoring at least one parameter with respect to positioning of the wire wrapped about the ribbed base pipe, wherein the camera is positioned a predetermined distanced from the wire wrapped about the ribbed base pipe, and wherein the camera is configured to capture images of the wire wrapped about the ribbed base pipe; a distance member configured to automatically adjust a position of the camera, during operation of the wrapping machine, to maintain the predetermined distance, wherein the distance member comprises a wheel coupled to a rigid arm, the rigid arm extending from the camera to the wire wrapped about the base pipe, and wherein the wheel is in contact with a surface of the wire and configured to roll along the surface of the wire as the base pipe rotates; and a controller programmed with logic to: process the images to determine a width slot between wraps; provide feedback in real-time, via the controller, to the wrapping machine regarding the width of the slot; and cause the wrapping machine to make real-time adjustments of operating parameters of the wrapping machine based on the feedback regarding the width of the slot.', '7.', 'The system as recited in claim 6, further comprising an actuator coupled to the camera to control positioning of the camera.', '8.', 'The method as recited in claim 1, wherein automatically adjusting the position of the camera, during the operation of the wrapping machine, to maintain the predetermined distance includes using an actuator to adjust a position of the camera to maintain the predetermined distance.', '9.', 'The method as recited in claim 1, wherein capturing the images of the wire wrapped about the base pipe using the camera comprises capturing an image of the slot between each successive wrap of the wire.', '10.', 'The method as recited in claim 1, further comprising indexing and storing in memory measurement data associated with the images for use after creation of the wire-wrapped screen.', '11.', 'The method as recited in claim 1, wherein adjusting the operating parameters comprises changing the width of the slot.', '12.', 'The method as recited in claim 1, further comprising projecting light to an area, via a light source, to facilitate the capturing of the images.', '13.', 'The method as recited in claim 5, wherein adjusting the operating parameters further comprises adjusting a speed the wrapping machine wraps the wire about the base pipe.']

['FIG.', '1 is a schematic cross-sectional illustration of an example of a wire-wrapped screen which may be used to filter particulates during production of hydrocarbon fluid, according to an embodiment of the disclosure;; FIG.', '2 is a schematic side view of the wire-wrapped screen illustrated in FIG.', '1, according to an embodiment of the disclosure;; FIG.', '3 is a close-up illustration of wrapped wire and the resulting slot located between wraps of the wire during construction of a wire-wrapped screen, according to an embodiment of the disclosure;; FIG.', '4 is a schematic illustration of an example of a feedback system utilized during manufacture of the wire-wrapped screen, according to an embodiment of the disclosure;; FIG.', '5 is a schematic illustration of another example of a feedback system utilized during manufacture of the wire-wrapped screen, according to an embodiment of the disclosure;; FIG.', '6 is an illustration of an example of a slot width measurement chart, according to an embodiment of the disclosure;; FIG. 7 is a diagrammatic illustration of a feedback control implemented via the feedback system during manufacture of the wire-wrapped screen, according to an embodiment of the disclosure;; FIG. 8 is a flow chart illustrating an example of a flow diagram for operation of a feedback system during manufacture of a wire-wrapped screen, according to an embodiment of the disclosure.']

US11942237

System for wireline cable coating

Feb 17, 2020

Marc-Andre de Looz, Bendang Aomeren Imchen, Vassilis Varveropoulos

SCHLUMBERGER TECHNOLOGY CORPORATION

Erickson et al, “Application of package-level high-performance EMI shield material with a novel nozzleless spray coating technology,” 2020 IEEE 70th Electronic Components and Technology Conference (ECTC), 2020, pp. 1691-1696. (Year: 2020).; CN First Office Action; Application No. 202010096195X; dated Dec. 28, 2023; 13 pages with English Translation.

4441113; April 3, 1984; Madan; 5331714; July 26, 1994; Essex; 20090054713; February 26, 2009; Matkovsky; 20140010954; January 9, 2014; Hobson, III; 20170110220; April 20, 2017; Romer

1053179; July 1991; CN; 1571643; January 2005; CN; 1768663; May 2006; CN; 108821037; November 2018; CN; 2221647; August 2010; EP; 2768849; March 1999; FR; 2008525568; July 2008; JP; 2017091633; May 2017; JP

['A cable coater system for a downhole tool includes a cable coater.', 'The cable coater may include a housing and one or more rollers that are coupled to the housing, wherein the one or more rollers are configured to rest on the downhole cable while guiding the cable through openings in the cable coater during wireline operations.', 'The cable coater may remain on cable during all spooling (on and off) activities for the duration of operations and activated to coat the cable upon the final pull out of hole and prior to storage of the cable.', 'The spooling in and out of the cable may further be automatically controlled by providing a positional indicator of the cable coater and thus where the cable is in three-dimensional space relative the spool.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This disclosure claims the benefit of and priority to U.S. Provisional Patent Application No. 62/806,286, titled “System and Method for Cable Coating,” filed Feb. 15, 2019, which is incorporated by reference herein in its entirety for all purposes.', 'BACKGROUND\n \nThis disclosure relates generally to downhole tools and more specifically to tools for coating wireline cables for downhole tools.', 'This section is intended to introduce the reader to various aspects of art that may be related to the present techniques, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'A wellbore drilled into a geological formation may be targeted to produce oil and/or gas from only certain zones of the geological formation.', 'After or during certain wellbore operations, it is desirable to get more information about the formation in the wellbore using wireline cable.', 'Wireline cables may accumulate debris and wellbore fluids as they are used within the wellbore, which may result in damage of cables due to degradation of the armor and/or jackets of the cable.', 'A cable coater or cleaner may be employed to clean the cables or coat them with liquids such as inhibitors and/or grease.', 'Certain conventional cable coaters may add additional stress to the cables, which may result in damage of the cables.', 'SUMMARY\n \nA summary of certain embodiments disclosed herein is set forth below.', 'These aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.', 'One embodiment of the present disclosure relates to a cable coater system for a downhole tool including a cable coater.', 'The cable coater may include a housing having a recess, a first opening, and a second opening that are configured to receive a downhole cable.', 'In some embodiments, the cable coater may include one or more nozzles disposed on the housing, wherein the one or more nozzles configured to direct a flow of liquid onto the downhole cable disposed in the recess.', 'Further, the cable coater may include one or more rollers that are coupled to the housing, wherein the one or more rollers are configured to guide the downhole cable through the first opening, the recess, and the second opening.', 'In addition, the cable coater may include fiducials on any number of exterior surfaces, allowing the coater itself to aid in visual processing and automation of the spooling process.', 'The fiducials can include but are not limited to, circles, ovals, polygons, lines and crossed lines of any number.', 'In some embodiments, the cable coater may apply a lubricant that may change the optical properties (e.g., reflection, color, spectrum in a particular wavelength range, and so forth) such that application of the lubricant may be detected.', 'In some embodiments, the lubricant may include a dopant that may impart a larger change in optical properties.', 'In any case, detection of the downhole cable may allow for positional tracking of the downhole cable based at least in part on certain predetermined, known, and/or input information relating to properties of the cable and/or storage of the cable (e.g., when the cable is stored on a spool or drum) such as cable thickness, diameter of spool, time of run, and so forth.', 'Positional tracking of the downhole cable may be based on fiducials located on the cable coater itself, optical properties of the cable, or combinations thereof.', 'Various refinements of the features noted above may be undertaken in relation to various aspects of the present disclosure.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'The brief summary presented above is intended only to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings in which:\n \nFIG.', '1\n is a partial cross sectional view of a well-logging and perforating system that may be used to bring a well into production, perform well diagnostics, or remediate or repair a well after it has been drilled through the subsurface formations, in accordance with an embodiment of the present techniques;\n \nFIG.', '2\n is a schematic diagram of a cable coater with rollers, in accordance with an embodiment of the present techniques;\n \nFIG.', '3\n is an image of a cable coater with a cable from a first perspective, in accordance with an embodiment of the present techniques;\n \nFIG.', '4\n is an image of a cable coater from a second perspective, in accordance with an embodiment of the present techniques;\n \nFIG.', '5\n is a side view of a cable coater, in accordance with an embodiment of the present techniques; and\n \nFIG.', '6\n is a flow diagram for taking control actions relating to the operation of the cable based at least in part on optical data related to the cable, in accordance with an embodiment of the present techniques.', 'DETAILED DESCRIPTION', 'One or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only examples of the presently disclosed techniques.', 'Additionally, to provide a concise description of these embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'Wireline cables accumulate debris and wellbore fluids as they are used in-hole.', 'The debris and wellbore fluids, if uncleaned can result in damage to cables through degradation of the armor or jackets.', 'Cable cleaners are used in wireline operations to clean the cable as it is pulled out of hole (POOH), and a cable coater can be used to coat the cable with inhibitors, grease, or other fluids depending on the specific need.', 'A roller-suspended coater presented below is used to coat the cable.', 'Spooling of the cable may be fully automatable through intelligent connection to a wireline truck or a substantially fixed installation, which is configurable to have and monitor information such as cable diameter, logging speed/winch speed and where in the run the spooling is.', 'The automatic control of the cable spooling can increase the efficiency of the complete job and may further be used in conjunction with cable cleaners and coaters.', 'The present disclosure relates to a wireline cable coater system (e.g., cable coater system) that prevents damage that may occur during storage and/or in subsequent use.', 'In conventional cable coater systems, cables could be damaged during operation (i.e., running in and out of hole) due to friction with the cable coater during operation.', 'As such, conventional cable coater systems need to be removed during run-in-hole (RIH) and POOH operations.', 'Adding a roller to a cable coater system and, in certain embodiments, adjustable features such as flanges and/or spacers may reduce the frictional force applied to the cable as it moves through the cable coater, and thus reduce, the likelihood of damage applied to the cable when running in or out of hole.', 'Therefore, the cable coater may be left on the cable during the entire operation, which may reduce man-hours associated with maintenance and removal of such devices in addition to reducing the likelihood of damaging the cable when running in and out of hole.', 'Many steps in spooling the cable may be automated.', 'In some embodiments, the coater may operate as part of either partially or completely automated spooling through the intelligent connection to the wireline truck or fixed installation, which can determine positional information of the cable based at least in part on the cable diameter, logging speed (e.g., winch speed) and where in the run the spooling is.', 'The automatic control of spooling the cable in and out of hole as well as coating the cable on the last spooling (final) will increase the efficiency of the complete job.', 'With this in mind, \nFIG.', '1\n illustrates a well-logging system \n10\n that may employ the systems and methods of this disclosure.', 'The well-logging system \n10\n may be used to convey a downhole tool \n12\n through a geological formation \n14\n via a wellbore \n16\n.', 'The downhole tool \n12\n may be conveyed on a cable \n18\n via a logging winch system \n20\n.', 'Although the logging winch system \n20\n is schematically shown in \nFIG.', '1\n as a mobile logging winch system carried by a truck, the logging winch system \n20\n may be substantially fixed (e.g., a long-term installation that is substantially permanent or modular).', 'Any suitable cable \n18\n for well logging may be used.', 'The cable \n18\n may be spooled and unspooled on a drum or spool \n22\n and an auxiliary power source \n24\n may provide energy to the logging winch system \n20\n and/or the downhole tool \n12\n.', 'Moreover, although the downhole tool \n12\n is described as a wireline downhole tool, it should be appreciated that any suitable conveyance may be used.', 'For example, the downhole tool \n12\n may instead be conveyed as a logging-while-drilling (LWD) tool as part of a bottom hole assembly (BHA) of a drill string, conveyed on a slickline or via coiled tubing, and so forth.', 'For the purposes of this disclosure, the downhole tool \n12\n may be any suitable measurement tool that obtains logging measurements through depths of the wellbore \n16\n.', 'For example, such logging measurements may include, but are not limited to, density, resistivity, photoelectric absorption properties, neutron spectroscopy, and the like.', 'To this end, the data processing system \n28\n thus may be any electronic data processing system that can be used to carry out the systems and methods of this disclosure.', 'For example, the data processing system \n28\n may include a processor \n30\n, which may execute instructions stored in memory \n32\n and/or storage \n34\n.', 'As such, the memory \n32\n and/or the storage \n34\n of the data processing system \n28\n may be any suitable article of manufacture that can store the instructions.', 'The memory \n32\n and/or the storage \n34\n may be ROM memory, random-access memory (RAM), flash memory, an optical storage medium, or a hard disk drive, to name a few non-limiting examples.', 'A display \n36\n, which may be any suitable electronic display, may provide a visualization, a well log, or other indication of properties in the geological formation \n14\n or the wellbore \n16\n using logging measurements \n26\n.', 'The addition of centralizing rollers on the cable coater will transfer the load point to the rollers as opposed to bushings typically installed at cable entry and exit points of conventional cable coating devices.', 'As the rollers rotate, there is no reactionary force (friction) applied to the cable inhibiting milking damage, which may allow for continuous use.', 'An additional advantage of this design is the ability to run the cable in and out of hole.', 'That is, the cable coater can be installed at the beginning of the job and removed at the end.', 'It should be appreciated that this may reduce excess time of labor associated with set up of the cable coater during downhole operations.', 'Because the cable coater may be deployed throughout the job, the cable coater may further be used as part of a system to automatically control the cable spooling.', 'FIG.', '2\n is a schematic diagram of a cable coater \n38\n with rollers \n40\n in accordance with aspects of the present disclosure.', 'The illustrated embodiment of the cable coater \n38\n shown in \nFIG.', '2\n also includes a housing \n42\n where fluid, such as a type of lubricant, may be applied to the cable \n18\n.', 'The housing \n42\n includes a recess or channel, a first opening \n43\n, and a second opening \n47\n that are configured to receive a downhole cable.', 'Additionally, the cable coater \n38\n includes one or more nozzles \n44\n disposed on the housing \n42\n of the cable coater than may receive and direct a flow of fluid to the cable that is within the housing \n42\n.', 'As illustrated, the housing \n42\n is generally box-shaped or cuboid, but it should be appreciated that in some embodiments the housing \n42\n may be any shape including, but not limited to, ovoid, cylindrical, spherical, and cubical.', 'As illustrated, the cable coater \n38\n may include one or more flanges \n46\n that couple the rollers \n40\n to the housing \n42\n of the cable coater \n38\n.', 'The flanges \n46\n may have a suitable shape such that the rollers \n40\n receive the cable \n18\n at a suitable height (e.g., along the axis \n48\n), lateral position (e.g., along axis \n50\n), and/or distance from the housing (e.g., along axis \n52\n) to space the cable \n18\n in a position to pass through the first opening \n43\n, recess, and second opening \n47\n.', 'Keeping the cable positioned and generally aligned with the first and second openings \n43\n, \n47\n along axes \n48\n, \n50\n, where a central axis of the cable is aligned or closely aligned and/or overlapping with a central axis of the first opening, recess, and second opening, reduces friction and/or milking of the cable to improve longevity of the cable \n18\n.', 'In addition, the flanges \n46\n may have a suitable shape to also accommodate different shaped housings as described above.', 'In some embodiments, one or more spacers \n54\n may be disposed between the flanges \n46\n and the housing \n42\n.', 'The spacers \n54\n may have a suitable shape and thickness \n56\n such that the roller \n40\n is offset along the axis \n48\n to fit cables of different thicknesses.', 'As such, at least one of the rollers \n40\n and the flange \n46\n may remain constant during operations when different cables \n18\n of different thicknesses are used.', 'Put differently, it may be easier to replace on the spacer \n54\n, while using the same roller \n40\n and/or flange \n46\n.', 'As illustrated, only one spacer \n54\n is used per flange \n46\n, but it should be appreciated that in some embodiments multiple spacers \n54\n may be used per flange \n46\n to position the rollers \n40\n and/or flange \n46\n at a suitable height (e.g., along axis \n48\n) along the housing \n42\n.', 'FIG.', '3\n is an image of a cable coater \n38\n in operation proximate a spool \n64\n, in accordance with aspects of the present disclosure.', 'As discussed herein, the cable coater \n38\n may receive a cable \n18\n via the rollers \n40\n.', 'For example, the cable \n18\n may be directed from a downstream position \n58\n to an upstream position \n60\n.', 'However, it should be appreciated that, in some embodiments, the cable \n18\n may be directed in the reverse direction (e.g., from the upstream position \n60\n to the downstream position \n58\n).', 'In any case, the cable \n18\n directed toward the upstream position may receive a fluid (e.g., a lubricant, or lubricant having a dopant) while the cable \n18\n passes through the housing \n42\n.', 'The dopant may be a solid or liquid that may change the optical properties visible at the surface of the cable \n18\n.', 'For example, cable \n18\n within and/or after the region \n62\n may have a different optical property such as color, reflectivity, and/or an optical signal at a non-visible region of light (e.g., near- or mid-infrared, ultraviolet, and so forth).', 'In another embodiment, the lubricant may be sufficient for producing a change in the optical properties of the cable \n18\n (e.g., able to be detected by a detector such as a camera).', 'As such, the change in optical property at the surface of the cable \n18\n is indicative of successful coating of the cable \n18\n with the lubricant by the cable coater \n38\n.', 'Another aspect of the present disclosure is directed to a positional locator of the cable.', 'That is, the cable coater \n38\n can be used as a position or location indicator of where the cable is in three-dimensional space.', 'The housing \n42\n of the cable coater \n38\n may further include fiducials \n45\n disposed at predetermined and known locations.', 'The fiducials \n45\n may be any shape recognizable by a detector known in the art including, but not limited to, circles, ovals, polygons, lines, and crossed lines of any number.', 'As the cable coater \n38\n is positioned on the cable \n18\n and proximate the spool \n64\n, shape of the cable coater \n38\n itself or the fiducials \n45\n can be used to positionally located the cable coater \n38\n and thus the cable \n18\n as it passes through the cable coater \n38\n.', 'This allows visual automation algorithms used to automatically control spooling to have a much higher accuracy and decreased error over the course of the wireline job; the cable coater shape itself and the fiducials can be used as easily recognizable positional locators (data points) for processing.', 'For example, visual automation algorithms may receive data indicative of the position of the cable via position of the cable coater \n38\n and/or the fiducials \n45\n relative the spool \n64\n.\n \nFIG.', '4\n is an additional image of the cable coater \n38\n from a second perspective, in accordance with aspects of the present disclosure.', 'In particular, \nFIG.', '4\n shows cable coater \n38\n disposed on cable \n18\n being positioned on a spool \n64\n.', 'In this embodiment, the cable \n18\n is being added along the direction \n66\n.', 'Additionally, the cable \n18\n along region \n68\n may have different optical properties than the rest of the cable on the spool \n66\n as the optical property may be less apparent as the lubricant dries or settles, or is obstructed by subsequently added cable \n18\n.', 'In any case, it is presently recognized that the optical properties of the cable \n18\n leaving the cable coater \n38\n may facilitate tracking of the cable.', 'In some embodiments, the cable \n18\n within region \n70\n may be used for positional tracking of the cable \n18\n.', 'For example, an angle of the cable \n18\n within the region \n70\n from the roller \n40\n may be used to determine positional information of the cable \n18\n.', 'As it should be appreciated, the angle may also be determined relative to other points on the image such as a center point, or the angle between the cable \n18\n within the region \n70\n and the cable in the region \n68\n.', 'Alternatively, position of the cable may also be determined using a linear distance (e.g., in the direction \n66\n) and/or', 'how much cable \n18\n has been added to the spool \n64\n based on time information and/or reflectivity measurements.', 'Further, visual automation algorithms may use data indicative of the angle, linear distance, time, reflectivity measurements, or combinations thereof to automatically control spooling.\n \nFIG.', '5\n is a schematic diagram of cable coater system \n72\n for tracking a position of the cable \n18\n, in accordance with aspects of the present disclosure.', 'As shown in the illustrated embodiment of the cable coater system \n70\n of \nFIG.', '3\n, the cable coater system \n72\n includes the cable coater \n38\n, a detector \n74\n, a grease or inhibitor tank \n76\n, a coater control line \n78\n, and a coater control box \n80\n.', 'In some embodiments, the coater control box \n80\n may be the data processing system \n28\n.', 'In any case, the cable coater \n38\n, detector \n74\n, grease or inhibitor tank \n76\n, coater control line \n78\n, and coater control box \n80\n generally cooperate to facilitate position tracking of the cable \n18\n by applying lubricant to the cable \n18\n, detecting a change in optical property of the cable \n18\n due to the added lubricant or a dopant within the lubricant, and determining positional information of the cable based on the change, or lack of change, of the optical property.', 'In some embodiments, predetermined information relating to the geometry or size of the cable may be used in such a determination as discussed herein.\n \nFIG.', '6\n is a flow diagram \n82\n for tracking a position of a cable \n18\n, in accordance with aspects of the present disclosure.', 'In general, the flow diagram \n82\n may include receiving optical data indicative of the position of a cable coater to provide feedback to a data processing system or operator.', 'The elements illustrated in the flow diagram \n82\n may be performed by the data processing system \n28\n or any suitable processing system.', 'The illustrated embodiment of the flow diagram \n82\n in \nFIG.', '6\n begins with receiving (e.g., block \n84\n) optical data.', 'For example, this may include receiving a picture, or taking a video and extracting pixels with a signal above or below a threshold that is indicative of the shape of the cable coater \n38\n itself, fiducials \n45\n, or a presence and/or absence of a lubricant and/or dopant within the lubricant.', 'The flow diagram also includes identifying (e.g., block \n86\n) a position of the cable.', 'As discussed herein, this may be based on pre-determined, known information relating to the cable, the optical data, and/or input from, for example, an operator with information about the cable.', 'Additionally, the flow diagram \n82\n includes taking (e.g., block \n88\n) control action, which may be automated.', 'For example, control action may include sending suitable control signals to halt retraction of the cable or direct the spooling control arm of the cable.', 'The specific embodiments described above have been shown by way of example, and it should be understood that these embodiments may be susceptible to various modifications and alternative forms.', 'It should be further understood that the claims are not intended to be limited to the particular forms disclosed, but rather to cover all modifications, equivalents, and alternatives falling within the spirit and scope of this disclosure.']

['1.', 'A cable coater system for a downhole tool, the system comprising:\na cable coater comprising: a housing having a recess, a first opening, and a second opening that are configured to receive a downhole cable; and one or more nozzles disposed on the housing, wherein the one or more nozzles are configured to direct a flow of liquid onto the downhole cable disposed in the recess;\none or more rollers coupled to the housing;\nwherein the one or more rollers are configured to guide the downhole cable through the first opening, the recess, and the second opening; and\none or more fiducials disposed on the housing configured to be used to positionally locate the downhole cable.', '2.', 'The cable coater system of claim 1, further comprising a detector configured to measure a property of the liquid disposed on the cable.', '3.', 'The cable coater system of claim 2, wherein the property of the liquid is a property of a dopant within the liquid.', '4.', 'The cable coater system of claim 2, further comprising a control system configured to:\ndetermine positional information of the downhole cable based at least in part on the measured property of the liquid; and\nperform a control action based on the measured property.', '5.', 'The cable coater system of claim 1, further comprising one or more flanges disposed between the rollers and the housing.', '6.', 'The cable coater system of claim 5, wherein the one or more flanges is configured to position and align the downhole cable with the first and second openings.', '7.', 'The cable coater system of claim 1, further comprising one or more spacers disposed between the rollers and the housing.', '8.', 'The cable coater system of claim 7, wherein the one or more spacers is disposed between the one or more flanges and the housing.']

['FIG.', '1 is a partial cross sectional view of a well-logging and perforating system that may be used to bring a well into production, perform well diagnostics, or remediate or repair a well after it has been drilled through the subsurface formations, in accordance with an embodiment of the present techniques;; FIG.', '2 is a schematic diagram of a cable coater with rollers, in accordance with an embodiment of the present techniques;; FIG.', '3 is an image of a cable coater with a cable from a first perspective, in accordance with an embodiment of the present techniques;; FIG. 4 is an image of a cable coater from a second perspective, in accordance with an embodiment of the present techniques;; FIG.', '5 is a side view of a cable coater, in accordance with an embodiment of the present techniques; and; FIG.', '6 is a flow diagram for taking control actions relating to the operation of the cable based at least in part on optical data related to the cable, in accordance with an embodiment of the present techniques.; FIG.', '3 is an image of a cable coater 38 in operation proximate a spool 64, in accordance with aspects of the present disclosure.', 'As discussed herein, the cable coater 38 may receive a cable 18 via the rollers 40.', 'For example, the cable 18 may be directed from a downstream position 58 to an upstream position 60.', 'However, it should be appreciated that, in some embodiments, the cable 18 may be directed in the reverse direction (e.g., from the upstream position 60 to the downstream position 58).', 'In any case, the cable 18 directed toward the upstream position may receive a fluid (e.g., a lubricant, or lubricant having a dopant) while the cable 18 passes through the housing 42.', 'The dopant may be a solid or liquid that may change the optical properties visible at the surface of the cable 18.', 'For example, cable 18 within and/or after the region 62 may have a different optical property such as color, reflectivity, and/or an optical signal at a non-visible region of light (e.g., near- or mid-infrared, ultraviolet, and so forth).', 'In another embodiment, the lubricant may be sufficient for producing a change in the optical properties of the cable 18 (e.g., able to be detected by a detector such as a camera).', 'As such, the change in optical property at the surface of the cable 18 is indicative of successful coating of the cable 18 with the lubricant by the cable coater 38.; FIG.', '4 is an additional image of the cable coater 38 from a second perspective, in accordance with aspects of the present disclosure.', 'In particular, FIG.', '4 shows cable coater 38 disposed on cable 18 being positioned on a spool 64.', 'In this embodiment, the cable 18 is being added along the direction 66.', 'Additionally, the cable 18 along region 68 may have different optical properties than the rest of the cable on the spool 66 as the optical property may be less apparent as the lubricant dries or settles, or is obstructed by subsequently added cable 18.', 'In any case, it is presently recognized that the optical properties of the cable 18 leaving the cable coater 38 may facilitate tracking of the cable.', '; FIG.', '5 is a schematic diagram of cable coater system 72 for tracking a position of the cable 18, in accordance with aspects of the present disclosure.', 'As shown in the illustrated embodiment of the cable coater system 70 of FIG.', '3, the cable coater system 72 includes the cable coater 38, a detector 74, a grease or inhibitor tank 76, a coater control line 78, and a coater control box 80.', 'In some embodiments, the coater control box 80 may be the data processing system 28.', 'In any case, the cable coater 38, detector 74, grease or inhibitor tank 76, coater control line 78, and coater control box 80 generally cooperate to facilitate position tracking of the cable 18 by applying lubricant to the cable 18, detecting a change in optical property of the cable 18 due to the added lubricant or a dopant within the lubricant, and determining positional information of the cable based on the change, or lack of change, of the optical property.', 'In some embodiments, predetermined information relating to the geometry or size of the cable may be used in such a determination as discussed herein.; FIG.', '6 is a flow diagram 82 for tracking a position of a cable 18, in accordance with aspects of the present disclosure.', 'In general, the flow diagram 82 may include receiving optical data indicative of the position of a cable coater to provide feedback to a data processing system or operator.', 'The elements illustrated in the flow diagram 82 may be performed by the data processing system 28 or any suitable processing system.']

US11788359

Downhole steering system and methods

Sep 13, 2021

Jonathan D. Marshall, Edward George Parkin, Geoffrey Charles Downton, David C. Hoyle, Nalin Weerasinghe, Dennis Patrick Chesnutt

SCHLUMBERGER TECHNOLOGY CORPORATION

First Substantive Examination Report issed in Saudi Arabian Patent Application No. 519410879 dated Jul. 10, 2022, 8 pages.; International Search Report and Written Opinion issued in International Patent application PCT/US2019/039376 dated Oct. 29, 2018, 19 pages.; International Preliminary Report on Patentability issued in International Patent application PCT/US2018/039376, dated Dec. 31, 2019, 14 pages.; First Office Action and Search Report issued in Chinese Patent Application 201880051550.2 dated Mar. 29, 2021, 7 pages.

6116354; September 12, 2000; Buytaert; 20120234604; September 20, 2012; Hall; 20130032401; February 7, 2013; Edbury et al.; 20150008045; January 8, 2015; Downton; 20160060960; March 3, 2016; Parkin et al.; 20160160567; June 9, 2016; Downton; 20180128060; May 10, 2018; Haugvaldstad; 20180142520; May 24, 2018; Haugvaldstad; 20190136632; May 9, 2019; Haugvaldstad; 20200040658; February 6, 2020; Mohon; 20200141188; May 7, 2020; Marshall et al.; 20200318437; October 8, 2020; Gray

Foreign Citations not found.

['A downhole steering system includes a substantially tubular housing, a shaft positioned within the substantially tubular housing, a first bearing and a second bearing, the first and second bearings being configured to support rotation of the shaft relative to the housing.', 'The first bearing, the second bearing, the shaft, and the housing at least partially define a chamber therebetween.', 'The system also includes at least one structure positioned axially between the first and second bearing and being configured to extend from an exterior of the housing in response to pressure communicated to the chamber.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is a continuation application of U.S. Pat.', 'No. 11,118,408 filed on Dec. 12, 2019, which is a 371 of International Application No. PCT/US2018/039376 filed on Jun. 26, 2018, which claims priority This application claims priority to U.S. Provisional Patent Applications having Ser.', 'Nos. 62/525,121; 62/525,140; 62/525,143; and 62/525,148, each of which was filed on Jun. 26, 2017.', 'The entire contents of each these priority applications is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nExploring for and extracting oil, gas, or geothermal energy deposits from the earth often involves boring subterranean holes.', 'To do so, it is common to secure a drill bit to the end of a drill string suspended from a derrick.', 'The drill bit may be rotated to engage and degrade the earth forming a wellbore therein and allowing the drill bit to advance.', 'It may often be desirable to direct a drill bit toward a deposit or away from an obstruction as it advances through the earth.', 'To do so, a rotational axis of the drill bit must typically be offset from a centerline of its respective borehole such that the drill bit engages one side of the borehole more than another.', 'Furthermore, it is not uncommon for a rotational axis of a drill bit to deviate from a centerline of a borehole on its own, causing the borehole to diverge from its intended path.', 'Thus, it may be advantageous to steer a drill bit back toward the centerline of its respective borehole.', 'Accordingly, various downhole steering systems have been developed for the purpose of actively shifting a drill bit axis from a borehole centerline or returning it thereto.', 'Such downhole steering systems have utilized a variety of different techniques.', 'One common technique is to push off of an inner wall of a wellbore through which a drill bit is traveling in a direction opposite from where the drill bit is intended to go.', 'For example, a structure may be extended radially from a side of a drill string, push against an inner wall of a wellbore and urge a drill bit in an opposite radial direction.', 'As the drill bit is urged radially, it may tend to degrade the wellbore unevenly causing it to veer in a desired direction.', 'It has been found that the closer an extendable structure is placed to a drill bit, the greater affect its extension may have on the drill bit.', 'Thus, several attempts have been made to place extendable structures as close as possible to their respective drill bits.', 'However, such placement often leaves little room for other equipment, such as control systems and the like.', 'In many instances, positioning of control systems or other equipment far from extendable structures complicates electrical wiring and/or fluid channeling.', 'SUMMARY\n \nEmbodiments of the disclosure may provide a downhole steering system including a substantially tubular housing, a shaft positioned within the substantially tubular housing, a first bearing and a second bearing, the first and second bearings being configured to support rotation of the shaft relative to the housing.', 'The first bearing, the second bearing, the shaft, and the housing at least partially define a chamber therebetween.', 'The system also includes at least one structure positioned axially between the first and second bearing and being configured to extend from an exterior of the housing in response to pressure communicated to the chamber.', 'Embodiments of the disclosure may also provide a drilling system including a drill bit, a shaft coupled to the drill bit, wherein rotation of the shaft causes the drill bit to rotate, and a substantially tubular housing positioned around at least a portion of the shaft.', 'The shaft and the drill bit are rotatable relative to the housing.', 'The system also includes a first bearing and a second bearing, the first and second bearings being configured to support rotation of the shaft relative to the housing.', 'The first bearing, the second bearing, the shaft, and the housing at least partially define a chamber therebetween.', 'The system further includes one or more radially-extendable pistons positioned axially between the first and second bearings and in pressure communication with the chamber, the one or more pistons being configured to extend outward of an exterior of the housing in response to pressure communicated to the chamber, and a valve configured to control pressure communication between the chamber and the radially-extendable pistons.', 'Embodiments of the disclosure may also provide a method for steering a drill bit, including deploying drill bit and a downhole steering system into a wellbore.', 'The system includes a substantially tubular housing, a shaft positioned within the substantially tubular housing, a first bearing and a second bearing, the first and second bearings being configured to support rotation of the shaft relative to the housing.', 'The first bearing, the second bearing, the shaft, and the housing at least partially define a chamber therebetween.', 'The system also includes at least one structure positioned axially between the first and second bearing and being configured to extend from an exterior of the housing in response to pressure communicated to the chamber.', 'The method also includes flowing drilling fluid into the downhole steering system such that the shaft is rotated relative to the tubular housing, wherein rotation of the shaft causes the drill bit to rotate, and actuating a valve so as to allow pressure communication between the chamber and the at least one structure, such that the at least one extendable structure extends radially outward and engages a wellbore.', 'Embodiments of the disclosure may provide a method for steering a downhole system including placing a drill string in a well, the drill string including a drill bit and a motor, the motor including a shaft connected to the drill bit and a stator housing in which the shaft is positioned.', 'At least one structure is radially extendable from the stator housing.', 'The method also includes passing drilling fluid from an inlet of the wellbore along the drill string and between the shaft and the stator housing.', 'Passing the drilling fluid between the shaft and the stator housing causes the shaft to rotate the drill bit relative to the stator housing.', 'The method further includes holding the stator housing rotationally stationary, and selectively communicating a pressure of the drilling fluid to the structure via a port extending radially through the stator, so as to extend the structure radially outward against a wall of the wellbore, and alter a trajectory of the drill bit.', 'Embodiments of the disclosure may provide a downhole steering system including a substantially tubular housing comprising a longitudinal axis and an exterior, a shaft coupled to a drill bit, extending through the housing, and rotatable relative to the housing, and a first structure, a second structure, and a third structure.', 'The first, second, and third structures are extendable outward of the exterior of the housing.', 'The first structure is circumferentially offset from the second and third structures.', 'The first, second, and third structures are positioned along an angular interval of less than about 120 degrees as proceeding around the housing.', 'Embodiments of the disclosure may also provide a drilling system including a drill bit, a substantially tubular housing comprising a longitudinal axis and an exterior, a shaft coupled to the drill bit, extending through the housing, and rotatable relative to the housing, wherein rotation of the shaft causes the drill bit to rotate, and a first structure, a second structure, and a third structure.', 'The first, second, and third structures are extendable outward of the exterior of the housing, the first structure being circumferentially offset from the second and third structures.', 'The first, second, and third structures are positioned along an angular interval of less than about 120 degrees as proceeding around the housing.', 'Embodiments of the disclosure may further provide A method for steering a drill bit, which includes flowing a drilling fluid between a housing and a shaft, such that the shaft is caused to rotate relative to the housing, with rotating the shaft causing the drill bit to rotate.', 'The method also includes holding the housing rotationally stationary with respect to a rock formation, and while holding the housing rotationally stationary, selectively communicating pressure to at least three extendable structures coupled to the housing.', 'Communicating pressure to the at least three extendable structures causes the structures to extend outwards and engage the rock formation.', 'The at least three extendable structures each define central axes, the central axes being angularly offset from one another.', 'The at least three extendable structures are positioned along an angular interval of less than about 120 degrees as proceeding around the housing.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is an orthogonal view of an embodiment of an earth-boring operation.\n \nFIG.', '2\n is a perspective view of an embodiment of a drill bit and a downhole steering system.\n \nFIG.', '3\n is a longitude-sectional view of an embodiment of a drill bit, a motor, and a downhole steering system.\n \nFIG.', '4\n-\n1\n is a cross-sectional view of an embodiment of a downhole steering system.\n \nFIG.', '4\n-\n2\n is perspective view of another embodiment of a downhole steering system.\n \nFIG.', '4\n-\n3\n is a longitude-sectional view of an embodiment of a drill bit and a downhole steering system.\n \nFIG.', '5\n-\n1\n is a longitude-sectional view of an embodiment of a drill string wherein a mass may block and unblock an opening leading to a pressurized chamber based on rotation of the drill string.\n \nFIG.', '5\n-\n2\n is a longitude-sectional view of an embodiment of a drill string wherein a mass may block and unblock an opening leading to a pressurized chamber based on a flow rate of drilling fluid passing through the drill string.\n \nFIG.', '5\n-\n3\n is a longitude-sectional view of an embodiment of a drill string wherein a plurality of balls traveling within drilling fluid passing through the drill string may get caught in a slidable trap that may block an opening leading to a pressurized chamber.\n \nFIG.', '5\n-\n4\n is a schematic view of an embodiment of a pin that may travel in a cam slot to index between blocking and unblocking positions.\n \nFIG.', '5\n-\n5\n is a longitude-sectional view of an embodiment of a drill string wherein a disk may be ruptured by an increase in drilling fluid pressure to bypass a pressurized chamber.\n \nFIG.', '6\n-\n1\n is a longitude-sectional view of an embodiment of a control mechanism comprising a direction and inclination sensor.\n \nFIG.', '6\n-\n2\n is a longitude-sectional view of an embodiment of a control mechanism including a formation property sensor.\n \nFIG.', '6\n-\n3\n is a longitude-sectional view of an embodiment of a control mechanism including an acoustic receiver.\n \nFIG.', '6\n-\n4\n is a longitude-sectional view of an embodiment of a control mechanism including a pressure sensor.\n \nFIG.', '6\n-\n5\n is a schematic representation of an embodiment of a control mechanism including a communications wire.', 'FIGS.', '7\n-\n1\n, \n7\n-\n2\n and \n7\n-\n3\n are perspective views of different embodiments of bearings.', 'FIGS.', '8\n-\n1\n and \n8\n-\n2\n are perspective views of embodiments of a three-dimensional printing operation and coating operation, respectively.', 'FIGS.', '9\n-\n1\n and \n9\n-\n2\n are orthogonal views of different embodiments of bearings while \nFIG.', '9\n-\n3\n is a longitude-sectional view of an embodiment of another type of bearing.\n \nFIG.', '10\n-\n1\n is a magnified longitude-sectional view of an embodiment of an axial support ring while \nFIG.', '10\n-\n2\n is a longitude-sectional view of an embodiment of a flow restrictor and filter.\n \nFIG.', '11\n is a longitude-sectional view of an embodiment of oil lubricated bearings.\n \nFIG.', '12\n is a longitude-sectional view of an embodiment of a shaft including a cavity therein sized to receive proximal ends of extendable pads.\n \nFIG.', '13\n is an orthogonal view of an embodiment of a downhole steering system including a combination of both extendable pads and a bent sub.\n \nFIG.', '14\n is a perspective view of an embodiment of a downhole steering system including a combination of both extendable pads and a mating whipstock.\n \nFIG.', '15\n-\n1\n illustrates a sectional view of an embodiment of a ratcheting valve device.\n \nFIG.', '15\n-\n2\n illustrates a perspective view of an embodiment of a valve element for the ratcheting valve device.\n \nFIG.', '15\n-\n3\n illustrates a perspective view of an embodiment of a downhole steering system including the ratcheting valve device.\n \nFIG.', '16\n illustrates a conceptual end view of an embodiment of a cam-piston valve actuator.', 'FIGS.', '17\n-\n1\n and \n17\n-\n2\n illustrate perspective views of two other embodiments of a steering system.', 'DETAILED DESCRIPTION\n \nFIG.', '1\n shows an embodiment of an earth-boring operation \n110\n that may be used when exploring for or extracting oil, gas or geothermal energy deposits from the earth.', 'The earth-boring operation \n110\n may include a drill bit \n111\n secured to one end of a drill string \n112\n suspended from a derrick \n113\n.', 'The drill bit \n111\n may be rotated to degrade subterranean formations \n114\n, forming a wellbore \n115\n therein and allowing the drill bit \n111\n to advance.', 'The drill string \n112\n may be formed from a plurality of drill pipe sections \n116\n fastened together end-to-end, each configured to pass a drilling fluid \n117\n therethrough.', 'The drilling fluid \n117\n may be pumped through the drill string \n112\n from an inlet of the wellbore \n115\n and expelled from nozzles on the drill bit \n111\n.', 'The drilling fluid \n117\n may serve a variety of purposes, including carrying earthen debris away from the drill bit \n111\n, cooling and lubricating the drill bit \n111\n and powering a variety of downhole tools.\n \nFIG.', '2\n shows an embodiment of a drill bit \n211\n secured on an end of a drill string \n212\n.', 'The drill bit \n211\n may comprise a plurality of cutters \n220\n arranged on distal edges of a plurality of blades \n221\n extending from and spaced about the drill bit \n211\n.', 'As the drill bit \n211\n is rotated the cutters \n220\n may engage and degrade an earthen formation.', 'A variety of known drill bit styles may be swapped for the style shown and perform similarly.', 'The drill bit \n211\n may be rotated by a motor.', 'FIG.', '3\n shows an embodiment of a motor, which may be powered by drilling fluid, including a shaft \n330\n positioned within a substantially tubular housing \n331\n.', 'As is typical in progressive cavity positive displacement type motors, the shaft \n330\n may have a helical exterior geometry with two or more lobes disposed thereon.', 'The housing \n331\n may have a helical interior geometry also with two or more lobes disposed thereon.', 'If the housing \n331\n includes more lobes than the shaft \n330\n, then drilling fluid passing along a drill string passing between the exterior geometry of the shaft \n330\n and the interior geometry of the housing \n331\n may cause the shaft \n330\n to rotate eccentrically relative to the housing \n331\n.', 'In this way the shaft \n330\n may act as a rotor and the housing \n331\n may act as a stator of the motor.', 'While a progressive cavity positive displacement motor is shown in this embodiment, other types of motors, such as a turbine motor, may produce a similar result.', 'The housing \n331\n may be provided as two or more tubular members that are secured together, or as one integral piece.', 'Similarly, the shaft \n330\n may be one integral piece, or two or more cylinders that are rigidly or otherwise coupled together.', 'Another example of a downhole tool that may be powered by drilling fluid is a steering system.', 'FIG.', '3\n also shows an embodiment of steering system including a shaft \n332\n positioned within a substantially tubular housing \n333\n, similar to the motor.', 'First and second bearings \n334\n, \n335\n may be axially spaced from one another, disposed between an exterior of the shaft \n332\n and an interior of the housing \n333\n.', 'The first and second bearings \n334\n, \n335\n may support the shaft \n332\n within the housing \n333\n allowing the shaft \n332\n to rotate relative thereto while reducing friction and wear therebetween.', 'Together, the first and second bearings, \n334\n, \n335\n, shaft \n332\n and housing \n333\n may define the boundaries of a chamber \n336\n configured to maintain pressurized drilling fluid therein.', 'Fluid within the chamber \n336\n may be channeled through a valve \n337\n and a passage \n338\n to a plurality of pads \n339\n (or other radially-extendable structures) configured to extend from an exterior of the housing \n333\n when adequately pressurized from within.', 'When extended, the plurality of pads \n339\n may push against a wall of a wellbore in which the housing \n333\n is positioned, thus shifting a rotational axis of a drill bit \n311\n away from or toward a wellbore centerline.', 'Such pushing may be timed and executed to change or maintain a trajectory of advancement of the drill bit \n311\n.', 'The pads \n339\n may be rotationally fixed to the tubular housing \n333\n, such that they may be positioned by rotation of a drill string at an inlet to a wellbore.', 'In such a configuration, the drill bit \n311\n may be rotatable relative to the pads \n339\n and the tubular housing \n333\n.', 'The pads \n339\n may be positioned in a variety of arrangements.', 'For instance, in one embodiment shown in \nFIG.', '4\n-\n1\n, at least three pads \n439\n-\n1\n may be extendable from an exterior of a substantially tubular housing \n433\n-\n1\n such that each of the pads \n439\n-\n1\n remains within an angular range \n440\n-\n1\n of one-third of a full rotation about an axis of the housing \n433\n-\n1\n (e.g., about 120 degrees), whether the pads \n439\n-\n1\n are extended or retracted.', 'While an angular range of one-third is shown, other embodiments may define ranges of one-quarter (80 degrees) to one-half (180 degrees).', 'Such an arrangement of pads \n439\n-\n1\n may allow for sufficient force to be applied by the pads \n439\n-\n1\n to an adjacent wellbore without blocking drilling fluid flow down the housing \n433\n-\n1\n or up an annulus surrounding the housing \n433\n-\n1\n.', 'A cylindrical orifice \n447\n-\n1\n within the housing \n433\n-\n1\n and configured to carry drilling fluid may extend longitudinally through the housing \n433\n-\n1\n, uninterrupted by the pads \n439\n-\n1\n.', 'Also, at least one fluid channel \n441\n-\n1\n may run longitudinally along the exterior of the housing \n433\n-\n1\n configured to carry drilling fluid through the wellbore.', 'This particular embodiment includes two such fluid channels, each disposed between the pads \n439\n-\n1\n and a point on the exterior of the housing \n433\n-\n1\n opposite the pads \n439\n-\n1\n relative to the axis, e.g., along flattened sections of the exterior of the housing \n433\n-\n1\n.', 'A distance \n450\n-\n1\n, between respective nadirs of the two fluid channels, may be greater than a widest span of the pads \n439\n-\n1\n.', 'Due to the spacing of the pads \n439\n-\n1\n, a sum of such fluid channels may be an angular range of over two-fifths of a full rotation about the housing \n433\n-\n1\n axis and over 8% of a cross-sectional footprint area of the housing \n433\n-\n1\n allowing for adequate fluid flow.', 'In some embodiments, the angular range may be between three-tenths and one-half, and the percentage of the cross-sectional footprint area over 6%.', 'A surface \n442\n-\n1\n forming the fluid channel \n441\n-\n1\n may be substantially perpendicular to a radius of the housing \n433\n-\n1\n and parallel to the axis thereof.', 'As also shown in the embodiment of \nFIG.', '4\n-\n1\n, at least two of the pads \n439\n-\n1\n may define axes disposed substantially on a single plane (the cross-section shown) perpendicular to the axis of the housing \n433\n-\n1\n.', 'For example, three pads sharing a single perpendicular plane are shown in \nFIG.', '2\n.', 'The axes of the at least two pads \n439\n-\n1\n may be disposed within an angular range \n443\n-\n1\n of one-fifth (about 72 degrees) of a full rotation about the housing \n433\n-\n1\n axis.', 'In some embodiments, such an angular range may fall between one-tenth (36 degrees) and three-tenths (108 degrees) of a full rotation.', 'Furthermore, one pad \n444\n-\n1\n defines an axis disposed perpendicular to the axis of the housing \n433\n-\n1\n and substantially midway between the axes of the other two pads \n439\n-\n1\n.', 'These respective pads \n439\n-\n1\n, \n444\n-\n1\n may include a distal end shaped generally as a circular arc when viewed in a plane (the cross section shown) perpendicular to the axis of the housing \n433\n-\n1\n.', 'Furthermore, the circular arcs of each of the pads \n439\n-\n1\n, \n444\n-\n1\n may share the same radius and center.', 'In the embodiment shown, the circular-arc distal-end geometry of the center pad \n444\n-\n1\n may be generally symmetrical about its axis.', 'This distal end shape may differ from distal ends of the other two pads \n439\n-\n1\n that may be asymmetrical about their respective axes when viewed in the same plane.', 'More specifically, the distal ends of the other two pads \n439\n-\n1\n may extend farther from the axis of the housing \n433\n-\n1\n on sides facing each other \n445\n-\n1\n than on opposite sides \n446\n-\n1\n.', 'This may be because the center of the circular arcs of each of the pads \n439\n-\n1\n, \n444\n-\n1\n is offset from the axis of the housing \n433\n-\n1\n.', 'In the embodiment shown, this offset equals the length of maximum extension of the pads \n439\n-\n1\n, \n444\n-\n1\n from the exterior.', 'In some embodiments, such an offset may result in less wear, especially on peripheral edges of the pads \n439\n-\n1\n, \n444\n-\n1\n.', 'As also shown in this embodiment, the exterior of the housing \n433\n-\n1\n immediately adjacent the pads \n439\n-\n1\n may extend a greater distance \n448\n-\n1\n from the axis than a distance \n449\n-\n1\n to a point on the exterior opposite from the axis, and a lesser distance \n448\n-\n1\n than a length of a radius of a drill bit secured to a shaft passing through the housing \n433\n-\n1\n.', 'In some embodiments, the housing \n433\n-\n1\n may be configured such that a difference, between this greater distance \n448\n-\n1\n and the distance \n449\n-\n1\n to the opposite point, is substantially equal to a length of maximum extension of the pads \n439\n-\n1\n; however, other designs may also be employed.', 'Also, in some embodiments, the housing \n433\n-\n1\n may be designed such that a sum of these two distances \n448\n-\n1\n, \n449\n-\n1\n is less than a diameter of a drill bit secured to an end of a shaft passing through the housing \n433\n-\n1\n.\n \nFIG.', '4\n-\n2\n shows one embodiment of the pads \n439\n-\n2\n arranged on an exterior of a substantially tubular housing \n433\n-\n2\n.', 'As shown, sets \n451\n-\n2\n of three pads \n439\n-\n2\n, each extendable from the exterior, may be spaced longitudinally along the housing \n433\n-\n2\n.', 'Each of the sets \n451\n-\n2\n may include one pad positioned equidistant and axially displaced, in a staggered configuration, between pairs of double pads spaced longitudinally along the housing \n433\n-\n2\n.', 'In other embodiments, other configurations are possible, such as rows of double pads without center pads.', 'While the illustrated embodiment includes eight extendable pads, other embodiments may have from one to twelve pads, such as three, nine (such as shown in \nFIG.', '2\n), eleven or any other suitable number of pads.', 'In addition, while two specific configurations have been shown in \nFIG.', '2\n and \nFIG.', '4\n-\n2\n, any suitable configuration may be used.', 'For example, pads could be located on any suitable number (such as one to four or more) of axial rows and (one to five or more) circumferential rows.', 'FIG.', '4\n-\n3\n shows an embodiment of a drill bit \n411\n-\n3\n secured to a shaft \n432\n-\n3\n positioned within a housing \n433\n-\n3\n.', 'The housing \n433\n-\n3\n may include a plurality of extendable pads \n439\n-\n3\n disposed on the same side of the housing \n433\n-\n3\n as a control mechanism \n401\n-\n3\n.', 'Specifically, the control mechanism \n401\n-\n3\n may be positioned within the same angular range, one-third of a full rotation about the housing \n433\n-\n3\n, as the pads \n439\n-\n3\n.', 'As also can be seen in this embodiment, to make space for the housing \n433\n-\n3\n when located within a curved wellbore, an exterior of the housing \n433\n-\n3\n may taper longitudinally from a diameter \n459\n-\n3\n adjacent the drill bit \n411\n-\n3\n to a diameter \n458\n-\n3\n closer to a drill string secured to the housing \n433\n-\n3\n opposite the drill bit \n411\n-\n3\n.', 'As described, timing and execution of pad extension may be performed by a control mechanism (also referred to herein as a “control device”) \n301\n disposed axially between the first bearing \n334\n and the second bearing \n335\n, as shown in \nFIG.', '3\n.', 'Various embodiments of control mechanisms may incorporate different control regimen, as will be described in more detail below.', 'For example, the control mechanism \n301\n may actuate the valve \n337\n to affect the timing and duration of pressure on or stroke length of the pads \n339\n.', 'This could be done by the control mechanism \n301\n without the aid of external information.', 'In some embodiments, all pads may be actuated together, groups of pads may be actuated together, or individual pads may be actuated.', 'To determine how much pressure or stroke length is desirable, a variety of sensors may gather information and feed it to such a control mechanism.', 'For instance, some embodiments of sensors, such as inclinometers and magnetometers, may determine position or orientation of a drill string or pads.', 'A control mechanism may then use this information in deciding when and how to actuate a valve.', 'Other embodiments of sensors may detect formation properties of a wellbore surrounding the drill string.', 'Such information may provide addition layers of information to assist a control mechanism.', 'As such, a control mechanism may manipulate a valve with proportional, nonlinear, or on/off actuation in order to achieve a chosen outcome.', 'In various embodiments, a resting position of such pads, before extending, may be either generally flush with or sunken within an exterior of the housing.', 'In other embodiments, however, the pads at rest may protrude from the exterior of the housing to provide a resting outward offset, such that the pads may be either extended or retracted from that position to provide additional steering control.', 'Also, in assorted embodiments, such a plurality of pads may extend together, at least one of the pads may extend separately from the rest, or at least one of the pads may remain continuously extended.', 'In this configuration, pressurized drilling fluid may be channeled to the plurality of pads \n339\n without needing to bypass either of the first or second bearings \n334\n, \n335\n.', 'Specifically, the pressurized drilling fluid traveling from the chamber \n336\n to the pads \n339\n may be continuously maintained axially between the first bearing \n334\n and the second bearing \n335\n.', 'Even without the valve \n337\n, a downhole steering system of the type shown may be operated by holding the housing \n333\n rotationally stationary at an inlet of a wellbore, passing drilling fluid from the inlet along a drill string until it reaches the plurality of pads \n339\n, and pressing the pads \n339\n outwards with pressure from the drilling fluid.', 'Because the housing \n333\n is held, the pads \n339\n may generally extend in a constant orientation thus altering a trajectory of the drill bit \n311\n.', 'A rate of alteration may be controlled by adjusting a pressure of the drilling fluid at the inlet.', 'When straight drilling is desired, the drill string may be rotated at the inlet.', 'Even with the pads \n339\n extended, rotation may generally balance out or negate their effect on drilling direction.', 'One steering plan includes may include generally vertically drilling, for a first distance, then drilling in a curve for a second distance, and then drilling generally horizontally for a third distance.', 'To achieve this steering plan, drilling fluid pressure at an inlet to a wellbore may be increased to extend at least some of the pads when it is desirable to start curving.', 'To stop curving when horizontal is reached, drilling fluid may be blocked from passing to the pads or the pads may be bypassed by the drilling fluid.', 'This may be accomplished by any of a variety of devices.', 'For example, drilling fluid may be blocked by shifting a mass radially within the drill string by adjusting rotation of the drill string.', 'FIG.', '5\n-\n1\n shows an embodiment of a drill string \n512\n-\n1\n including a passage \n547\n-\n1\n positioned longitudinally therethrough with an opening \n551\n-\n1\n to a chamber \n536\n-\n1\n.', 'Drilling fluid traveling through the passage \n547\n-\n1\n may pass through the opening \n551\n-\n1\n into the chamber \n536\n-\n1\n to extend at least one extendable pad \n539\n-\n1\n.', 'When the drill string \n512\n-\n1\n is rotated at a certain speed, a mass \n552\n-\n1\n, rotatable about a hinge, may overcome a spring by centrifugal force to block the opening \n551\n-\n1\n from allowing drilling fluid to pass therethrough.', 'Blocking drilling fluid from reaching extendable pads may also be achieved by shifting a mass longitudinally within a drill string.', 'For example, \nFIG.', '5\n-\n2\n shows an embodiment of a mass \n552\n-\n2\n that may overcome a spring and shift longitudinally when a flow rate of drilling fluid passing along a drill string \n512\n-\n2\n is sufficient.', 'As it does so, it may block an opening \n551\n-\n2\n preventing drilling fluid from entering a chamber \n536\n-\n2\n and extending a pad \n539\n-\n2\n.', 'In other embodiments, drilling fluid may be blocked by passing one or more objects through a drill string along with the drilling fluid.', 'For example, \nFIG.', '5\n-\n3\n shows an embodiment of a plurality of balls \n553\n-\n3\n that may be dropped into a drill string \n512\n-\n3\n and travel with drilling fluid flowing through the drill string \n512\n-\n3\n until they reach a slidable trap \n552\n-\n3\n.', 'The plurality of balls \n553\n-\n3\n may be sufficiently small and durable to pass through a downhole mud motor (not shown).', 'Each of the balls \n553\n-\n3\n may be received within apertures formed in the slidable trap \n552\n-\n3\n.', 'When the apertures are obstructed by the balls \n553\n-\n3\n, the drilling fluid may push the slidable trap \n552\n-\n3\n to block an opening \n551\n-\n3\n into a chamber \n536\n-\n3\n.', 'In other embodiments, drilling fluid may be blocked by a ratcheting device.', 'For example, \nFIG.', '5\n-\n4\n shows an embodiment of a cam slot \n554\n-\n4\n that may wrap around a drill string and receive a pin \n555\n-\n4\n that may travel therein.', 'The cam slot \n554\n-\n4\n may be biased by a spring which may index the pin \n555\n-\n4\n relative to the cam slot \n554\n-\n4\n when compressed by weight-on-bit of the drill string.', 'Indexing of the pin \n555\n-\n4\n to a subsequent location relative to the cam slot \n554\n-\n4\n may then block or unblock an opening leading to a chamber as described previously.', 'With such a design, the opening may be blocked and unblocked repeatedly.', 'FIGS.', '15\n-\n1\n, \n15\n-\n2\n, and \n15\n-\n3\n provide an additional example of such a ratcheting device, described below.', 'In yet another embodiment, drilling fluid may bypass an opening leading to a chamber.', 'For example, in \nFIG.', '5\n-\n5\n an embodiment of a rupture disk \n557\n-\n5\n may be positioned adjacent an opening \n551\n-\n5\n to a chamber \n536\n-\n5\n.', 'An increase in pressure of drilling fluid passing by the rupture disk \n557\n-\n5\n may cause it to burst, thus causing drilling fluid to bypass outward rather than into the chamber \n536\n-\n5\n.', 'Referring back to \nFIG.', '3\n, while extendable pads \n339\n are shown, other embodiments may include different structures such as rings or stabilizer blades that may extend to produce a similar result.', 'The pads \n339\n may be extendable from an exterior of the housing \n333\n based upon an amount of fluid pressure maintained within the chamber \n336\n.', 'For instance the pads \n339\n may extend a certain distance or with certain force based on the chamber \n336\n pressure.', 'In the embodiment shown, this relationship is maintained by each pad \n339\n forming a piston that may slide axially along a cylinder based on a difference of pressure experienced between either end thereof.', 'In some embodiments other configurations are possible, such as hinged pads actuated by pistons.', 'Additionally, a pressure gauge \n305\n may be disposed between the valve \n337\n and the pads \n339\n.', 'This pressure gauge \n305\n may provide feedback to the control mechanism \n301\n that may control actuation of the valve \n337\n to allow for a desirable fluid pressure to be achieved at the pads \n339\n.', 'This fluid pressure may be used to determine a distance extended or force exerted by the pads \n339\n.', 'Another approach may be to measure fluid pressure within the chamber.', 'In some embodiments, the control mechanism \n301\n may be configured to receive communications from the wellbore inlet to adjust the valve \n337\n to reach a target fluid pressure at the pads \n339\n.', 'For instance, a pressure wave, originating at the wellbore inlet, may be transmitted via drilling fluid along the drill string to the control mechanism \n301\n.', 'The pressure wave may include a signal discernible by the control mechanism \n301\n that may inform the control mechanism \n301\n of a desirable pressure for the pads \n339\n.', 'The control mechanism \n301\n may then realize that desirable pressure based on feedback from the pressure gauge \n305\n.', 'In some situations, the pressure wave may include instructions to the control mechanism \n301\n to not actuate the valve \n337\n at all.', 'This override mode, where the pads \n339\n remain retracted, may be helpful in situations where the drill string is to be removed from a wellbore or has become stuck therein.', 'In either case, it may be desirable to keep drilling fluid flowing through a drill string without extending the pads \n339\n.', 'In the embodiment shown, the valve \n337\n is sized to allow between 5 and 30 gallons per minute of drilling fluid to flow therethrough.', 'In other embodiments, this range may be between 0 and 50 gallons or more.', 'A method of operating the downhole steering system utilizing the valve \n337\n may include rotating the drill string, including the pads \n339\n, from the wellbore inlet at one speed and the drill bit \n311\n via the motor at a different speed.', 'A trajectory of the drill bit \n311\n may be altered by repeatedly extending the pads \n339\n as the drill string continues to turn.', 'Such repeated extensions may be timed to carry out a set well plan or return the drill bit \n311\n to its intended trajectory if it begins to stray.', 'Specifically, as a drill string rotates, the pads \n339\n may rotate therewith.', 'As the pads \n339\n pass through an angular range of the drill string circumference, facing generally opposite a lateral direction in which it is desirable to steer, the pads \n339\n may be extended by actuating the valve \n337\n to push off of a wellbore wall.', 'As the pads \n339\n exit that angular range, they may be retracted to disengage from the wellbore wall.', 'In some embodiments, the pads \n339\n may be extended without any communication from the inlet.', 'For example, the control mechanism \n301\n controlling the valve \n337\n may include one or more sensors configured to sense direction, inclination, angular position, rotation and/or lateral displacement of the drill bit \n311\n.', 'As another example, the control mechanism \n301\n may include one or more sensors configured to measure a property of a formation surrounding the housing \n333\n.', 'Actuation of the valve \n337\n may be based on the direction, inclination, angular position, rotation and/or lateral displacement sensed or the formation property measured.', 'To avoid destabilizing drilling behaviors that may be caused by repetitive cyclical pad extensions, it may be desirable for these repeating pad extensions to occur for a brief moment every several rotations or for a full rotation every several rotations.', 'One method of operating the downhole steering system utilizing this downhole rotation sensor may be to rotate the drill string or hold it rotationally stationary at the inlet, sense this rotation or lack thereof downhole and then actuate the valve \n337\n and extend or retract the pads \n339\n based thereon.', 'By so doing, the control mechanism \n301\n might not be configured to communicate axially beyond the first and second bearings \n334\n, \n335\n.', 'Torque from the rotor shaft \n330\n of the motor may be passed through the shaft \n332\n to rotate the drill bit \n311\n.', 'This rotation of the drill bit \n311\n via the motor may allow the drill bit \n311\n to continue its advance regardless of whether it is being rotated from the inlet.', 'Extending or retracting the pads \n339\n may include holding the valve \n337\n in one state, either open or closed, while the drill string is rotating and in an opposite state while the drill string is rotationally stationary.', 'In some situations, a specified rate of change of drill bit trajectory may be achieved by alternating between rotating the drill string at the inlet and holding it rotationally stationary in particular amounts.', 'More specifically, to produce a certain rate of change of trajectory, a specific ratio of time may be spent rotating versus holding rotationally stationary.', 'A defined drill plan may be followed.', 'For example, the drill string may be rotated at the inlet to drill substantially straight in a generally vertical direction for a first distance.', 'The drill string may then be held rotationally stationary at the inlet to drill at a curve for a second distance.', 'Finally, the drill string may be rotated again at the inlet to drill substantially straight again, this time generally horizontally, for a third distance.', 'In some embodiments, the closer extendable pads are placed to a downhole drill bit, the more effect they may have on a trajectory of the drill bit.', 'For instance, in the present embodiment, the pads \n339\n may be positioned axially along the housing \n333\n a distance from a distal end of the drill bit \n311\n equal to or less than two times a diameter of the drill bit \n311\n.', 'Unlike prior attempts to place extendable structures as close as possible to their respective drill bits, however, the structure shown need not bypass either of the first or second bearings \n334\n, \n335\n.', 'To get the pads \n339\n as close as possible to the drill bit \n311\n, a pin and box combination may be used.', 'In some configurations, a drill string generally includes a threaded box into which a threaded pin of a drill bit may be fastened to secure the drill bit to the drill string in a manner configured to transfer rotation therebetween.', 'In the present embodiment, however, the shaft \n332\n includes a pin \n302\n that may be received and fastened within a box \n303\n of the drill bit \n311\n.', 'This configuration may position the pads \n339\n even closer to the drill bit \n311\n than the other configuration, where the threaded pin of the drill bit is secured to the box of the drill string.', 'Another component that may have a similar effect to positioning the pads \n339\n as close as possible to the drill bit \n311\n is to locate one or more cutting elements \n304\n on the shaft \n332\n itself adjacent to the drill bit \n311\n as shown.', 'In some embodiments, it may be desirable to pass at least some drilling fluid to a chamber and pads regardless of whether a valve is actuated or not.', 'Also, in some situations, such a valve may be or include a proportional valve configured to proportionally control of fluid pressure within a chamber.', 'A variety of different bearing designs may be used in conjunction with a downhole steering system of the type described.', 'One variety of bearings may allow drilling fluid flowing along a drill string to pass through the bearings themselves to lubricate the bearings as well as control fluid pressure within the chamber.', 'For example, the first bearing \n334\n may include an internal journal and an external housing, with the internal journal and the external housing being movable with respect to one another.', 'A gap between the journal and the housing may allow drilling fluid to pass by.', 'In various embodiments, the gap may be sized to allow sufficient drilling fluid to pass to pressurize the chamber \n336\n while blocking larger particulate matter from entering the chamber \n336\n.', 'The second bearing \n335\n may also allow some drilling fluid to pass through a gap therein sufficient to lubricate the second bearing \n335\n while not overly reducing fluid pressure within the chamber \n336\n.', 'In this manner, the second bearing \n335\n may maintain a greater pressure differential thereacross than across the first bearing \n334\n.', 'Such dissimilarity in pressure differentials may aid in maintaining a desired pressure within the chamber \n336\n.\n \nFIG.', '6\n-\n1\n shows an embodiment of a control mechanism \n601\n-\n1\n configured to actuate a valve \n637\n-\n1\n.', 'The control mechanism \n601\n-\n1\n includes a sensor \n660\n-\n1\n configured to measure direction and inclination of the control mechanism \n601\n-\n1\n via a three-axis accelerometer that may measure accelerations in x, y and z directions, respectively.', 'While a three-axis accelerometer is illustrated, those of skill in the art will recognize that a variety of other sensor types could additionally or alternately be used.', 'Further, in some embodiments, other characteristics of a substantially tubular housing, such as angular position or rotation, may be measured by such a sensor device.', 'Other embodiments may measure a lateral displacement of a substantially tubular housing relative to a wellbore.', 'Such measurements may be made by a caliper-like sensor or by a determination of pad stroke length.', 'In various embodiments, such a control mechanism may be powered by batteries or a generator configured to convert energy from a flowing drilling fluid to electricity to energize a valve and/or sensor.\n \nFIG.', '6\n-\n2\n shows another embodiment of a control mechanism \n601\n-\n2\n configured to actuate a valve \n637\n-\n2\n.', 'This control mechanism \n601\n-\n2\n includes a series of sensors \n660\n-\n2\n configured to measure a property of a formation proximate the sensors \n660\n-\n2\n.', 'In this embodiment, the sensors \n660\n-\n2\n are configured to measure electrical resistivity of an adjacent formation.', 'This may be accomplished by injecting current into the formation via a first electrode, surrounded by an insulating ring, of one of the sensors \n660\n-\n2\n and receiving current from the formation via a second electrode of another of the sensors \n660\n-\n2\n.', 'While resistivity sensors are featured in the embodiment shown, those of skill in the art will recognize that a variety of other sensor types could alternately be used to measure any of a variety of formation properties.', 'FIG.', '6\n-\n3\n shows an embodiment of a control mechanism \n601\n-\n3\n housed within a sidewall of a portion of a substantially tubular housing \n633\n-\n3\n.', 'The control mechanism \n601\n-\n3\n includes an acoustic receiver \n660\n-\n3\n configured to detect acoustic waves propagating through the housing \n633\n-\n3\n.', 'Specifically, the acoustic receiver \n660\n-\n3\n may include a plurality of piezoelectric crystals positioned such that they contact the housing \n633\n-\n3\n.', 'Acoustic waves propagating through the housing \n633\n-\n3\n may apply mechanical stress to the piezoelectric crystals causing an electric charge to accumulate therein.', 'These acoustic waves may carry information or directions to the control mechanism to guide it in its actuation of a valve \n637\n-\n3\n and be sent from another downhole tool or from a surface of a wellbore.', 'While piezoelectric crystals have been shown in this embodiment, those of skill in the art will recognize that a selection of other sensor types may alternately be used and produce similar results.', 'FIG.', '6\n-\n4\n shows another embodiment of a control mechanism \n601\n-\n4\n housed within a sidewall of a portion of a substantially tubular housing \n633\n-\n4\n.', 'The control mechanism \n601\n-\n4\n includes a pressure sensor \n660\n-\n4\n configured to measure pressure waves propagating through a fluid flowing through the housing \n633\n-\n4\n.', 'Such pressure waves may originate from a wellbore inlet or a downhole device, such as a measurement-while-drilling unit disposed axially beyond first or second bearings, and/or a mud motor, from a control mechanism.', 'Pressure waves generated by a measurement-while-drilling unit and intended for a wellbore inlet may be received and comprehended by a control mechanism as described.', 'In some embodiments, actuation of a valve of the sort shown may create pressure waves in fluid that may be discernible at a wellbore inlet or another downhole device, allowing for two-way communication.', 'As shown, the control mechanism \n601\n-\n4\n includes a piezoelectric crystal facing an opening \n661\n-\n4\n in the housing \n633\n-\n4\n.', 'This opening \n661\n-\n4\n may expose the piezoelectric crystal to fluid flowing through the housing \n633\n-\n4\n.', 'Changes in pressure of that fluid may apply mechanical stress to the piezoelectric crystals causing an electric charge to accumulate therein as described in regards to other embodiments.', 'While piezoelectric crystals have been shown in this embodiment, those of skill in the art will recognize that a selection of other sensor types may alternately be used and produce similar results.', 'FIG.', '6\n-\n5\n shows yet another embodiment of a control mechanism \n601\n-\n5\n housed within a sidewall of a substantially tubular housing \n633\n-\n5\n.', 'In this embodiment, a downhole device \n662\n-\n5\n, such as a measurement-while-drilling unit, may be disposed on an opposite side of a mud motor \n663\n-\n5\n from the control mechanism \n601\n-\n5\n.', 'The downhole device \n662\n-\n5\n may comprise its own detection and measurement equipment, separate from any sensors forming part of the control mechanism \n601\n-\n5\n.', 'Such detection and measurement equipment, of the downhole device \n662\n-\n5\n, may be larger and more sophisticated due to it being positioned axially farther from a drill bit than the control mechanism \n601\n-\n5\n.', 'Thus, more detailed and complex information may be gathered by the downhole device \n662\n-\n5\n.', 'The downhole device \n662\n-\n5\n may transmit at least some of this data to the control mechanism \n601\n-\n5\n.', 'In the embodiment shown, this data is transmitted to the control mechanism \n601\n-\n5\n via a communications wire \n664\n-\n5\n that may bypass the mud motor \n663\n-\n5\n through a sidewall thereof.', 'The control mechanism \n601\n-\n5\n may actuate a valve \n637\n-\n2\n based on this transmitted information.', 'In other embodiments, a measurement-while-drilling unit, or other downhole device, may transmit data past a mud motor to a valve control mechanism via acoustic waves propagating through a housing or pressure waves propagating through a fluid.', 'FIGS.', '7\n-\n1\n and \n7\n-\n2\n show embodiments of bearings \n734\n-\n1\n and \n734\n-\n2\n, respectively, including journals \n770\n-\n1\n, \n770\n-\n2\n that are movable with respect to housings \n771\n-\n1\n, \n771\n-\n2\n.', 'The bearings \n734\n-\n1\n, \n734\n-\n2\n include fluid passages, such as clearances \n772\n-\n1\n, \n772\n-\n2\n formed between the journals \n770\n-\n1\n, \n770\n-\n2\n and housings \n771\n-\n1\n, \n771\n-\n2\n that may allow drilling fluid to flow therebetween while restricting larger particulates.', 'Tolerances in the clearances \n772\n-\n1\n, \n772\n-\n2\n provided to maintain concentricity of the journals \n770\n-\n1\n, \n770\n-\n2\n and housings \n771\n-\n1\n, \n771\n-\n2\n, may impede the ability to establish and maintain sufficient fluid pressure within a chamber.', 'Accordingly, the bearing \n734\n-\n1\n, \n734\n-\n2\n may define flow passage geometries through which additional drilling fluid may pass.\n \nFIG.', '7\n-\n1\n shows a geometry including a plurality of grooves \n773\n-\n1\n disposed on an exterior of the journal \n770\n-\n1\n sitting parallel to a rotational axis \n774\n-\n1\n thereof.', 'Another plurality of grooves \n775\n-\n1\n may be disposed on an interior of the housing \n771\n-\n1\n.', 'The combination of grooves \n773\n-\n1\n, \n775\n-\n1\n may include a total cross-sectional area sufficient to allow up to 30 gallons per minute or 5% of a total flow of drilling fluid flowing through a drill string to pass the bearing \n734\n-\n1\n.', 'In other embodiments, this area may allow up to 60 gallons per minute, or 10% of a total, or more to pass.\n \nFIG.', '7\n-\n2\n shows another geometry including a plurality of grooves \n773\n-\n2\n disposed on an exterior of the journal \n770\n-\n2\n and another plurality of grooves \n775\n-\n2\n disposed on an interior of the housing \n771\n-\n2\n.', 'Each of these grooves \n773\n-\n2\n, \n775\n-\n2\n may curve around a rotational axis \n774\n-\n2\n of the bearing \n734\n-\n2\n to form a helical path.', 'Such curved grooves \n773\n-\n2\n, \n775\n-\n2\n may aid in cleaning the exterior of the journal \n770\n-\n2\n and the interior of the housing \n771\n-\n2\n.\n \nFIG.', '7\n-\n3\n shows an embodiment of a bearing \n734\n-\n3\n including a journal \n770\n-\n3\n rotatable within a housing \n771\n-\n3\n.', 'The housing \n771\n-\n3\n includes a plurality of conduits \n776\n-\n3\n extending along a length thereof and allowing a drilling fluid to flow therethrough.', 'In other embodiments, conduits may be disposed within a journal as well or forming helical paths.', 'Various manufacturing methods may be used to create bearings including such intricate geometries.', 'Specifically, it may not be possible to form a nonlinear conduit using a drill.', 'Thus, for example, one manufacturing technique that has been used is three-dimensionally printing a base structure having the desired geometry as shown in \nFIG.', '8\n-\n1\n.', 'As commonly available three-dimensionally printable materials are not generally suited to withstand abrasive conditions, the three-dimensionally printed base may be coated in materials chosen to withstand abrasion as shown in \nFIG.', '8\n-\n2\n.\n \nFIG.', '9\n-\n1\n shows an embodiment of a bearing \n934\n-\n1\n including a plurality of grooves \n975\n-\n1\n disposed on an interior of a housing \n971\n-\n1\n and sitting parallel to a rotational axis \n974\n-\n1\n thereof.', 'As can be seen, each of the grooves \n975\n-\n1\n may extend only part way along an axial length of the bearing \n934\n-\n1\n.', 'Additionally, each of the grooves \n975\n-\n1\n may extend from opposing ends alternatingly.', 'Grooves of this and similar geometries may increase an area for fluid flow between a journal and housing.', 'Such grooves may also allow for cleaning and lubrication while blocking large particulate.\n \nFIG.', '9\n-\n2\n shows another embodiment of a bearing \n934\n-\n2\n including a plurality of grooves \n975\n-\n2\n disposed on an interior of a housing \n971\n-\n2\n.', 'In this embodiment, the grooves \n975\n-\n2\n are cross-sectionally larger on a first end \n990\n-\n2\n than on an opposing second end \n991\n-\n2\n.', 'Positioning the second end \n991\n-\n2\n facing toward a chamber and second bearing may allow the bearing \n934\n-\n2\n to act like a compressor in that large amounts of drilling fluid may enter the grooves \n975\n-\n2\n at the first end \n990\n-\n2\n and then be forced into a smaller space at the second end \n991\n-\n2\n as the housing \n971\n-\n2\n rotates relative to a journal.', 'By so doing, a fluid pressure within the chamber may be greater than before entering through the bearing \n934\n-\n2\n.', 'Additionally, the fluid pressure within the chamber may be dependent and at least somewhat regulated by a rotational speed of the housing \n971\n-\n2\n relative to the journal.', 'FIG.', '9\n-\n3\n shows another embodiment of a bearing \n935\n-\n3\n including discrete superhard elements \n993\n-\n3\n (e.g., polycrystalline diamond, cubic boron nitride, carbon nitride or boron-nitrogen-carbon structures) secured within cavities on an internal surface \n992\n-\n3\n thereof.', 'The internal surface \n992\n-\n1\n may include hard cladding (e.g., tungsten and tungsten carbide) brazed thereto.', 'Such features may prolong the life of these types of bearings.\n \nFIG.', '10\n-\n1\n shows an embodiment of a ring \n1094\n-\n1\n that may be disposed between a shaft \n1032\n-\n1\n and a substantially tubular housing \n1033\n-\n1\n.', 'The ring \n1094\n-\n1\n rests axially between a second bearing \n1035\n-\n1\n and an internal ledge formed in the housing \n1033\n-\n1\n, although other configurations are possible.', 'This ring \n1094\n-\n1\n may allow the second bearing \n1035\n-\n1\n and an axially spaced first bearing (not shown) to support the shaft \n1032\n-\n1\n axially relative to the housing \n1033\n-\n1\n as well as radially.\n \nFIG.', '10\n-\n2\n shows an embodiment of another type of ring, this time forming a flow restrictor \n1094\n-\n2\n.', 'The ring forming this flow restrictor \n1094\n-\n2\n may be retained axially, but otherwise float freely between a shaft \n1032\n-\n2\n and a housing \n1033\n-\n2\n.', 'In this configuration, the flow restrictor \n1094\n-\n2\n may impede fluid flow passing between the shaft \n1032\n-\n2\n and the housing \n1033\n-\n2\n.', 'Restricting or impeding this fluid flow may reduce wear on a second bearing \n1035\n-\n2\n that also interacts with the flow.\n \nFIG.', '10\n-\n2\n also shows an embodiment of a filter \n1010\n-\n2\n that may screen particulate matter of a given size traveling with the fluid flow from reaching a valve \n1037\n-\n2\n or extendable pads \n1039\n-\n2\n there beyond.', 'Thus, this filter \n1010\n-\n2\n may reduce wear on the valve \n1037\n-\n2\n, pads \n1039\n-\n2\n and internal fluid channels.', 'Bearing designs described thus far have generally been lubricated by drilling fluid passing through the bearing.', 'However, other lubrication methods are also possible.', 'For example, \nFIG.', '11\n shows an embodiment of a chamber \n1136\n defined by a shaft \n1132\n, a substantially tubular housing \n1133\n, and first and second bearings \n1134\n, \n1135\n.', 'The chamber \n1136\n may be filled and pressurized by at least one port \n1195\n passing from a hollow interior \n1196\n of the shaft \n1132\n, through which drilling fluid may be flowing, to the chamber \n1136\n.', 'The first and second bearings \n1134\n, \n1135\n may be lubricated by oil released from first and second reservoirs \n1197\n, \n1198\n, respectively.', 'While not specifically shown, various embodiments of ports may include screens or filters to keep larger particulate matter traveling down a hollow interior of a shaft from entering a pressure chamber.', 'Further, similar to bearing designs described previously, pressurized drilling fluid may be channeled from the chamber \n1136\n to a plurality of extendable pads \n1139\n without needing to bypass either of the first or second bearings \n1134\n, \n1135\n.', 'FIG.', '12\n shows an embodiment of a shaft \n1232\n positioned within a substantially tubular housing \n1233\n.', 'The shaft \n1232\n may include a cavity \n1210\n disposed on an external surface thereof.', 'The cavity \n1210\n may surround the shaft \n1232\n and be sufficiently sized to allow proximal ends of a plurality of extendable pads \n1239\n to fit therein.', 'Allowing the pads \n1239\n to retract into the cavity \n1210\n may provide for a longer pad stroke in general, thus increasing how far they may extend from an exterior of the housing \n1233\n.', 'Moreover, the embodiment shown includes a plurality of elastic members \n1211\n, such as springs, each individually urging one of the pads \n1239\n to retract into the cavity \n1210\n.', 'These elastic members \n1211\n may allow for active retraction of the pads \n1239\n rather than relying completely on pressure from outside the housing \n1233\n.', 'Retraction of the pads \n1239\n requires removing some fluid from within the cavity \n1210\n.', 'Without removing fluid, rather than retracting, the pads \n1239\n would generally hydraulically lock when a valve \n1237\n leading to the cavity \n1210\n was shut.', 'In some embodiments, hydraulic locking of pads may be avoided by allowing some fluid to leak past the pads to exhaust from a cavity.', 'In this embodiment, however, exhausting may be amplified by at least one port \n1212\n passing from the cavity \n1210\n to an exterior of the housing \n1233\n.', 'This port \n1212\n may be sized relative to the valve \n1237\n such as to have a minor effect on fluid pressure within the cavity \n1210\n when the valve \n1237\n is open but allow pressure within the cavity \n1210\n to decrease when the valve \n1237\n is closed.', 'Pressure within the cavity \n1210\n may decrease to a point where it is overcome by pressure outside of the housing \n1233\n which may cause the pads \n1239\n to retract.', 'So far, embodiments of pads pressurized by drilling fluid have primarily been discussed.', 'Additional embodiments of downhole steering systems, however, may include pads extendable by a variety of alternate means.', 'For example, in some embodiments, pressurized hydraulic fluid, such as oil, may be channeled within a closed circuit from a reservoir to a plurality of extendable pads.', 'Such hydraulic fluid may pass through a valve to a chamber positioned adjacent the pads to urge them outward from a substantially tubular housing.', 'In some embodiments, an electrical screw may be used to extend pads from such a housing.', 'For instance, in some embodiments, a control mechanism may rotate a nut engaged with a screw such that the screw translates axially with respect to the nut.', 'As the screw translates it may urge at least one pad outward from the housing.', 'Those of skill in the art will recognize that an assortment of additional devices could be interchanged with those described herein and function in a similar manner.\n \nFIG.', '13\n shows an embodiment of a downhole steering system including a plurality of pads \n1339\n extendable from an exterior thereof that may push off a wall of a wellbore to aid in steering a drill bit \n1311\n.', 'In combination with the extendable pads \n1339\n, the steering system may also include a bent sub \n1310\n portion of a drill string \n1312\n.', 'In this configuration, force applied by the pads \n1339\n against a wall of a wellbore may either add to or take away from the already bent section of the drill string \n1312\n allowing for greater severity when altering trajectory of advancement of the drill bit \n1311\n.\n \nFIG.', '14\n shows an embodiment of a whipstock \n1410\n which is a device, often shaped generally as a ramp, which may be disposed in a wellbore \n1415\n to alter a trajectory of a drill bit \n1411\n as it drills.', 'In use, when engaged by the drill bit \n1411\n, the whipstock \n1410\n may push the drill bit \n1411\n sideways, off its current trajectory.', 'In the present embodiment, a pad \n1439\n, extendable from an exterior of a drill string \n1412\n secured to the drill bit \n1411\n, may include a geometry \n1430\n configured to be slidably received within a mating geometry \n1431\n of the whipstock \n1410\n.', 'In this configuration, the geometry \n1430\n of the pad \n1439\n may align with the geometry \n1431\n of the whipstock \n1410\n when in proximity thereto to combine the force exerted by extension of the pads \n1439\n with push of the whipstock \n1410\n for greater severity when altering trajectory of advancement of the drill bit \n1411\n.', 'FIGS.', '15\n-\n1\n, \n15\n-\n2\n, and \n15\n-\n3\n illustrate another embodiment of a ratcheting device \n1500\n, similar to the embodiment described above with reference to \nFIG.', '5\n-\n4\n.', 'As shown, the ratcheting device \n1500\n may include a valve element \n1502\n and a valve housing \n1504\n.', 'The valve element \n1502\n may be positioned in the valve housing \n1504\n and may define an indexing slot \n1506\n.', 'The indexing slot \n1506\n may be similar in shape to the slot \n554\n-\n5\n (\nFIG.', '5\n-\n4\n), and may extend partially or entirely around the circumference of the valve element \n562\n.', 'The valve element \n1502\n may further include one or more fingers \n1507\n.', 'Ports \n1509\n may be defined between the fingers \n1507\n.', 'The ratcheting device \n1500\n may also include a biasing member \n1508\n, such as a spring that is coiled around or within the valve element \n1502\n (or both, as shown).', 'The biasing member \n1508\n may be configured to bear against the valve housing \n1504\n, either directly or via connection with another member, and the valve element \n1502\n, so as to push the valve element \n1502\n in an axial direction (e.g., to the right, as shown) with respect to the valve housing \n1504\n.', 'The ratcheting device \n1500\n may further include an indexing pin \n1510\n, which may extend inwards from the valve housing \n1504\n, and may be received into the indexing slot \n1506\n.', 'When the valve element \n1502\n moves with respect to the valve housing \n1504\n, the indexing pin \n1510\n advances in the indexing slot \n1506\n, and translates some of the axial motion of the valve element \n1502\n into rotational movement thereof.', 'The housing \n1504\n may define openings \n1520\n therein and an inlet opening \n1521\n.', 'Drilling fluid pressure acts on the valve element \n1502\n through the inlet opening \n1521\n.', 'When the ratcheting device (valve) \n1500\n is in an open position, the ports \n1509\n of the valve element \n1502\n may be aligned with the openings \n1520\n, allowing fluid communication through the ratcheting device \n1500\n.', 'When the ratcheting device \n1500\n is in a closed position, whether caused by the fingers \n1507\n being rotationally aligned with and thereby blocking the openings \n1520\n or the valve element \n1502\n being pushed axially toward the right, such that the ports \n1509\n are axially misaligned from the openings \n1520\n, fluid is prevented from proceeding through the openings \n1520\n.', 'Referring now specifically to \nFIG.', '15\n-\n3\n, but with continuing reference to \nFIGS.', '15\n-\n1\n and \n15\n-\n2\n, there is shown an embodiment of the ratcheting device \n1500\n positioned in a housing \n1550\n.', 'Similar to the embodiment described above, radially extendable structures (e.g., pistons) \n1552\n may be positioned on or in the exterior of the housing \n1550\n.', 'The structures \n1552\n may be extendable in response to and propelled outwards by pressure selectively communicated thereto from the interior of the housing \n1550\n.', 'In order to control the communication of such pressure, the ratcheting device \n1500\n is provided.', 'Drilling fluid pressure acts on the valve element \n1502\n via the inlet opening \n1521\n, pushing the valve element \n1502\n (e.g., to the left in \nFIG.', '15\n-\n2\n) in the housing \n1504\n.', 'The axial motion of the valve element \n1502\n, as it overcomes the biasing member \n1508\n, is partially converted to rotational movement by the interaction between the slot \n1506\n and the pin \n1510\n, thereby causing the ports \n1509\n to align with the openings \n1520\n.', 'Thus, fluid pressure communicates to the structures \n1552\n, which extend outwards.', 'When the pressure is released, the valve element \n1502\n is pushed axially back to the right, and rotates again by interaction with between the slot \n1506\n and the pin \n1510\n back to closed, thereby allowing the structures \n1552\n to retract.', 'FIG.', '16\n illustrates a steering system \n1600\n which employs a mechanical actuation for radially extendable structures \n1604\n (e.g., pistons or pads), according to an embodiment.', 'The structures may be oriented relative to the tool-face angle of the drill bit.', 'While sliding, the structures can be actuated using drilling mud pressure to bias the drill string causing the system to drill a desired direction and dog leg (curve).', 'The structures can be deactivated for periods when the drill string is rotating.', 'A valve may be employed, and may be changed mechanical between open and closed.', 'The change in state of the valve can be achieved via axial or rotational movement.', 'The change in valve state may be achieved by temporarily increasing mud pressure above a certain value to trigger the switching.', 'One mechanism that may achieve this is a cam-piston system, as shown, which includes a rotatable cam \n1602\n and a plurality of internal pistons \n1604\n.', 'When circulating, pressure may act against an internal piston \n1604\n and cam system, which stops in a pre-defined location.', 'Depending upon the location of the cam \n1602\n, ports either align with ports to the piston chamber to activate the tool, or do not align with those ports, and no activation takes place.', 'The tool is indexed through a sequence of pressures, which change the track upon which the cam piston is guided.\n \nFIG.', '17\n illustrates a downhole steering system \n1700\n, according to an embodiment.', 'In this embodiment, a connector block \n1702\n of the system \n1700\n, which may be a full ring, is attached to the lower end of a housing \n1704\n of the steering system \n1700\n.', 'The connector block \n1702\n can be connected in any suitable manner, such as by bolts, threaded in a way that the main ring body does not need to rotate so it can align with the exposed components, or another retention feature.', 'The connector block \n1702\n contains the connectors and wiring as well as the radially-extendable structures \n1706\n.', 'The structures \n1706\n may be pistons (\nFIG.', '17\n-\n1\n) or pads (\nFIG.', '17\n-\n2\n).', 'Whereas certain embodiments have been described in particular relation to the drawings attached hereto, it should be understood that other and further modifications apart from those shown or suggested herein, may be made within the scope and spirit of the present disclosure.']

['1.', 'A downhole steering system, comprising:\na housing comprising a longitudinal axis and an exterior, the housing comprising a pad side and an opposite side;\na shaft coupled to a drill bit, extending through the housing, and rotatable relative to the housing; and\na plurality of extendable pads, each extendable pad of the plurality of extendable pads is disposed on the pad side of the housing, the plurality of extendable pads comprising a first structure, a second structure, and a third structure, wherein the first structure, the second structure, and the third structure are extendable outward of the exterior of the housing, the first structure being circumferentially offset from the second structure a first distance and circumferentially offset from the third structure a second distance,\nwherein the first structure, and the third structure are positioned along an angular interval of less than about 120 degrees as proceeding around the housing.', '2.', 'The downhole steering system of claim 1, wherein the housing defines at least one fluid channel running longitudinally along the exterior, wherein a total area of the at least one fluid channel is an angular range of over two-fifths of a full rotation about the axis.', '3.', 'The downhole steering system of claim 2, wherein the first structure and the second structure each define a central axis, the central axes of first and second structures being disposed substantially in a single plane perpendicular to the axis of the housing.', '4.', 'The downhole steering system of claim 3, wherein the axes of the first and second structures are within an angular range of one-fifth of a full rotation about the axis of the housing, wherein distal ends of the first and second structures are each asymmetric about the axis of their respective structure when viewed in a plane perpendicular to the axis of the housing, wherein the distal ends of the first and second structures extend farther from the axis of the housing on sides facing each other than on opposite sides.', '5.', 'The downhole steering system of claim 1, wherein the exterior of the housing immediately adjacent the structures extends farther from the longitudinal axis than a point on the exterior opposite from the longitudinal axis.', '6.', 'The downhole steering system of claim 5, wherein a difference in distances from the axis to the adjacent exterior compared to the opposite exterior is substantially equal to a length of extension of the structures from the exterior, wherein a sum of the distances from the axis to the adjacent exterior and to the opposite exterior is less than a diameter of a drill bit secured to a shaft passing through the housing.', '7.', 'The downhole steering system of claim 1, wherein distal ends of the structures, within a plane perpendicular to the axis, comprise substantially circular-arc geometries all sharing the same radius and center, wherein the center is offset from the axis of the housing a length of extension of the structures from the exterior.\n\n\n\n\n\n\n8.', 'The downhole steering system of claim 1, wherein at least one of the structures is positioned axially along the housing a distance, from a distal end of the drill bit secured to the shaft, equal to or less than two times a diameter of the drill bit.', '9.', 'The downhole steering system of claim 1, wherein the first structure and the second structure are positioned along an angular interval of between 36 degrees and 108 degrees as proceeding around the housing.', '10.', 'A method for steering a drill bit, comprising:\nflowing a drilling fluid between a housing and a shaft, such that the shaft is caused to rotate relative to the housing, wherein rotating the shaft causes the drill bit to rotate;\nholding the housing rotationally stationary with respect to a rock formation;\nwhile holding the housing rotationally stationary, communicating drilling fluid pressure to at least one extendable structure coupled to the housing without a valve of the housing, wherein communicating drilling fluid pressure to the at least one extendable structure causes the at least one extendable structure to extend outwards and engage the rock formation, thereby altering a trajectory of the drill bit;\nrotating the housing and the shaft with respect to the rock formation; and\nwhile rotating the housing and the shaft, communicating drilling fluid pressure to the at least one extendable structure coupled to the housing to cause the at least one extendable structure to extend outwards and engage the rock formation, thereby straightening the trajectory of the drill bit.', '11.', 'The method for steering a drill bit of claim 10, comprising continuously extending the at least one extendable structure while holding the tubular housing rotationally stationary and while rotating the tubular housing and the shaft.\n\n\n\n\n\n\n12.', 'The method for steering a drill bit of claim 10, comprising controlling a rate of altering the trajectory of the drill bit based in part on adjusting the pressure of the drilling fluid at a wellbore inlet in fluid communication with the chamber.', '13.', 'A downhole steering system, comprising:\na housing;\na shaft positioned within the housing and rotatable with respect thereto, wherein the shaft and the housing at least partially define a chamber therebetween, wherein the chamber is configured to receive a drilling fluid along a drill string;\nat least one extendable structure in fluid communication with the chamber, wherein the at least one extendable structure is configured to extend from an exterior of the housing in response to pressure of the drilling fluid communicated to the chamber without a valve of the housing to control drilling fluid to the at least one extendable structure;\na second bearing; and\na flow restrictor, wherein the flow restrictor is positioned within the housing and uphole of the second bearing, wherein the flow restrictor is configured to impede drilling fluid flow between the shaft and the housing.', '14.', 'The downhole steering system of claim 13, comprising a first bearing, the first and second bearings being configured to support rotation of the shaft relative to the housing, wherein the first bearing, the second bearing, the shaft, and the housing at least partially define the chamber therebetween.\n\n\n\n\n\n\n15.', 'The downhole steering system of claim 14, wherein the drilling fluid pressure is communicated to the chamber via one or more flow passages defined in the first bearing.', '16.', 'The downhole steering system of claim 14, wherein the at least one extendable structure is positioned axially between the first bearing and the second bearing.', '17.', 'The downhole steering system of claim 13, comprising a drill bit coupled to the shaft.', '18.', 'The downhole steering system of claim 13, wherein the at least one extendable structure comprises a first structure and a second structure, wherein the first structure and the second structure are extendable outward of the exterior of the housing, the first structure being circumferentially offset from the second structure, wherein the first structure and the second structure are positioned along an angular interval of less than about 120 degrees as proceeding around the housing.', '19.', 'The downhole steering system of claim 13, wherein the at least one extendable structure comprises a resting position flush with the exterior of the housing or within the exterior of the housing, and the at least one extendable structure is configured to extend from the resting position in response to pressure of the drilling fluid communicated to the chamber.']

['FIG.', '1 is an orthogonal view of an embodiment of an earth-boring operation.; FIG.', '2 is a perspective view of an embodiment of a drill bit and a downhole steering system.; FIG.', '3 is a longitude-sectional view of an embodiment of a drill bit, a motor, and a downhole steering system.; FIG.', '4-1 is a cross-sectional view of an embodiment of a downhole steering system.; FIG.', '4-2 is perspective view of another embodiment of a downhole steering system.; FIG.', '4-3 is a longitude-sectional view of an embodiment of a drill bit and a downhole steering system.; FIG.', '5-1 is a longitude-sectional view of an embodiment of a drill string wherein a mass may block and unblock an opening leading to a pressurized chamber based on rotation of the drill string.; FIG.', '5-2 is a longitude-sectional view of an embodiment of a drill string wherein a mass may block and unblock an opening leading to a pressurized chamber based on a flow rate of drilling fluid passing through the drill string.; FIG.', '5-3 is a longitude-sectional view of an embodiment of a drill string wherein a plurality of balls traveling within drilling fluid passing through the drill string may get caught in a slidable trap that may block an opening leading to a pressurized chamber.; FIG.', '5-4 is a schematic view of an embodiment of a pin that may travel in a cam slot to index between blocking and unblocking positions.; FIG.', '5-5 is a longitude-sectional view of an embodiment of a drill string wherein a disk may be ruptured by an increase in drilling fluid pressure to bypass a pressurized chamber.; FIG.', '6-1 is a longitude-sectional view of an embodiment of a control mechanism comprising a direction and inclination sensor.; FIG.', '6-2 is a longitude-sectional view of an embodiment of a control mechanism including a formation property sensor.; FIG.', '6-3 is a longitude-sectional view of an embodiment of a control mechanism including an acoustic receiver.; FIG.', '6-4 is a longitude-sectional view of an embodiment of a control mechanism including a pressure sensor.; FIG.', '6-5 is a schematic representation of an embodiment of a control mechanism including a communications wire.; FIGS.', '7-1, 7-2 and 7-3 are perspective views of different embodiments of bearings.; FIGS. 8-1 and 8-2 are perspective views of embodiments of a three-dimensional printing operation and coating operation, respectively.; FIGS.', '9-1 and 9-2 are orthogonal views of different embodiments of bearings while FIG.', '9-3 is a longitude-sectional view of an embodiment of another type of bearing.', '; FIG.', '10-1 is a magnified longitude-sectional view of an embodiment of an axial support ring while FIG.', '10-2 is a longitude-sectional view of an embodiment of a flow restrictor and filter.; FIG.', '11 is a longitude-sectional view of an embodiment of oil lubricated bearings.; FIG.', '12 is a longitude-sectional view of an embodiment of a shaft including a cavity therein sized to receive proximal ends of extendable pads.; FIG. 13 is an orthogonal view of an embodiment of a downhole steering system including a combination of both extendable pads and a bent sub.; FIG.', '14 is a perspective view of an embodiment of a downhole steering system including a combination of both extendable pads and a mating whipstock.; FIG.', '15-1 illustrates a sectional view of an embodiment of a ratcheting valve device.; FIG.', '15-2 illustrates a perspective view of an embodiment of a valve element for the ratcheting valve device.; FIG.', '15-3 illustrates a perspective view of an embodiment of a downhole steering system including the ratcheting valve device.', '; FIG.', '16 illustrates a conceptual end view of an embodiment of a cam-piston valve actuator.; FIGS.', '17-1 and 17-2 illustrate perspective views of two other embodiments of a steering system.; FIG.', '1 shows an embodiment of an earth-boring operation 110 that may be used when exploring for or extracting oil, gas or geothermal energy deposits from the earth.', 'The earth-boring operation 110 may include a drill bit 111 secured to one end of a drill string 112 suspended from a derrick 113.', 'The drill bit 111 may be rotated to degrade subterranean formations 114, forming a wellbore 115 therein and allowing the drill bit 111 to advance.', '; FIG.', '2 shows an embodiment of a drill bit 211 secured on an end of a drill string 212.', 'The drill bit 211 may comprise a plurality of cutters 220 arranged on distal edges of a plurality of blades 221 extending from and spaced about the drill bit 211.', 'As the drill bit 211 is rotated the cutters 220 may engage and degrade an earthen formation.', 'A variety of known drill bit styles may be swapped for the style shown and perform similarly.; FIG.', '4-2 shows one embodiment of the pads 439-2 arranged on an exterior of a substantially tubular housing 433-2.', 'As shown, sets 451-2 of three pads 439-2, each extendable from the exterior, may be spaced longitudinally along the housing 433-2.', 'Each of the sets 451-2 may include one pad positioned equidistant and axially displaced, in a staggered configuration, between pairs of double pads spaced longitudinally along the housing 433-2.', 'In other embodiments, other configurations are possible, such as rows of double pads without center pads.', 'While the illustrated embodiment includes eight extendable pads, other embodiments may have from one to twelve pads, such as three, nine (such as shown in FIG. 2), eleven or any other suitable number of pads.', 'In addition, while two specific configurations have been shown in FIG.', '2 and FIG.', '4-2, any suitable configuration may be used.', 'For example, pads could be located on any suitable number (such as one to four or more) of axial rows and (one to five or more) circumferential rows.; FIG.', '4-3 shows an embodiment of a drill bit 411-3 secured to a shaft 432-3 positioned within a housing 433-3.', 'The housing 433-3 may include a plurality of extendable pads 439-3 disposed on the same side of the housing 433-3 as a control mechanism 401-3.', 'Specifically, the control mechanism 401-3 may be positioned within the same angular range, one-third of a full rotation about the housing 433-3, as the pads 439-3.', 'As also can be seen in this embodiment, to make space for the housing 433-3 when located within a curved wellbore, an exterior of the housing 433-3 may taper longitudinally from a diameter 459-3 adjacent the drill bit 411-3 to a diameter 458-3 closer to a drill string secured to the housing 433-3 opposite the drill bit 411-3.; FIG.', '6-1 shows an embodiment of a control mechanism 601-1 configured to actuate a valve 637-1.', 'The control mechanism 601-1 includes a sensor 660-1 configured to measure direction and inclination of the control mechanism 601-1 via a three-axis accelerometer that may measure accelerations in x, y and z directions, respectively.', 'While a three-axis accelerometer is illustrated, those of skill in the art will recognize that a variety of other sensor types could additionally or alternately be used.', 'Further, in some embodiments, other characteristics of a substantially tubular housing, such as angular position or rotation, may be measured by such a sensor device.', 'Other embodiments may measure a lateral displacement of a substantially tubular housing relative to a wellbore.', 'Such measurements may be made by a caliper-like sensor or by a determination of pad stroke length.', 'In various embodiments, such a control mechanism may be powered by batteries or a generator configured to convert energy from a flowing drilling fluid to electricity to energize a valve and/or sensor.; FIG.', '6-2 shows another embodiment of a control mechanism 601-2 configured to actuate a valve 637-2.', 'This control mechanism 601-2 includes a series of sensors 660-2 configured to measure a property of a formation proximate the sensors 660-2.', 'In this embodiment, the sensors 660-2 are configured to measure electrical resistivity of an adjacent formation.', 'This may be accomplished by injecting current into the formation via a first electrode, surrounded by an insulating ring, of one of the sensors 660-2 and receiving current from the formation via a second electrode of another of the sensors 660-2.', 'While resistivity sensors are featured in the embodiment shown, those of skill in the art will recognize that a variety of other sensor types could alternately be used to measure any of a variety of formation properties.', '; FIG.', '6-3 shows an embodiment of a control mechanism 601-3 housed within a sidewall of a portion of a substantially tubular housing 633-3.', 'The control mechanism 601-3 includes an acoustic receiver 660-3 configured to detect acoustic waves propagating through the housing 633-3.', 'Specifically, the acoustic receiver 660-3 may include a plurality of piezoelectric crystals positioned such that they contact the housing 633-3.', 'Acoustic waves propagating through the housing 633-3 may apply mechanical stress to the piezoelectric crystals causing an electric charge to accumulate therein.', 'These acoustic waves may carry information or directions to the control mechanism to guide it in its actuation of a valve 637-3 and be sent from another downhole tool or from a surface of a wellbore.', 'While piezoelectric crystals have been shown in this embodiment, those of skill in the art will recognize that a selection of other sensor types may alternately be used and produce similar results.', '; FIG.', '6-4 shows another embodiment of a control mechanism 601-4 housed within a sidewall of a portion of a substantially tubular housing 633-4.', 'The control mechanism 601-4 includes a pressure sensor 660-4 configured to measure pressure waves propagating through a fluid flowing through the housing 633-4.', 'Such pressure waves may originate from a wellbore inlet or a downhole device, such as a measurement-while-drilling unit disposed axially beyond first or second bearings, and/or a mud motor, from a control mechanism.', 'Pressure waves generated by a measurement-while-drilling unit and intended for a wellbore inlet may be received and comprehended by a control mechanism as described.', 'In some embodiments, actuation of a valve of the sort shown may create pressure waves in fluid that may be discernible at a wellbore inlet or another downhole device, allowing for two-way communication.; FIG.', '6-5 shows yet another embodiment of a control mechanism 601-5 housed within a sidewall of a substantially tubular housing 633-5.', 'In this embodiment, a downhole device 662-5, such as a measurement-while-drilling unit, may be disposed on an opposite side of a mud motor 663-5 from the control mechanism 601-5.', 'The downhole device 662-5 may comprise its own detection and measurement equipment, separate from any sensors forming part of the control mechanism 601-5.', 'Such detection and measurement equipment, of the downhole device 662-5, may be larger and more sophisticated due to it being positioned axially farther from a drill bit than the control mechanism 601-5.', 'Thus, more detailed and complex information may be gathered by the downhole device 662-5.', 'The downhole device 662-5 may transmit at least some of this data to the control mechanism 601-5.', 'In the embodiment shown, this data is transmitted to the control mechanism 601-5 via a communications wire 664-5 that may bypass the mud motor 663-5 through a sidewall thereof.', 'The control mechanism 601-5 may actuate a valve 637-2 based on this transmitted information.', 'In other embodiments, a measurement-while-drilling unit, or other downhole device, may transmit data past a mud motor to a valve control mechanism via acoustic waves propagating through a housing or pressure waves propagating through a fluid.; FIGS.', '7-1 and 7-2 show embodiments of bearings 734-1 and 734-2, respectively, including journals 770-1, 770-2 that are movable with respect to housings 771-1, 771-2.', 'The bearings 734-1, 734-2 include fluid passages, such as clearances 772-1, 772-2 formed between the journals 770-1, 770-2 and housings 771-1, 771-2 that may allow drilling fluid to flow therebetween while restricting larger particulates.', 'Tolerances in the clearances 772-1, 772-2 provided to maintain concentricity of the journals 770-1, 770-2 and housings 771-1, 771-2, may impede the ability to establish and maintain sufficient fluid pressure within a chamber.', 'Accordingly, the bearing 734-1, 734-2 may define flow passage geometries through which additional drilling fluid may pass.; FIG.', '7-1 shows a geometry including a plurality of grooves 773-1 disposed on an exterior of the journal 770-1 sitting parallel to a rotational axis 774-1 thereof.', 'Another plurality of grooves 775-1 may be disposed on an interior of the housing 771-1.', 'The combination of grooves 773-1, 775-1 may include a total cross-sectional area sufficient to allow up to 30 gallons per minute or 5% of a total flow of drilling fluid flowing through a drill string to pass the bearing 734-1.', 'In other embodiments, this area may allow up to 60 gallons per minute, or 10% of a total, or more to pass.; FIG.', '7-2 shows another geometry including a plurality of grooves 773-2 disposed on an exterior of the journal 770-2 and another plurality of grooves 775-2 disposed on an interior of the housing 771-2.', 'Each of these grooves 773-2, 775-2 may curve around a rotational axis 774-2 of the bearing 734-2 to form a helical path.', 'Such curved grooves 773-2, 775-2 may aid in cleaning the exterior of the journal 770-2 and the interior of the housing 771-2.; FIG.', '7-3 shows an embodiment of a bearing 734-3 including a journal 770-3 rotatable within a housing 771-3.', 'The housing 771-3 includes a plurality of conduits 776-3 extending along a length thereof and allowing a drilling fluid to flow therethrough.', 'In other embodiments, conduits may be disposed within a journal as well or forming helical paths.; FIG.', '9-1 shows an embodiment of a bearing 934-1 including a plurality of grooves 975-1 disposed on an interior of a housing 971-1 and sitting parallel to a rotational axis 974-1 thereof.', 'As can be seen, each of the grooves 975-1 may extend only part way along an axial length of the bearing 934-1.', 'Additionally, each of the grooves 975-1 may extend from opposing ends alternatingly.', 'Grooves of this and similar geometries may increase an area for fluid flow between a journal and housing.', 'Such grooves may also allow for cleaning and lubrication while blocking large particulate.', '; FIG.', '9-2 shows another embodiment of a bearing 934-2 including a plurality of grooves 975-2 disposed on an interior of a housing 971-2.', 'In this embodiment, the grooves 975-2 are cross-sectionally larger on a first end 990-2 than on an opposing second end 991-2.', 'Positioning the second end 991-2 facing toward a chamber and second bearing may allow the bearing 934-2 to act like a compressor in that large amounts of drilling fluid may enter the grooves 975-2 at the first end 990-2 and then be forced into a smaller space at the second end 991-2 as the housing 971-2 rotates relative to a journal.', 'By so doing, a fluid pressure within the chamber may be greater than before entering through the bearing 934-2.', 'Additionally, the fluid pressure within the chamber may be dependent and at least somewhat regulated by a rotational speed of the housing 971-2 relative to the journal.', '; FIG.', '9-3 shows another embodiment of a bearing 935-3 including discrete superhard elements 993-3 (e.g., polycrystalline diamond, cubic boron nitride, carbon nitride or boron-nitrogen-carbon structures) secured within cavities on an internal surface 992-3 thereof.', 'The internal surface 992-1 may include hard cladding (e.g., tungsten and tungsten carbide) brazed thereto.', 'Such features may prolong the life of these types of bearings.; FIG.', '10-1 shows an embodiment of a ring 1094-1 that may be disposed between a shaft 1032-1 and a substantially tubular housing 1033-1.', 'The ring 1094-1 rests axially between a second bearing 1035-1 and an internal ledge formed in the housing 1033-1, although other configurations are possible.', 'This ring 1094-1 may allow the second bearing 1035-1 and an axially spaced first bearing (not shown) to support the shaft 1032-1 axially relative to the housing 1033-1 as well as radially.; FIG.', '10-2 shows an embodiment of another type of ring, this time forming a flow restrictor 1094-2.', 'The ring forming this flow restrictor 1094-2 may be retained axially, but otherwise float freely between a shaft 1032-2 and a housing 1033-2.', 'In this configuration, the flow restrictor 1094-2 may impede fluid flow passing between the shaft 1032-2 and the housing 1033-2.', 'Restricting or impeding this fluid flow may reduce wear on a second bearing 1035-2 that also interacts with the flow.', '; FIG.', '10-2 also shows an embodiment of a filter 1010-2 that may screen particulate matter of a given size traveling with the fluid flow from reaching a valve 1037-2 or extendable pads 1039-2 there beyond.', 'Thus, this filter 1010-2 may reduce wear on the valve 1037-2, pads 1039-2 and internal fluid channels.; FIG.', '12 shows an embodiment of a shaft 1232 positioned within a substantially tubular housing 1233.', 'The shaft 1232 may include a cavity 1210 disposed on an external surface thereof.', 'The cavity 1210 may surround the shaft 1232 and be sufficiently sized to allow proximal ends of a plurality of extendable pads 1239 to fit therein.', 'Allowing the pads 1239 to retract into the cavity 1210 may provide for a longer pad stroke in general, thus increasing how far they may extend from an exterior of the housing 1233.', '; FIG.', '13 shows an embodiment of a downhole steering system including a plurality of pads 1339 extendable from an exterior thereof that may push off a wall of a wellbore to aid in steering a drill bit 1311.', 'In combination with the extendable pads 1339, the steering system may also include a bent sub 1310 portion of a drill string 1312.', 'In this configuration, force applied by the pads 1339 against a wall of a wellbore may either add to or take away from the already bent section of the drill string 1312 allowing for greater severity when altering trajectory of advancement of the drill bit 1311.', '; FIG.', '14 shows an embodiment of a whipstock 1410 which is a device, often shaped generally as a ramp, which may be disposed in a wellbore 1415 to alter a trajectory of a drill bit 1411 as it drills.', 'In use, when engaged by the drill bit 1411, the whipstock 1410 may push the drill bit 1411 sideways, off its current trajectory.', 'In the present embodiment, a pad 1439, extendable from an exterior of a drill string 1412 secured to the drill bit 1411, may include a geometry 1430 configured to be slidably received within a mating geometry 1431 of the whipstock 1410.', 'In this configuration, the geometry 1430 of the pad 1439 may align with the geometry 1431 of the whipstock 1410 when in proximity thereto to combine the force exerted by extension of the pads 1439 with push of the whipstock 1410 for greater severity when altering trajectory of advancement of the drill bit 1411.; FIGS.', '15-1, 15-2, and 15-3 illustrate another embodiment of a ratcheting device 1500, similar to the embodiment described above with reference to FIG.', '5-4.', 'As shown, the ratcheting device 1500 may include a valve element 1502 and a valve housing 1504.', 'The valve element 1502 may be positioned in the valve housing 1504 and may define an indexing slot 1506.', 'The indexing slot 1506 may be similar in shape to the slot 554-5 (FIG.', '5-4), and may extend partially or entirely around the circumference of the valve element 562.', 'The valve element 1502 may further include one or more fingers 1507.', 'Ports 1509 may be defined between the fingers 1507.; FIG.', '16 illustrates a steering system 1600 which employs a mechanical actuation for radially extendable structures 1604 (e.g., pistons or pads), according to an embodiment.', 'The structures may be oriented relative to the tool-face angle of the drill bit.', 'While sliding, the structures can be actuated using drilling mud pressure to bias the drill string causing the system to drill a desired direction and dog leg (curve).', 'The structures can be deactivated for periods when the drill string is rotating.; FIG.', '17 illustrates a downhole steering system 1700, according to an embodiment.', 'In this embodiment, a connector block 1702 of the system 1700, which may be a full ring, is attached to the lower end of a housing 1704 of the steering system 1700.', 'The connector block 1702 can be connected in any suitable manner, such as by bolts, threaded in a way that the main ring body does not need to rotate so it can align with the exposed components, or another retention feature.', 'The connector block 1702 contains the connectors and wiring as well as the radially-extendable structures 1706.', 'The structures 1706 may be pistons (FIG.', '17-1) or pads (FIG.', '17-2).']

US11829399

Extracting user-defined attributes from documents

Jul 22, 2022

Prashanth Pillai, Purnaprajna Raghavendra Mangsuli

SCHLUMBERGER TECHNOLOGY CORPORATION

NPL References not found.

20150278691; October 1, 2015; Xia; 20210233008; July 29, 2021; Gupta; 20220148048; May 12, 2022; Kumar Singh

Foreign Citations not found.

['Systems, computer-readable media, and methods are provided.', 'Relevant documents related to a specific entity are identified based on document metadata.', 'Text and associated spatial coordinates are extracted based on relevant document pages.', 'Significant document entities and associated spatial locations are identified.', 'Page ranking is based on the extracted text and the spatial coordinates, the significant document entities, and image vector representations of the pages.', 'A deep learning language model that utilizes the text and the spatial coordinates, layout information of the document entities, and the image vector representations of the pages is used to extract the user-defined attributes from the relevant document pages.', 'First attribute values associated with the user-defined attributes are aggregated from the pages of one of the relevant documents into a single record.', 'Second attribute values associated with the user-defined attributes are aggregated across the relevant documents.', 'Aggregated records, including a first and second attribute, are written to a database.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nOil exploration and production companies invest considerable time and money to extract information from unstructured data such as, for example, technical reports, logs, surveys to aid strategic decisions, reports regarding new well drilling, planning and production schedules, etc.', 'Current methods of extracting information from unstructured data include domain experts manually extracting the data from various unstructured data sources.', 'When extracting information such as, for example, well header attributes, pressure, volume, temperature (PVT) data, etc. from the above-mentioned sources, different challenges may be encountered such as diverse and non-standard document and page formats, poor print quality, varied fact representations, and domain-specific semantics, thereby making information extraction more difficult.', 'SUMMARY\n \nEmbodiments of the present disclosure may provide a method for extracting text associated with user-defined attributes from multiple documents.', 'Relevant documents related to a specific entity are identified from storage based on document metadata.', 'Text and associated spatial coordinates are extracted based on pages of the relevant documents.', 'Significant document entities and associated spatial locations are identified based on the pages of the relevant documents through page layout analysis.', 'The pages of the relevant documents are ranked based on the extracted text and the spatial coordinates, the identified significant document entities, and image vector representations in the pages.', 'User-defined attributes are extracted from the pages of the relevant documents using a deep learning language model that utilizes the text and the spatial locations, layout information of document entities, and the image vector representations of the pages.', 'First attribute values, associated with the user-defined attributes, from at least some of the pages of one of the relevant documents are aggregated into a single record.', 'Second attribute values associated with the user-defined attributes are aggregated across the relevant documents.', 'Aggregated records are written to a database, each of the aggregated records including a first attribute or a second attribute.', 'In an embodiment of the method, the method includes processing, by attribute-specific parsers executing on a computing device, extracted geographic coordinates, date-specific attributes, and quantities associated with units of measurement.', 'In an embodiment of the method, the specific entity is either a specific oil well or is associated with one from a group consisting of a wellbore, a field, and a prospect, wherein the prospect is an area of exploration in which hydrocarbons have been predicted to exist.', 'In an embodiment of the method, the relevant documents are reports related to the specific entity.', 'In an embodiment of the method, the ranking further includes ranking the pages of the relevant documents based on at least one retrieval method, and the at least one retrieval method includes term frequency-inverse document frequency (TFIDF) or Okapi BM25.', 'In an embodiment of the method, the significant document entities include headings, paragraphs, tables, forms, figures, and logs.', 'In an embodiment of the method, the user-defined attributes are entity-specific attributes and each of the entity-specific attributes is extracted by at least one of a named entity recognition task and an extractive question-answering task.', 'In an embodiment of the method, an attribute value is aggregated across multiple sources based on at least one of a majority vote from among the multiple sources, a confidence probability of the attribute value from among the multiple sources, source metadata, and source priority.', 'Embodiments of the present disclosure may also provide a computer system for extracting text associated with user-defined attributes from multiple documents.', 'The computer system includes at least one processor and at least one memory connected with the at least one processor.', 'The at least one processor is configured to perform multiple operations.', 'According to the multiple operations, relevant documents related to a specific entity are identified from storage based on document metadata.', 'Text and spatial coordinates of the text are extracted based on pages of the relevant documents.', 'Significant document entities and associated spatial locations are identified based on the pages of the relevant documents through page layout analysis.', 'The pages of the relevant documents are ranked based on the extracted text and the spatial coordinates, the identified significant document entities, and image vector representations in the pages.', 'User-defined attributes from the pages of the relevant documents are extracted using a deep learning language model that utilizes the text and spatial locations, page layout information, and the image vector representations of the pages.', 'First attribute values associated with the user-defined attributes from at least some of the pages of the relevant documents are aggregated into a single record.', 'Second attribute values associated with the user-defined attributes are aggregated across the relevant documents.', 'Aggregated records are written to a database, each of the aggregated records including a first attribute or a second attribute.', 'Embodiments of the present disclosure may also provide a non-transitory computer-readable medium having instructions for a processor recorded thereon to configure the processor to perform multiple operations.', 'According to the operations, relevant documents related to a specific entity are identified from storage based on document metadata.', 'Text and spatial coordinates of the text are extracted from pages of the relevant documents.', 'Significant document entities and associated spatial locations are identified based on the pages of the relevant documents through page layout analysis.', 'The pages of the relevant documents are ranked based on the extracted text and the spatial coordinates, identified significant document entities, and image vector representations of the pages.', 'User-defined attributes from the pages of the relevant documents are extracted based on a deep learning language model utilizing the text and the spatial coordinates, page layout information, and image vector representations of the pages.', 'First attribute values associated with the user-defined attributes from at least some of the pages of the relevant documents are aggregated into a single record.', 'Second attribute values associated with the user-defined attributes are aggregated across the relevant documents.', 'Aggregated records are written to a database, each of the aggregated records including a first attribute or a second attribute.', 'Embodiments of the present disclosure may further provide a computing system including: a means for identifying relevant documents related to a specific entity from storage based on document metadata; a means for extracting text and spatial coordinates of the text based on pages of the relevant documents; a means for identifying significant document entities and associated spatial locations of the significant document entities based on the pages of the relevant documents through page layout analysis; a means for ranking the pages of the relevant documents based on the extracted text and the spatial coordinates, identified significant document entities, and image vector representations of the pages; a means for extracting user-defined attributes from the pages of the relevant documents using a deep learning language model that utilizes the text and spatial coordinates, page layout information, and the image vector representations of the pages; a means for aggregating first attribute values associated with the user-defined attributes from at least some of the pages of the relevant documents into a single record; a means for aggregating second attribute values associated with the user-defined attributes across the relevant documents; and a means for writing aggregated records to a database, each of the aggregated records including a first attribute value or a second attribute value.\n \nEmbodiments of the present disclosure may further provide a computing system configured to: identify relevant documents related to a specific entity from storage based on document metadata; extract text and spatial coordinates of the text based on pages of the relevant documents; identify significant document entities and associated spatial locations of the significant document entities based on the pages of the relevant documents through page layout analysis; rank the pages of the relevant documents based on the extracted text and the spatial coordinates, the identified significant document entities, and image vector representations in the pages; extract user-defined attributes from the pages of the relevant documents using a deep learning language models that utilizes the text and spatial locations, page layout information, and the image vector representations of the pages; aggregate first attribute values associated with the user-defined attributes from at least some of the pages of the relevant documents into a single record; aggregate second attribute values associated with the user-defined attributes across the relevant documents; and write aggregated records to a database, each of the aggregated records including a first attribute value or a second attribute value.', 'Thus, the computing systems and methods disclosed herein are more effective methods for processing collected data that may, for example, correspond to a surface and a subsurface region.', 'These computing systems and methods increase data processing effectiveness, efficiency, and accuracy.', 'Such methods and computing systems may complement or replace conventional methods for processing collected data.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings.', 'In the figures:\n \nFIGS.', '1\nA, \n1\nB, \n1\nC, \n1\nD, \n2\n, \n3\nA, and \n3\nB\n illustrate simplified, schematic views of an oilfield and its operation, according to an embodiment.\n \nFIG.', '4\n illustrates an example workflow of a method for extracting text associated with user-defined attributes from multiple documents, according to an embodiment.\n \nFIG.', '5\n illustrates a flowchart of an example method for extracting text associated with user-defined attributes from multiple documents, according to an embodiment.\n \nFIG.', '6\n illustrates a method for resolving conflicts among attribute values extracted from pages of a document according to various embodiments.\n \nFIG.', '7\n illustrates a method for resolving conflicts among attribute values extracted from multiple documents according to various embodiments.\n \nFIG.', '8\n illustrates a method of processing and standardizing date attribute values, geographic attribute values, and quantity attribute values associated with a unit of measurement.\n \nFIG.', '9\n illustrates a process of performing data quality checks on attribute values extracted from multiple sources according to an embodiment.\n \nFIG.', '10\n illustrates a schematic view of a computing system, according to an embodiment.\n \n \nDESCRIPTION OF EMBODIMENTS\n \nReference will now be made in detail to embodiments, examples of which are illustrated in the accompanying drawings and figures.', 'In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the invention.', 'However, it will be apparent to one of ordinary skill in the art that the invention may be practiced without these specific details.', 'In other instances, well-known methods, procedures, components, circuits and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms are only used to distinguish one element from another.', 'For example, a first object could be termed a second object, and, similarly, a second object could be termed a first object, without departing from the scope of the invention.', 'The first object and the second object are both objects, respectively, but they are not to be considered the same object.', 'The terminology used in the description of the invention herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention.', 'As used in the description of the invention and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will also be understood that the term “and/or” as used herein refers to and encompasses any possible combinations of one or more of the associated listed items.', 'It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.', 'Attention is now directed to processing procedures, methods, techniques and workflows that are in accordance with some embodiments.', 'Some operations in the processing procedures, methods, techniques and workflows disclosed herein may be combined and/or the order of some operations may be changed.', 'FIGS.', '1\nA-\n1\nD\n illustrate simplified, schematic views of oilfield \n100\n having subterranean formation \n102\n containing reservoir \n104\n therein in accordance with implementations of various technologies and techniques described herein. \nFIG.', '1\nA\n illustrates a survey operation being performed by a survey tool, such as seismic truck \n106\na\n, to measure properties of the subterranean formation.', 'The survey operation is a seismic survey operation for producing sound vibrations.', 'In \nFIG.', '1\nA\n, one such sound vibration, e.g., sound vibration \n112\n generated by source \n110\n, reflects off horizons \n114\n in earth formation \n116\n.', "A set of sound vibrations is received by sensors, such as geophone-receivers \n118\n, situated on the earth's surface.", 'The data received \n120\n is provided as input data to a computer \n122\na \nof a seismic truck \n106\na\n, and responsive to the input data, computer \n122\na \ngenerates seismic data output \n124\n.', 'This seismic data output may be stored, transmitted or further processed as desired, for example, by data reduction.', 'FIG.', '1\nB\n illustrates a drilling operation being performed by drilling tools \n106\nb \nsuspended by rig \n128\n and advanced into subterranean formations \n102\n to form wellbore \n136\n.', 'Mud pit \n130\n is used to draw drilling mud into the drilling tools via flow line \n132\n for circulating drilling mud down through the drilling tools, then up wellbore \n136\n and back to the surface.', 'The drilling mud is typically filtered and returned to the mud pit.', 'A circulating system may be used for storing, controlling, or filtering the flowing drilling mud.', 'The drilling tools are advanced into subterranean formations \n102\n to reach reservoir \n104\n.', 'Each well may target one or more reservoirs.', 'The drilling tools are adapted for measuring downhole properties using logging while drilling tools.', 'The logging while drilling tools may also be adapted for taking core sample \n133\n as shown.', 'Computer facilities may be positioned at various locations about the oilfield \n100\n (e.g., the surface unit \n134\n) and/or at remote locations.', 'Surface unit \n134\n may be used to communicate with the drilling tools and/or offsite operations, as well as with other surface or downhole sensors.', 'Surface unit \n134\n is capable of communicating with the drilling tools to send commands to the drilling tools, and to receive data therefrom.', 'Surface unit \n134\n may also collect data generated during the drilling operation and produce data output \n135\n, which may then be stored or transmitted.', 'Sensors (S), such as gauges, may be positioned about oilfield \n100\n to collect data relating to various oilfield operations as described previously.', 'As shown, sensor (S) is positioned in one or more locations in the drilling tools and/or at rig \n128\n to measure drilling parameters, such as weight on bit, torque on bit, pressures, temperatures, flow rates, compositions, rotary speed, and/or other parameters of the field operation.', 'Sensors (S) may also be positioned in one or more locations in the circulating system.', 'Drilling tools \n106\nb \nmay include a bottom hole assembly (BHA) (not shown), generally referenced, near the drill bit (e.g., within several drill collar lengths from the drill bit).', 'The bottom hole assembly includes capabilities for measuring, processing, and storing information, as well as communicating with surface unit \n134\n.', 'The bottom hole assembly further includes drill collars for performing various other measurement functions.', 'The bottom hole assembly may include a communication subassembly that communicates with surface unit \n134\n.', 'The communication subassembly is adapted to send signals to and receive signals from the surface using a communications channel such as mud pulse telemetry, electro-magnetic telemetry, or wired drill pipe communications.', 'The communication subassembly may include, for example, a transmitter that generates a signal, such as an acoustic or electromagnetic signal, which is representative of the measured drilling parameters.', 'It will be appreciated by one of skill in the art that a variety of telemetry systems may be employed, such as wired drill pipe, electromagnetic or other known telemetry systems.', 'Typically, the wellbore is drilled according to a drilling plan that is established prior to drilling.', 'The drilling plan typically sets forth equipment, pressures, trajectories and/or other parameters that define the drilling process for the wellsite.', 'The drilling operation may then be performed according to the drilling plan.', 'However, as information is gathered, the drilling operation may need to deviate from the drilling plan.', 'Additionally, as drilling or other operations are performed, the subsurface conditions may change.', 'The earth model may also need adjustment as new information is collected\n \nThe data gathered by sensors (S) may be collected by surface unit \n134\n and/or other data collection sources for analysis or other processing.', 'The data collected by sensors (S) may be used alone or in combination with other data.', 'The data may be collected in one or more databases and/or transmitted on or offsite.', 'The data may be historical data, real time data, or combinations thereof.', 'The real time data may be used in real time, or stored for later use.', 'The data may also be combined with historical data or other inputs for further analysis.', 'The data may be stored in separate databases, or combined into a single database.', 'Surface unit \n134\n may include transceiver \n137\n to allow communications between surface unit \n134\n and various portions of the oilfield \n100\n or other locations.', 'Surface unit \n134\n may also be provided with or functionally connected to one or more controllers (not shown) for actuating mechanisms at oilfield \n100\n.', 'Surface unit \n134\n may then send command signals to oilfield \n100\n in response to data received.', 'Surface unit \n134\n may receive commands via transceiver \n137\n or may itself execute commands to the controller.', 'A processor may be provided to analyze the data (locally or remotely), make the decisions and/or actuate the controller.', 'In this manner, oilfield \n100\n may be selectively adjusted based on the data collected.', 'This technique may be used to optimize (or improve) portions of the field operation, such as controlling drilling, weight on bit, pump rates, or other parameters.', 'These adjustments may be made automatically based on computer protocol, and/or manually by an operator.', 'In some cases, well plans may be adjusted to select optimum (or improved) operating conditions, or to avoid problems.', 'FIG.', '1\nC\n illustrates a wireline operation being performed by wireline tool \n106\nc \nsuspended by rig \n128\n and into wellbore \n136\n of \nFIG.', '1\nB\n.', 'Wireline tool \n106\nc \nis adapted for deployment into wellbore \n136\n for generating well logs, performing downhole tests and/or collecting samples.', 'Wireline tool \n106\nc \nmay be used to provide another method and apparatus for performing a seismic survey operation.', 'Wireline tool \n106\nc \nmay, for example, have an explosive, radioactive, electrical, or acoustic energy source \n144\n that sends and/or receives electrical signals to surrounding subterranean formations \n102\n and fluids therein.', 'Wireline tool \n106\nc \nmay be operatively connected to, for example, geophones \n118\n and a computer \n122\na \nof a seismic truck \n106\na \nof \nFIG.', '1\nA\n.', 'Wireline tool \n106\nc \nmay also provide data to surface unit \n134\n.', 'Surface unit \n134\n may collect data generated during the wireline operation and may produce data output \n135\n that may be stored or transmitted.', 'Wireline tool \n106\nc \nmay be positioned at various depths in the wellbore \n136\n to provide a survey or other information relating to the subterranean formation \n102\n.', 'Sensors (S), such as gauges, may be positioned about oilfield \n100\n to collect data relating to various field operations as described previously.', 'As shown, sensor S is positioned in wireline tool \n106\nc \nto measure downhole parameters which relate to, for example porosity, permeability, fluid composition and/or other parameters of the field operation.', 'FIG.', '1\nD\n illustrates a production operation being performed by production tool \n106\nd \ndeployed from a production unit or Christmas tree \n129\n and into completed wellbore \n136\n for drawing fluid from the downhole reservoirs into surface facilities \n142\n.', 'The fluid flows from reservoir \n104\n through perforations in the casing (not shown) and into production tool \n106\nd \nin wellbore \n136\n and to surface facilities \n142\n via gathering network \n146\n.', 'Sensors (S), such as gauges, may be positioned about oilfield \n100\n to collect data relating to various field operations as described previously.', 'As shown, the sensor (S) may be positioned in production tool \n106\nd \nor associated equipment, such as Christmas tree \n129\n, gathering network \n146\n, surface facility \n142\n, and/or the production facility, to measure fluid parameters, such as fluid composition, flow rates, pressures, temperatures, and/or other parameters of the production operation.', 'Production may also include injection wells for added recovery.', 'One or more gathering facilities may be operatively connected to one or more of the wellsites for selectively collecting downhole fluids from the wellsite(s).', 'While \nFIGS.', '1\nB-\n1\nD\n illustrate tools used to measure properties of an oilfield, it will be appreciated that the tools may be used in connection with non-oilfield operations, such as gas fields, mines, aquifers, storage or other subterranean facilities.', 'Also, while certain data acquisition tools are depicted, it will be appreciated that various measurement tools capable of sensing parameters, such as seismic two-way travel time, density, resistivity, production rate, etc., of the subterranean formation and/or its geological formations may be used.', 'Various sensors (S) may be located at various positions along the wellbore and/or the monitoring tools to collect and/or monitor the desired data.', 'Other sources of data may also be provided from offsite locations.', 'The field configurations of \nFIGS.', '1\nA-\n1\nD\n are intended to provide a brief description of an example of a field usable with oilfield application frameworks.', 'Part of, or the entirety, of oilfield \n100\n may be on land, water and/or sea.', 'Also, while a single field measured at a single location is depicted, oilfield applications may be utilized with any combination of one or more oilfields, one or more processing facilities and one or more wellsites.\n \nFIG.', '2\n illustrates a schematic view, partially in cross section of oilfield \n200\n having data acquisition tools \n202\na\n, \n202\nb\n, \n202\nc \nand \n202\nd \npositioned at various locations along oilfield \n200\n for collecting data of subterranean formation \n204\n in accordance with implementations of various technologies and techniques described herein.', 'Data acquisition tools \n202\na\n-\n202\nd \nmay be the same as data acquisition tools \n106\na\n-\n106\nd \nof \nFIGS.', '1\nA-\n1\nD\n, respectively, or others not depicted.', 'As shown, data acquisition tools \n202\na\n-\n202\nd \ngenerate data plots or measurements \n208\na\n-\n208\nd\n, respectively.', 'These data plots are depicted along oilfield \n200\n to demonstrate the data generated by the various operations.', 'Data plots \n208\na\n-\n208\nc \nare examples of static data plots that may be generated by data acquisition tools \n202\na\n-\n202\nc\n, respectively; however, it should be understood that data plots \n208\na\n-\n208\nc \nmay also be data plots that are updated in real time.', 'These measurements may be analyzed to better define the properties of the formation(s) and/or determine the accuracy of the measurements and/or for checking for errors.', 'The plots of each of the respective measurements may be aligned and scaled for comparison and verification of the properties.', 'Static data plot \n208\na \nis a seismic two-way response over a period of time.', 'Static plot \n208\nb \nis core sample data measured from a core sample of the formation \n204\n.', 'The core sample may be used to provide data, such as a graph of the density, porosity, permeability, or some other physical property of the core sample over the length of the core.', 'Tests for density and viscosity may be performed on the fluids in the core at varying pressures and temperatures.', 'Static data plot \n208\nc \nis a logging trace that typically provides a resistivity or other measurement of the formation at various depths.', 'A production decline curve or graph \n208\nd \nis a dynamic data plot of the fluid flow rate over time.', 'The production decline curve typically provides the production rate as a function of time.', 'As the fluid flows through the wellbore, measurements are taken of fluid properties, such as flow rates, pressures, composition, etc.', 'Other data may also be collected, such as historical data, user inputs, economic information, and/or other measurement data and other parameters of interest.', 'As described below, the static and dynamic measurements may be analyzed and used to generate models of the subterranean formation to determine characteristics thereof.', 'Similar measurements may also be used to measure changes in formation aspects over time.', 'The subterranean structure \n204\n has a plurality of geological formations \n206\na\n-\n206\nd\n.', 'As shown, this structure has several formations or layers, including a shale layer \n206\na\n, a carbonate layer \n206\nb\n, a shale layer \n206\nc \nand a sand layer \n206\nd\n.', 'A fault \n207\n extends through the shale layer \n206\na \nand the carbonate layer \n206\nb\n.', 'The static data acquisition tools are adapted to take measurements and detect characteristics of the formations.', 'While a specific subterranean formation with specific geological structures is depicted, it will be appreciated that oilfield \n200\n may contain a variety of geological structures and/or formations, sometimes having extreme complexity.', 'In some locations, typically below the water line, fluid may occupy pore spaces of the formations.', 'Each of the measurement devices may be used to measure properties of the formations and/or its geological features.', 'While each acquisition tool is shown as being in specific locations in oilfield \n200\n, it will be appreciated that one or more types of measurement may be taken at one or more locations across one or more fields or other locations for comparison and/or analysis.', 'The data collected from various sources, such as the data acquisition tools of \nFIG.', '2\n, may then be processed and/or evaluated.', 'Typically, seismic data displayed in static data plot \n208\na \nfrom data acquisition tool \n202\na \nis used by a geophysicist to determine characteristics of the subterranean formations and features.', 'The core data shown in static plot \n208\nb \nand/or log data from well log \n208\nc \nare typically used by a geologist to determine various characteristics of the subterranean formation.', 'The production data from graph \n208\nd \nis typically used by the reservoir engineer to determine fluid flow reservoir characteristics.', 'The data analyzed by the geologist, geophysicist and the reservoir engineer may be analyzed using modeling techniques.\n \nFIG.', '3\nA\n illustrates an oilfield \n300\n for performing production operations in accordance with implementations of various technologies and techniques described herein.', 'As shown, the oilfield has a plurality of wellsites \n302\n operatively connected to central processing facility \n354\n.', 'The oilfield configuration of \nFIG.', '3\nA\n is not intended to limit the scope of the oilfield application system.', 'Part, or all, of the oilfield may be on land and/or sea.', 'Also, while a single oilfield with a single processing facility and a plurality of wellsites is depicted, any combination of one or more oilfields, one or more processing facilities and one or more wellsites may be present.', 'Each wellsite \n302\n has equipment that forms wellbore \n336\n into the Earth.', 'The wellbores extend through subterranean formations \n306\n including reservoirs \n304\n.', 'These reservoirs \n304\n contain fluids, such as hydrocarbons.', 'The wellsites draw fluid from the reservoirs and pass them to the processing facilities via surface networks \n344\n.', 'The surface networks \n344\n have tubing and control mechanisms for controlling the flow of fluids from the wellsite to processing facility \n354\n.', 'Attention is now directed to \nFIG.', '3\nB\n, which illustrates a side view of a marine-based survey \n360\n of a subterranean subsurface \n362\n in accordance with one or more implementations of various techniques described herein.', 'Subsurface \n362\n includes seafloor surface \n364\n.', 'Seismic sources \n366\n may include marine sources such as vibroseis or airguns, which may propagate seismic waves \n368\n (e.g., energy signals) into the Earth over an extended period of time or at a nearly instantaneous energy provided by impulsive sources.', 'The seismic waves may be propagated by marine sources as a frequency sweep signal.', 'For example, marine sources of the vibroseis type may initially emit a seismic wave at a low frequency (e.g., 5 Hz) and increase the seismic wave to a high frequency (e.g., 80-90 Hz) over time.', 'The component(s) of the seismic waves \n368\n may be reflected and converted by seafloor surface \n364\n (i.e., reflector), and seismic wave reflections \n370\n may be received by a plurality of seismic receivers \n372\n.', 'Seismic receivers \n372\n may be disposed on a plurality of streamers (i.e., streamer array \n374\n).', 'The seismic receivers \n372\n may generate electrical signals representative of the received seismic wave reflections \n370\n.', 'The electrical signals may be embedded with information regarding the subsurface \n362\n and captured as a record of seismic data.', 'In one implementation, each streamer may include streamer steering devices such as a bird, a deflector, a tail buoy and the like, which are not illustrated in this application.', 'The streamer steering devices may be used to control the position of the streamers in accordance with the techniques described herein.', 'In one implementation, seismic wave reflections \n370\n may travel upward and reach the water/air interface at the water surface \n376\n, a portion of reflections \n370\n may then reflect downward again (i.e., sea-surface ghost waves \n378\n) and be received by the plurality of seismic receivers \n372\n.', 'The sea-surface ghost waves \n378\n may be referred to as surface multiples.', 'The point on the water surface \n376\n at which the wave is reflected downward is generally referred to as the downward reflection point.', 'The electrical signals may be transmitted to a vessel \n380\n via transmission cables, wireless communication or the like.', 'The vessel \n380\n may then transmit the electrical signals to a data processing center.', 'Alternatively, the vessel \n380\n may include an onboard computer capable of processing the electrical signals (i.e., seismic data).', 'Those skilled in the art having the benefit of this disclosure will appreciate that this illustration is highly idealized.', 'For instance, surveys may be of formations deep beneath the surface.', 'The formations may typically include multiple reflectors, some of which may include dipping events, and may generate multiple reflections (including wave conversion) for receipt by the seismic receivers \n372\n.', 'In one implementation, the seismic data may be processed to generate a seismic image of the subsurface \n362\n.', 'Marine seismic acquisition systems tow each streamer in streamer array \n374\n at the same depth (e.g., 5-10 m).', 'However, marine based survey \n360\n may tow each streamer in streamer array \n374\n at different depths such that seismic data may be acquired and processed in a manner that avoids the effects of destructive interference due to sea-surface ghost waves.', 'For instance, marine-based survey \n360\n of \nFIG.', '3\nB\n illustrates eight streamers towed by vessel \n380\n at eight different depths.', 'The depth of each streamer may be controlled and maintained using the birds disposed on each streamer.', 'FIG.', '4\n illustrates an example machine learning workflow for well header attribute extraction.', 'At \n402\n, documents associated with a particular well identifier may be identified and retrieved from storage.', 'In one embodiment, the documents may be any relevant reports including, but not limited to, final well reports, completion reports, and drilling reports.', 'Next, at \n404\n, each page of the retrieved documents may be extracted into corresponding image objects.', 'Using optical character recognition (OCR) or PDF parsers, text and corresponding spatial coordinates (positions of bounding boxes surrounding text) may be extracted from the image objects at \n406\n.', 'At \n408\n, page layout analysis may be performed.', 'This may include identifying significant entities in documents and their corresponding spatial locations.', 'The significant entities may include, but not be limited to, headings, paragraphs, tables, forms, figures, and logs.', 'At \n410\n, a list of well header attributes, or alternatively, any user-defined attributes \n403\n may be used along with page layout information, including entity labels, and retrieval methods that may include, but not be limited to, term frequency-inverse document frequency (TFIDF) and Okapi best matching 25 (Okapi BM25) may be used to rank pages in a document for efficient attribute or fact extraction.', 'At \n412\n, a deep learning language model including, but not limited to, Bidirectional Encoder Representations from Transformers (BERT), variants, and probabilistic models as well as relative spatial positions of text may be used to extract attribute values or facts in a page using an extractive question-answering task or a named entity recognition task.', 'In various embodiments, each well header or other attribute to be extracted may be extracted by a query generator module using an extractive question answering task, or by a named entity recognition task.', 'In other embodiments, the image object, text, and text layout of a page can be used either by a fusion of multiple models or a single model to perform attribute value or fact extraction.', 'At \n414\n, attribute specific text parsers may be used to process and standardize extracted geographic coordinates, date-specific attributes, and units of measurement associated with quantities.', 'In some embodiments, a unit conversion module may be used to standardize attributes to a common measurement system.', 'At \n416\n, attribute values may be extracted across multiple pages in a document.', 'The extracted information may be aggregated into a single record using majority vote, confidence, page type, extraction source, as well as other information.', 'When values of a particular attribute vary among relevant pages, a majority vote may determine which value of the attribute will be aggregated.', 'The majority vote involves determining which attribute value of the particular attribute was extracted a majority of the time.', 'For example, an attribute, depth, may have an attribute value of 500 meters on one or more pages of a document, and may have an attribute value of 501 meters on one or more other pages of the document.', 'A majority vote method determines which attribute value for the attribute, depth, was extracted a majority of times from the relevant pages.', 'Confidence refers to a probability that the deep learning language model such as, for example, a transformer-based language model, extracted a correct attribute value from the relevant pages.', 'The confidence probability may be obtained from the deep learning language model or any other machine learning model architecture used for extraction in some embodiments.', 'Page type refers to whether a page includes text only, tables, figures, forms, etc.', 'Attribute values extracted from pages of a certain page type may be given a greater weight than attribute values of a same attribute extracted from other page types when determining which attribute value of an attribute to include in an aggregation.', 'Similar to page type, extracted attribute values from some extraction sources may be given a greater weight than extracted attribute values of a same attribute from other extraction sources.', 'For example, attribute values extracted from tables may be given a greater weight than attribute values extracted from a paragraph in some embodiments.', 'Thus, attribute values extracted from those greater weight extraction sources may be given a greater weight than attribute values of a same attribute extracted from lower weight extraction sources when determining which attribute value of an attribute to include in an aggregation.', 'At \n418\n, extraction aggregation of attribute values may occur across documents using document priority, confidence, and majority vote.', 'That is, document priority of a document from which an attribute value is extracted, a confidence regarding accuracy of the extracted attribute value, and a number of documents from which a same attribute value is extracted may be taken into consideration during aggregation.', 'According to some embodiments, a priority of a document from which attribute values may be extracted may determine a weight given to the extracted attribute values during aggregation.', 'Confidence, according to some embodiments, refers to an average probability that an extracted attribute value is correct as determined by the deep learning language model or any other machine learning model in other embodiments.', 'A weight of attribute values, in some embodiments, may be determined by majority vote.', 'That is, an attribute value of an attribute extracted from a greater number of documents may be given greater weight than other attribute values of a same attribute extracted from fewer documents when aggregating attribute values across documents.', 'At \n420\n, aggregated attribute values may be written to a database, which may be a well database is some embodiments.', 'FIG.', '5\n is a flowchart of an example process for extracting attribute values from documents according to embodiments.', 'The process may begin by retrieving relevant documents related to a well identifier (act \n502\n).', 'Metadata may be used to select the relevant documents in some embodiments.', 'Pages of the relevant documents related to the well identifier then may be extracted into image objects (act \n504\n).', 'Page layout analysis may be performed on the image objects to identify significant document entities in a document including, but not limited to, headings, paragraphs, tables, forms, figures, and spatial locations thereof (act \n508\n).', 'Further, text may be extracted and spatial locations of bounding boxes surrounding the text may be identified (act \n506\n).', 'In some embodiments, acts \n506\n and \n508\n may be performed in parallel.', 'Next, page ranking of pages in a document may be performed (act \n510\n).', 'In some embodiments, page ranking may be performed according to TFIDF or Okapi BM25.', 'The page ranking may be performed based on occurrences of well header attributes from a provided list of well header attributes and occurrences of entity labels that correspond to attributes from the provided list of well header attributes (act \n510\n).', 'Alternatively, page ranking may be performed based on occurrences of user-defined attributes and corresponding entity labels.', 'Page ranking can also include supplementary information like page layout information on the document entities and vector representations of the image information in the pages.', 'One or more deep learning language models such as a transformer-based language model, which may include, but not be limited to, BERT and Okapi BM25, along with relative spatial positions of text, image representations of pages, and page layout information may be used to extract facts in a page (act \n512\n).', 'In various embodiments, the facts may include attribute names and corresponding attribute values.', 'The extracted attribute values may be standardized using attribute-specific text parsers (act \n514\n).', 'For example, according to various embodiments, one or more date parsers may parse a date to produce the date in a standardized format, one or more latitude longitude parsers may parse latitude and longitude to produce the latitude and longitude in a standardized format, and measurements may be parsed by one or more quantitative parsers to produce the measurements in a standard format.', 'Page level aggregation of attribute value pairs may be performed (act \n516\n).', 'As previously mentioned, conflicting values may be resolved, according to various embodiments, by majority vote, confidence probability that an attribute value pair is correct, page type from which the attribute value pair is extracted, and extraction source (figure, table, heading, paragraph, form, etc.)', 'Next, attribute value pairs may be aggregated across documents (act \n518\n).', 'Conflicts in extracted attribute value pairs across documents may be resolved, according to some embodiments, based on priority of a source document, transformer-based language model confidence that the attribute value pair is correct, an attribute value pair occurring in a majority of documents, and a priority of an extraction source.', 'The aggregated extracted attribute value pairs then may be written to records of a database, which may be a well database in some embodiments.', 'FIG.', '6\n illustrates an example of how attribute value conflicts within pages of a document may be resolved according to some embodiments.', 'As an example, an attribute value pair may be extracted from pages A, B, and C. Suppose the attribute value pair, depth, 499 feet, is extracted from page A, the attribute value pair depth, 500 feet, is extracted from page B, and the attribute value pair depth, 500 feet, is extracted from page C. Based on a majority vote, the conflict would be resolved to depth, 500 feet.', 'Continuing with the same example, a confidence that the extracted attribute value pair is correct is obtained from the transformer-based language model being used.', 'For example, the confidence that the attribute value pair, depth, 499 feet, is correct may be 85%, while the confidence that the attribute value pair depth, 500 feet is correct may be 92%.', 'According to some embodiments, the higher the confidence probability, the greater a weight that may be applied to the attribute value pair when resolving conflicts.', 'Next, a page type of pages A, B, and C may be considered.', 'For example, page A may include a header, a table, and text, page B may include a figure, and page C may include paragraphs of text.', 'According to embodiments, attribute value pairs extracted from some page types may be given more weight than the attribute value pairs extracted from other page types.', 'Extraction source also may be considered when resolving conflicts in attribute values.', 'For example, in some embodiments, attribute values extracted from certain sources such as figures may be given more weight than attribute values extracted from a table or a paragraph.', 'Although \nFIG.', '6\n shows attribute value pairs being extracted from three different pages of a document, attribute values may be extracted from fewer than three different pages or more than three different pages.', 'FIG.', '7\n illustrates an example of how attribute value conflicts among different documents may be resolved during aggregation across documents according to some embodiments.', 'An attribute value pair may be extracted and aggregated from each of documents A, B, and C.', 'As an example, suppose the attribute value pair, depth, 499 feet, is extracted from document A, the attribute value pair, depth, 500 feet, is extracted from document B, and the attribute value pair, depth, 500 feet, is extracted from document C. Based on a majority vote, the conflict would be resolved to depth, 500 feet, because this attribute value pair occurs in a majority of documents.', 'Continuing with the same example, a confidence probability that the extracted attribute value pair is correct is obtained from a transformer-based language model being used.', 'For example, the confidence that the attribute value pair depth, 499 feet is correct may be 85%, while the confidence that the attribute value pairs, depth, 500 feet, are correct may be 92%.', 'In this example, the attribute value pair, depth, 500 feet, may be given greater weight when resolving a conflict between the attribute value pairs of, depth, 499 feet, and depth, 500 feet.', 'Next, a document priority of documents A, B, and C may be considered.', 'For example, document A may be a type of report that has a higher priority than other types of reports, or document A may be a type of report that was generated more recently than another type of report.', 'According to various embodiments, the document may have a priority based on the type of report or based on how recently the report was generated.', 'In other embodiments, document priority may be determined using other methods.', 'According to the various embodiments, attribute value pairs extracted from higher priority documents may be given more weight than the attribute value pairs extracted from lower priority documents.', 'Extraction source also may be considered when resolving conflicts in attribute values.', 'For example, in some embodiments, attribute values extracted from certain sources such as figures may be given more weight than attribute values extracted from a table or a paragraph when resolving conflicts among attribute vales of a same attribute during aggregation.', 'Although \nFIG.', '7\n shows attribute value pairs being extracted from three different documents, attribute values may be extracted from fewer than three different documents or more than three different documents.', 'FIG.', '8\n shows examples of attribute-specific parsers parsing and standardizing various attribute values according to various embodiments.', 'For example, information may be extracted from an input page \n802\n.', 'The information may include dates, positional coordinates, and measurements.', 'Dates, such as “30 may 1983”, “29/01/2002 @ 1800 hours”, and “11 Apr. 2018 @', '10:30 hrs”, respectively, may be parsed and standardized by a date parser \n804\n to produce “5/30/1983 0:00”, Jan. 29, 2002 18:00″, and “4/11/2018 10:30” according to various embodiments.', 'Positional coordinates (longitude and latitude), such as [5 degrees 50′ 51.63″ n], [104 degrees 06′ 19.43″ e], and [05 degrees 50′ 39.55″ n], respectively, may be parsed and standardized by a latitude longitude parser \n806\n to “5.847675”, “104.1053972”, and “5.844319444” according to various embodiments.', 'Measurements, such as “120 ft”, “140.4 ft”, and “30.6m”, respectively, may be parsed and standardized by a quantitative parser \n808\n to “[120, foot]”, “[140.4, foot]”, and “[30.6, meter]” according to various embodiments.', 'FIG.', '9\n shows example data quality checks that may be performed in some embodiments.', 'Attribute value pairs extracted from relevant pages (shown in gray) of multiple documents may be checked for data quality according to some embodiments.', 'For example, attribute values may be checked for values that are out of range.', 'As an example, if a valid range includes 1 through 100, a value of less than 1 or greater than 100 would be determined to be out of range.', 'Dates may be checked to determine that an order in which a sequence of events is generated as expected.', 'For example, in a field of oil drilling, a well spud is expected to have an earlier date than a drilling completion date.', 'Dimension checks also may be performed on attribute values according to some embodiments.', 'For example, attribute values related to measurements may be checked to determine if these attribute values use certain specific units of measurement such as, for example, meters, feet, miles, kilometers, etc.', 'If units of measurements other than the certain specific units of measurement are detected, then a corresponding attribute value fails the dimension check.', 'In various embodiments, attribute values that fail any of the data quality checks may be discarded.', 'Otherwise, attribute values that pass the data quality checks may be aggregated, and conflicting attribute values may be resolved using, for example, majority vote, confidence probability, and source priority as previously discussed to produce a finalized value.', 'In some embodiments, conflicting attribute values also may be resolved based on source metadata such as, for example, attribute name or other source metadata.', 'In one or more embodiments, the functions described can be implemented in hardware, software, firmware, or any combination thereof.', 'For a software implementation, the techniques described herein can be implemented with modules (e.g., procedures, functions, subprograms, programs, routines, subroutines, modules, software packages, classes, and so on) that perform the functions described herein.', 'A module can be coupled to another module or a hardware circuit by passing and/or receiving information, data, arguments, parameters, or memory contents.', 'Information, arguments, parameters, data, or the like can be passed, forwarded, or transmitted using any suitable means including memory sharing, message passing, token passing, network transmission, and the like.', 'The software code can be stored in memory units and executed by processors.', 'The memory unit can be implemented within the processor or external to the processor, in which case it can be communicatively coupled to the processor via various means as is known in the art.', 'In some embodiments, any of the methods of the present disclosure may be executed using a system, such as a computing system.', 'FIG.', '10\n illustrates an example of such a computing system \n1000\n, in accordance with some embodiments.', 'The computing system \n1000\n may include a computer or computer system \n1001\na\n, which may be an individual computer system \n1001\na \nor an arrangement of distributed computer systems.', 'The computer system \n1001\na \nincludes one or more analysis module(s) \n1002\n configured to perform various tasks according to some embodiments, such as one or more methods disclosed herein.', 'To perform these various tasks, the analysis module \n1002\n executes independently, or in coordination with, one or more processors \n1004\n, which is (or are) connected to one or more storage media \n1006\n.', 'The processor(s) \n1004\n is (or are) also connected to a network interface \n1007\n to allow the computer system \n1001\na \nto communicate over a data network \n1009\n with one or more additional computer systems and/or computing systems, such as \n1001\nb\n, \n1001\nc\n, and/or \n1001\nd \n(note that computer systems \n1001\nb\n, \n1001\nc \nand/or \n1001\nd \nmay or may not share the same architecture as computer system \n1001\na\n, and may be located in different physical locations, e.g., computer systems \n1001\na \nand \n1001\nb \nmay be located in a processing facility, while in communication with one or more computer systems such as \n1001\nc \nand/or \n1001\nd \nthat are located in one or more data centers, and/or located in varying countries on different continents).', 'A processor can include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'The storage media \n1006\n can be implemented as one or more computer-readable or machine-readable storage media.', 'Note that while in the example embodiment of \nFIG.', '10\n storage media \n1006\n is depicted as within computer system \n1001\na\n, in some embodiments, storage media \n1006\n may be distributed within and/or across multiple internal and/or external enclosures of computing system \n1001\na \nand/or additional computing systems.', 'Storage media \n1006\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLURAY® disks, or other types of optical storage, or other types of storage devices.', 'Note that the instructions discussed above can be provided on one computer-readable or machine-readable storage medium, or alternatively, can be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture).', 'An article or article of manufacture can refer to any manufactured single component or multiple components.', 'The storage medium or media can be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions can be downloaded over a network for execution.', 'In some embodiments, computing system \n1000\n contains one or more extraction module(s) \n1008\n.', 'In some embodiments, a single extraction module \n1008\n may be used to perform some or all aspects of one or more embodiments of the methods.', 'In alternate embodiments, a plurality of extraction modules \n1008\n may be used to perform some or all aspects of methods.', 'It should be appreciated that computing system \n1000\n is only one example of a computing system, and that computing system \n1000\n may have more or fewer components than shown, may combine additional components not depicted in the example embodiment of \nFIG.', '10\n, and/or computing system \n1000\n may have a different configuration or arrangement of the components depicted in \nFIG. \n10\n.', 'The various components shown in \nFIG.', '10\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'Further, the steps in the processing methods described herein may be implemented by running one or more functional modules in information processing apparatus such as general purpose processors or application specific chips, such as ASICs, FPGAs, PLDs, or other appropriate devices.', 'These modules, combinations of these modules, and/or their combination with general hardware are all included within the scope of protection of the invention.', 'Geologic interpretations, models and/or other interpretation aids may be refined in an iterative fashion; this concept is applicable to embodiments of the present methods discussed herein.', 'This can include use of feedback loops executed on an algorithmic basis, such as at a computing device (e.g., computing system \n1000\n, \nFIG. \n10\n), and/or through manual control by a user who may make determinations regarding whether a given step, action, template, model, or set of curves has become sufficiently accurate for the evaluation of the subsurface three-dimensional geologic formation under consideration.', 'The foregoing description, for purpose of explanation, has been described with reference to specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or to limit the invention to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'Moreover, the order in which the elements of the methods are illustrated and described may be re-arranged, and/or two or more elements may occur simultaneously.', 'Further, in some embodiments, instead of retrieving documents related to a particular well identifier, documents may be retrieved based on another attribute value of combination of attribute values.', 'The embodiments were chosen and described in order to best explain the principles of the invention and its practical applications, to thereby enable others skilled in the art to best utilize the invention and various embodiments with various modifications as are suited to the particular use contemplated.']

['1.', 'A method for extracting text associated with user-defined attributes from a plurality of documents, the method comprising:\nidentifying relevant documents related to a specific entity from storage based on document metadata;\nextracting text and spatial coordinates of the text based on pages of the relevant documents;\nidentifying significant document entities and associated spatial locations of the significant document entities based on the pages of the relevant documents through page layout analysis;\nranking the pages of the relevant documents based on the extracted text and the spatial coordinates, the identified significant document entities, and image vector representations of the pages;\nextracting the user-defined attributes from the pages of the relevant documents using a deep learning language model that utilizes the text and the spatial coordinates, layout information of the document entities, and the image vector representations of the pages;\naggregating first attribute values associated with the user-defined attributes from at least some of the pages of one of the relevant documents into a single record;\naggregating second attribute values associated with the user-defined attributes across the relevant documents;\naggregating, by the computing device, an attribute value across multiple sources based on at least one of a majority vote from among the multiple sources, a confidence probability of the attribute value from among the multiple sources, source metadata, and source priority; and\nwriting aggregated records to a database, each of the aggregated records including a first attribute value or a second attribute value.', '2.', 'The method of claim 1, further comprising processing, by attribute-specific parsers executing on a computing device, extracted geographic coordinates, date-specific attributes, and quantities associated with units of measurement.', '3.', 'The method of claim 1, wherein the specific entity is either a specific oil well or is associated with one from a group consisting of a wellbore, a field, a basin, and a prospect, wherein the prospect is an area of exploration in which hydrocarbons are predicted to exist.', '4.', 'The method of claim 3, wherein the relevant documents are reports related to the specific oil well.', '5.', 'The method of claim 1, wherein: the ranking further comprises ranking the pages of the relevant documents based on at least one retrieval method, and the at least one retrieval method includes at least one of term frequency-inverse document frequency (TFIDF) and Okapi Best Match 25 (Okapi BM25).', '6.', 'The method of claim 1, wherein the significant document entities comprise headings, paragraphs, tables, forms, figures, and logs.', '7.', 'The method of claim 1, wherein: the user-defined attributes are entity-specific attributes, and each of the user-defined attributes is extracted by at least one of a named entity recognition task and an extractive question-answering task.', '8.', 'A computer system for extracting text associated with user-defined attributes from a plurality of documents, the computer system comprising:\nat least one processor; and\nat least one memory connected with the at least one processor, the at least one processor being configured to perform a plurality of operations comprising:\nidentifying relevant documents related to a specific entity from storage based on document metadata;\nextracting text and spatial coordinates of the text based on pages of the relevant documents;\nidentifying significant document entities and associated spatial locations of the significant document entities based on the pages of the relevant documents through page layout analysis;\nranking the pages of the relevant documents based on the extracted text and the spatial coordinates, the identified significant document entities, and the image vector representations of the pages;\nextracting user-defined attributes from the pages of the relevant documents using a deep learning language model that utilizes the text and the spatial coordinates, layout information of the document entities, and the image vector representations of the pages;\naggregating first attribute values associated with the user-defined attributes from at least some of the pages of the relevant documents into a single record;\naggregating second attribute values associated with the user-defined attributes across the relevant documents;\naggregating, by the computing device, an attribute value across multiple sources based on at least one of a majority vote from among the multiple sources, a confidence probability of the attribute value from among the multiple sources, source metadata, and source priority; and\nwriting aggregated records to a database, each of the aggregated records including a first attribute value or a second attribute value.\n\n\n\n\n\n\n9.', 'The computer system of claim 8, wherein the plurality of operations further comprise processing, by attribute-specific parsers, extracted geographic coordinates, date-specific attributes, and quantities associated with units of measurements.', '10.', 'The computer system of claim 8, wherein the specific entity is either a specific oil well or is associated with one from a group consisting of a wellbore, a field, a basin, and a prospect, wherein the prospect is an area of exploration in which hydrocarbons are predicted to exist.', '11.', 'The computer system of claim 10, wherein the relevant documents are reports related to the specific oil well.', '12.', 'The computer system of claim 8, wherein: the ranking further comprises ranking the pages of the relevant documents based on at least one retrieval method, and the at least one retrieval method includes at least one of term frequency-inverse document frequency (TFIDF) and Okapi Best Match 25 (Okapi BM25).', '13.', 'The computer system of claim 8, wherein the significant document entities comprise headings paragraphs, tables, forms, figures, and logs.', '14.', 'The computer system of claim 8, wherein: the user-defined attributes are entity-specific attributes, and each of the user-defined attributes is extracted by at least one of a named entity recognition task and an extractive question-answering task.', '15.', 'A non-transitory computer-readable medium having instructions for a processor recorded thereon to configure the processor to perform a plurality of operations comprising:\nidentifying relevant documents related to a specific entity from storage based on document metadata;\nextracting text and spatial coordinates of the text from based on pages of the relevant documents;\nidentifying significant document entities and associated spatial locations of the significant document entities based on the pages of the relevant documents through page layout analysis;\nranking the pages of the relevant documents based on the extracted text and the spatial coordinates, the identified significant document entities, and the image vector representations of the pages;\nextracting user-defined attributes from the pages of the relevant documents based on using a deep learning language model that utilizes the text and the spatial coordinates, layout information of the document entities, and the image vector representations of the pages;\naggregating first attribute values associated with the user-defined attributes from at least some of the pages of the relevant documents into a single record;\naggregating, by the computing device, second attribute values associated with the user-defined attributes across the relevant documents;\naggregating, by the computing device, an attribute value across multiple sources based on at least one of a majority vote from among the multiple sources, a confidence probability of the attribute value from among the multiple sources, source metadata, and source priority; and\nwriting aggregated records to a database, each of the aggregated records including a first attribute value or a second attribute value.', '16.', 'The non-transitory computer-readable medium of claim 15, wherein the plurality of operations further comprise processing, by attribute-specific parsers, extracted geographic coordinates, date-specific attributes, and quantities associated with units of measurements.\n\n\n\n\n\n\n17.', 'The non-transitory computer-readable medium of claim 15, wherein the specific entity is either a specific oil well or is associated with one from a group consisting of a wellbore, a field, a basin, and a prospect, wherein the prospect is an area or exploration in which hydrocarbons are predicted to exist.', '18.', 'The non-transitory computer-readable medium of claim 17, wherein the relevant documents are reports related to the specific oil well.', '19.', 'The non-transitory computer-readable medium of claim 15, wherein: the ranking further comprises ranking the pages of the relevant documents based on at least one retrieval method, and the at least one retrieval method includes at least one of term frequency-inverse document frequency (TFIDF) and Okapi Best Match 25 (Okapi BM25).', '20.', 'The non-transitory computer-readable medium of claim 15, wherein the significant entities comprise headings paragraphs, tables, forms, figures, and logs.', '21.', 'The non-transitory computer-readable medium of claim 15, wherein: the user-defined attributes are entity-specific attributes, and each of the user-defined attributes is extracted by at least one of a named entity recognition task and an extractive question-answering task.']

['FIGS.', '1A, 1B, 1C, 1D, 2, 3A, and 3B illustrate simplified, schematic views of an oilfield and its operation, according to an embodiment.; FIG.', '4 illustrates an example workflow of a method for extracting text associated with user-defined attributes from multiple documents, according to an embodiment.; FIG.', '5 illustrates a flowchart of an example method for extracting text associated with user-defined attributes from multiple documents, according to an embodiment.; FIG.', '6 illustrates a method for resolving conflicts among attribute values extracted from pages of a document according to various embodiments.; FIG.', '7 illustrates a method for resolving conflicts among attribute values extracted from multiple documents according to various embodiments.; FIG.', '8 illustrates a method of processing and standardizing date attribute values, geographic attribute values, and quantity attribute values associated with a unit of measurement.; FIG.', '9 illustrates a process of performing data quality checks on attribute values extracted from multiple sources according to an embodiment.; FIG.', '10 illustrates a schematic view of a computing system, according to an embodiment.; FIGS.', '1A-1D illustrate simplified, schematic views of oilfield 100 having subterranean formation 102 containing reservoir 104 therein in accordance with implementations of various technologies and techniques described herein.', 'FIG.', '1A illustrates a survey operation being performed by a survey tool, such as seismic truck 106a, to measure properties of the subterranean formation.', 'The survey operation is a seismic survey operation for producing sound vibrations.', 'In FIG.', '1A, one such sound vibration, e.g., sound vibration 112 generated by source 110, reflects off horizons 114 in earth formation 116.', "A set of sound vibrations is received by sensors, such as geophone-receivers 118, situated on the earth's surface.", 'The data received 120 is provided as input data to a computer 122a of a seismic truck 106a, and responsive to the input data, computer 122a generates seismic data output 124.', 'This seismic data output may be stored, transmitted or further processed as desired, for example, by data reduction.;', 'FIG.', '1B illustrates a drilling operation being performed by drilling tools 106b suspended by rig 128 and advanced into subterranean formations 102 to form wellbore 136.', 'Mud pit 130 is used to draw drilling mud into the drilling tools via flow line 132 for circulating drilling mud down through the drilling tools, then up wellbore 136 and back to the surface.', 'The drilling mud is typically filtered and returned to the mud pit.', 'A circulating system may be used for storing, controlling, or filtering the flowing drilling mud.', 'The drilling tools are advanced into subterranean formations 102 to reach reservoir 104.', 'Each well may target one or more reservoirs.', 'The drilling tools are adapted for measuring downhole properties using logging while drilling tools.', 'The logging while drilling tools may also be adapted for taking core sample 133 as shown.; FIG.', '1C illustrates a wireline operation being performed by wireline tool 106c suspended by rig 128 and into wellbore 136 of FIG.', '1B. Wireline tool 106c is adapted for deployment into wellbore 136 for generating well logs, performing downhole tests and/or collecting samples.', 'Wireline tool 106c may be used to provide another method and apparatus for performing a seismic survey operation.', 'Wireline tool 106c may, for example, have an explosive, radioactive, electrical, or acoustic energy source 144 that sends and/or receives electrical signals to surrounding subterranean formations 102 and fluids therein.;', 'FIG.', '1D illustrates a production operation being performed by production tool 106d deployed from a production unit or Christmas tree 129 and into completed wellbore 136 for drawing fluid from the downhole reservoirs into surface facilities 142.', 'The fluid flows from reservoir 104 through perforations in the casing (not shown) and into production tool 106d in wellbore 136 and to surface facilities 142 via gathering network 146.; FIG.', '2 illustrates a schematic view, partially in cross section of oilfield 200 having data acquisition tools 202a, 202b, 202c and 202d positioned at various locations along oilfield 200 for collecting data of subterranean formation 204 in accordance with implementations of various technologies and techniques described herein.', 'Data acquisition tools 202a-202d may be the same as data acquisition tools 106a-106d of FIGS.', '1A-1D, respectively, or others not depicted.', 'As shown, data acquisition tools 202a-202d generate data plots or measurements 208a-208d, respectively.', 'These data plots are depicted along oilfield 200 to demonstrate the data generated by the various operations.', ';', 'FIG.', '3A illustrates an oilfield 300 for performing production operations in accordance with implementations of various technologies and techniques described herein.', 'As shown, the oilfield has a plurality of wellsites 302 operatively connected to central processing facility 354.', 'The oilfield configuration of FIG.', '3A is not intended to limit the scope of the oilfield application system.', 'Part, or all, of the oilfield may be on land and/or sea.', 'Also, while a single oilfield with a single processing facility and a plurality of wellsites is depicted, any combination of one or more oilfields, one or more processing facilities and one or more wellsites may be present.; FIG.', '4 illustrates an example machine learning workflow for well header attribute extraction.', 'At 402, documents associated with a particular well identifier may be identified and retrieved from storage.', 'In one embodiment, the documents may be any relevant reports including, but not limited to, final well reports, completion reports, and drilling reports.; FIG.', '5 is a flowchart of an example process for extracting attribute values from documents according to embodiments.', 'The process may begin by retrieving relevant documents related to a well identifier (act 502).', 'Metadata may be used to select the relevant documents in some embodiments.', 'Pages of the relevant documents related to the well identifier then may be extracted into image objects (act 504).', 'Page layout analysis may be performed on the image objects to identify significant document entities in a document including, but not limited to, headings, paragraphs, tables, forms, figures, and spatial locations thereof (act 508).', 'Further, text may be extracted and spatial locations of bounding boxes surrounding the text may be identified (act 506).', 'In some embodiments, acts 506 and 508 may be performed in parallel.; FIG.', '6 illustrates an example of how attribute value conflicts within pages of a document may be resolved according to some embodiments.', 'As an example, an attribute value pair may be extracted from pages A, B, and C. Suppose the attribute value pair, depth, 499 feet, is extracted from page A, the attribute value pair depth, 500 feet, is extracted from page B, and the attribute value pair depth, 500 feet, is extracted from page C. Based on a majority vote, the conflict would be resolved to depth, 500 feet.;', 'FIG. 7 illustrates an example of how attribute value conflicts among different documents may be resolved during aggregation across documents according to some embodiments.', 'An attribute value pair may be extracted and aggregated from each of documents A, B, and C.', 'As an example, suppose the attribute value pair, depth, 499 feet, is extracted from document A, the attribute value pair, depth, 500 feet, is extracted from document B, and the attribute value pair, depth, 500 feet, is extracted from document C. Based on a majority vote, the conflict would be resolved to depth, 500 feet, because this attribute value pair occurs in a majority of documents.; FIG.', '8 shows examples of attribute-specific parsers parsing and standardizing various attribute values according to various embodiments.', 'For example, information may be extracted from an input page 802.', 'The information may include dates, positional coordinates, and measurements.', 'Dates, such as “30 may 1983”, “29/01/2002 @ 1800 hours”, and “11 Apr. 2018 @', '10:30 hrs”, respectively, may be parsed and standardized by a date parser 804 to produce “5/30/1983 0:00”, Jan. 29, 2002 18:00″, and “4/11/2018 10:30” according to various embodiments.', 'Positional coordinates (longitude and latitude), such as [5 degrees 50′ 51.63″ n], [104 degrees 06′ 19.43″ e], and [05 degrees 50′ 39.55″ n], respectively, may be parsed and standardized by a latitude longitude parser 806 to “5.847675”, “104.1053972”, and “5.844319444” according to various embodiments.', 'Measurements, such as “120 ft”, “140.4 ft”, and “30.6m”, respectively, may be parsed and standardized by a quantitative parser 808 to “[120, foot]”, “[140.4, foot]”, and “[30.6, meter]” according to various embodiments.', '; FIG.', '9 shows example data quality checks that may be performed in some embodiments.', 'Attribute value pairs extracted from relevant pages (shown in gray) of multiple documents may be checked for data quality according to some embodiments.', 'For example, attribute values may be checked for values that are out of range.', 'As an example, if a valid range includes 1 through 100, a value of less than 1 or greater than 100 would be determined to be out of range.', 'Dates may be checked to determine that an order in which a sequence of events is generated as expected.', 'For example, in a field of oil drilling, a well spud is expected to have an earlier date than a drilling completion date.', 'Dimension checks also may be performed on attribute values according to some embodiments.', 'For example, attribute values related to measurements may be checked to determine if these attribute values use certain specific units of measurement such as, for example, meters, feet, miles, kilometers, etc.', 'If units of measurements other than the certain specific units of measurement are detected, then a corresponding attribute value fails the dimension check.', 'In various embodiments, attribute values that fail any of the data quality checks may be discarded.', 'Otherwise, attribute values that pass the data quality checks may be aggregated, and conflicting attribute values may be resolved using, for example, majority vote, confidence probability, and source priority as previously discussed to produce a finalized value.', 'In some embodiments, conflicting attribute values also may be resolved based on source metadata such as, for example, attribute name or other source metadata.']

US11907300

Geologic formation operations relational framework

Jul 15, 2020

Todd Christopher Dixon, Andrei Ionescu, Sanjeet Khanuja

SCHLUMBERGER TECHNOLOGY CORPORATION

Deterministic and Probabilistic Implementation of Context, Brdiczka et al.(Year: 2006).

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WO-2018034656; February 2018; WO; WO-2018165124; September 2018; WO

['A method can include accessing data generated during field operations; generating a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and generating a query result using the graph responsive to receipt of a query.']

['Description\n\n\n\n\n\n\nThis application claims the benefit of India Patent Application No. 201921028840 filed on Jul. 17, 2019, and is hereby incorporated by reference in its entirety.', 'BACKGROUND\n \nVarious field operations can be performed with respect to a geologic formation.', 'Such operations can include exploration operations, development operations, production operations, etc., with respect to a reservoir in the geologic formation.', 'As an example, an operation can be a seismic survey that utilizes equipment to acquire a seismic data set as measured and recorded with reference to a particular area of the Earth, for example, to evaluate a subsurface formation.', 'A seismic survey can be acquired using one or more of surface, ocean/sea bottom, marine, borehole, land or other technology.', 'A seismic survey can acquire a seismic data set or sets, which can be spatial (e.g., 1D, 2D or 3D) or spatial and temporal (e.g., 1D, 2D or 3D in space and 1D in time).', 'Seismic data can be visualized by processing and rendering to a display where an interpreter can identify and select boundaries that can are representative of structure(s) in the Earth (e.g. reflectors, etc.).', 'As an example, an “Earth model” may be constructed using interpreted seismic data and optionally one or more other types of data.', 'For example, consider constructing an Earth model that represents a reservoir using seismic data and exploratory borehole data and performing a simulation of physical phenomena (e.g., fluid flow, etc.) using a reservoir simulator.', 'Results of a simulator can indicate a possible target that may be reached by drilling a borehole into the formation where the borehole can be completed to form a well that can produce fluid from the reservoir.', 'As an example, an operation can be a drilling operation where a borehole can be drilled into a geologic formation where the bore may be utilized to form a well.', 'As an example, an operation can be a logging operation, which may be a wireline logging operation, a logging while drilling operation or another type of logging operation.', 'After a borehole is formed by drilling, a formation is exposed via the borehole, which provides an opportunity to utilize one or more logging tools to acquire measurements (e.g., via sensors) that can be processed to determine properties of the formation (e.g., rock properties, fluid properties, etc.).', 'As an example, logging may be performed before, during or after casing, cementing, fracturing, treating, etc.', 'As an example, a cased-hole logging tool may include equipment to measure fluid flow rates and/or one or more other production parameters in a wellbore or, for example, to examine integrity of a casing and/or cement.', 'A rig can be a system of components that can be operated to form a borehole in a geologic formation, to transport equipment into and out of a bore in a geologic formation, etc.', 'As an example, a rig may include a system that can be used to drill a bore and to acquire information about a geologic formation, drilling, etc.', 'As an example, a rig configured for drilling can include one or more of the following components and/or equipment: a mud tank, a mud pump, a derrick or a mast, drawworks, a rotary table or a top drive, a drillstring, power generation equipment and auxiliary equipment.', 'As an example, an offshore rig may include one or more of such components, which may be on a vessel or a drilling platform.', 'As an example, a rotary steerable system (RSS) can be utilized to drill directionally.', 'An RSS can include a bottom hole assembly (BHA) that includes features that provide for directional drilling.', 'As an example, a rig or other surface equipment (e.g., onshore or offshore) may be utilized to perform one or more other types of operations, which can include logging operations.', 'SUMMARY\n \nA method can include accessing data generated during field operations; generating a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and generating a query result using the graph responsive to receipt of a query.', 'A system can include a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: access data generated during field operations; generate a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and generate a query result using the graph responsive to receipt of a query.', 'One or more computer-readable storage media can include computer-executable instructions executable to instruct a computing system to: access data generated during field operations; generate a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and generate a query result using the graph responsive to receipt of a query.', 'Various other apparatuses, systems, methods, etc., are also disclosed.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFeatures and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.\n \nFIG.', '1\n illustrates examples of equipment in a geologic environment;\n \nFIG.', '2\n illustrates an example of a system and examples of types of holes;\n \nFIG.', '3\n illustrates an example of a system;\n \nFIG.', '4\n illustrates an example of a system;\n \nFIG.', '5\n illustrates an example of a system;\n \nFIG.', '6\n illustrates an example of a graphical user interface;\n \nFIG.', '7\n illustrates an example of a graphical user interface;\n \nFIG.', '8\n illustrates an example of a system;\n \nFIG.', '9\n illustrates an example of a method;\n \nFIG.', '10\n illustrates an example of a graphical user interface;\n \nFIG.', '11\n illustrates an example of a graphical user interface;\n \nFIG.', '12\n illustrates an example of a graphical user interface;\n \nFIG.', '13\n illustrates an example of a system;\n \nFIG.', '14\n illustrates an example of a framework;\n \nFIG.', '15\n illustrates an example of a graphical user interface;\n \nFIG.', '16\n illustrates an example of a graphical user interface;\n \nFIG.', '17\n illustrates an example of a graphical user interface;\n \nFIG.', '18\n illustrates an example of a graphical user interface;\n \nFIG.', '19\n illustrates an example of a graphical user interface;\n \nFIG.', '20\n illustrates examples of computing and networking equipment; and\n \nFIG.', '21\n illustrates example components of a system and a networked system.', 'DETAILED DESCRIPTION', 'The following description includes embodiments of the best mode presently contemplated for practicing the described implementations.', 'This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.', 'Various operations can be performed in a field.', 'For example, consider exploration as an initial phase in petroleum operations that includes generation of a prospect or play or both, and drilling of an exploration well or borehole.', 'Appraisal, development and production phases may follow successful exploration.', 'A borehole may be referred to as a wellbore and can include an openhole portion or an uncased portion and/or may include a cased portion.', 'A borehole may be defined by a bore wall that is composed of a rock that bounds the borehole.', 'As to a well or borehole, whether for one or more of exploration, sensing, production, injection or other operation(s), it can be planned.', 'Such a process may be referred to generally as well planning, a process by which a path can be mapped in a geologic environment.', 'Such a path may be referred to as a trajectory, which can include coordinates in a three-dimensional coordinate system where a measure along the trajectory may be a measured depth, a total vertical depth or another type of measure.', 'During drilling, wireline investigations, etc., equipment may be moved into and/or out of a well or borehole.', 'Such operations can occur over time and may differ with respect to time.', 'A planning process may call for performing various operations, which may be serial, parallel, serial and parallel, etc.', 'As an example, a well plan can be generated based at least in part on imposed constraints and known information.', 'As an example, a well plan may be provided to a well owner, approved, and then implemented by a drilling service provider (e.g., a directional driller or “DD”).', 'In such an example, a rig may be used to drill, for example, according to a well plan.', 'During a period of time during which a well plan is implemented, a rig may transition from one state to another state, which may be referred to as rigstates.', 'As an example, a state may be a drilling state or may be a state where drilling into a formation (e.g., rock) is not occurring (e.g., an idle state, a tripping-in state, a tripping-out state, etc.).', 'As an example, a well design system can account for one or more capabilities of a drilling system or drilling systems that may be utilized at a wellsite.', 'As an example, a drilling engineer may be called upon to take such capabilities into account, for example, as one or more of various designs and specifications are created.', 'As an example, a state such as a rigstate may correspond to a capability, for example, while the capability is being utilized.', 'As an example, a well design system, which may be a well planning system, may take into account automation.', 'For example, where a wellsite includes wellsite equipment that can be automated, for example, via a local and/or a remote automation command, a well plan may be generated in digital form that can be utilized in a well drilling system where at least some amount of automation is possible and desired.', 'For example, a digital well plan can be accessible by a well drilling system where information in the digital well plan can be utilized via one or more automation mechanisms of the well drilling system to automate one or more operations at a wellsite.\n \nFIG.', '1\n shows an example of a geologic environment \n120\n.', 'In \nFIG.', '1\n, the geologic environment \n120\n may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir \n121\n and that may be, for example, intersected by a fault \n123\n (e.g., or faults).', 'As an example, the geologic environment \n120\n may be outfitted with a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n122\n may include communication circuitry to receive and/or to transmit information with respect to one or more networks \n125\n.', 'Such information may include information associated with downhole equipment \n124\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n126\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more pieces of equipment may provide for measurement, collection, communication, storage, analysis, etc. of data (e.g., for one or more produced resources, etc.).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, geolocation, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n125\n that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n120\n as optionally including equipment \n127\n and \n128\n associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures \n129\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n127\n and/or \n128\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, injection, production, etc.', 'As an example, the equipment \n127\n and/or \n128\n may provide for measurement, collection, communication, storage, analysis, etc. of data such as, for example, production data (e.g., for one or more produced resources).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.\n \nFIG.', '1\n also shows an example of equipment \n170\n and an example of equipment \n180\n.', 'Such equipment, which may be systems of components, may be suitable for use in the geologic environment \n120\n.', 'While the equipment \n170\n and \n180\n are illustrated as land-based, various components may be suitable for use in an offshore system.', 'As shown in \nFIG.', '1\n, the equipment \n180\n can be mobile as carried by a vehicle; noting that the equipment \n170\n can be assembled, disassembled, transported and re-assembled, etc.', 'The equipment \n170\n includes a platform \n171\n, a derrick \n172\n, a crown block \n173\n, a line \n174\n, a traveling block assembly \n175\n, drawworks \n176\n and a landing \n177\n (e.g., a monkeyboard).', 'As an example, the line \n174\n may be controlled at least in part via the drawworks \n176\n such that the traveling block assembly \n175\n travels in a vertical direction with respect to the platform \n171\n.', 'For example, by drawing the line 174 in, the drawworks \n176\n may cause the line \n174\n to run through the crown block \n173\n and lift the traveling block assembly \n175\n skyward away from the platform \n171\n; whereas, by allowing the line \n174\n out, the drawworks \n176\n may cause the line \n174\n to run through the crown block \n173\n and lower the traveling block assembly \n175\n toward the platform \n171\n.', 'Where the traveling block assembly \n175\n carries pipe (e.g., casing, etc.)', ', tracking of movement of the traveling block \n175\n may provide an indication as to how much pipe has been deployed.', 'A derrick can be a structure used to support a crown block and a traveling block operatively coupled to the crown block at least in part via line.', 'A derrick may be pyramidal in shape and offer a suitable strength-to-weight ratio.', 'A derrick may be movable as a unit or in a piece by piece manner (e.g., to be assembled and disassembled).', 'As an example, drawworks may include a spool, brakes, a power source and assorted auxiliary devices.', 'Drawworks may controllably reel out and reel in line.', 'Line may be reeled over a crown block and coupled to a traveling block to gain mechanical advantage in a “block and tackle” or “pulley” fashion.', 'Reeling out and in of line can cause a traveling block (e.g., and whatever may be hanging underneath it), to be lowered into or raised out of a bore.', 'Reeling out of line may be powered by gravity and reeling in by a motor, an engine, etc.', '(e.g., an electric motor, a diesel engine, etc.).', 'As an example, a crown block can include a set of pulleys (e.g., sheaves) that can be located at or near a top of a derrick or a mast, over which line is threaded.', 'A traveling block can include a set of sheaves that can be moved up and down in a derrick or a mast via line threaded in the set of sheaves of the traveling block and in the set of sheaves of a crown block.', 'A crown block, a traveling block and a line can form a pulley system of a derrick or a mast, which may enable handling of heavy loads (e.g., drillstring, pipe, casing, liners, etc.) to be lifted out of or lowered into a bore.', 'As an example, line may be about a centimeter to about five centimeters in diameter as, for example, steel cable.', 'Through use of a set of sheaves, such line may carry loads heavier than the line could support as a single strand.', 'As an example, a derrick person may be a rig crew member that works on a platform attached to a derrick or a mast.', 'A derrick can include a landing on which a derrick person may stand.', 'As an example, such a landing may be about 10 meters or more above a rig floor.', 'In an operation referred to as trip out of the hole (TOH), a derrick person may wear a safety harness that enables leaning out from the work landing (e.g., monkeyboard) to reach pipe in located at or near the center of a derrick or a mast and to throw a line around the pipe and pull it back into its storage location (e.g., fingerboards), for example, until it a time at which it may be desirable to run the pipe back into the bore.', 'As an example, a rig may include automated pipe-handling equipment such that the derrick person controls the machinery rather than physically handling the pipe.', 'As an example, a trip may refer to the act of pulling equipment from a bore and/or placing equipment in a bore.', 'As an example, equipment may include a drillstring that can be pulled out of the hole and/or place or replaced in the hole.', 'As an example, a pipe trip may be performed where a drill bit has dulled or has otherwise ceased to drill efficiently and is to be replaced.\n \nFIG.', '2\n shows an example of a wellsite system \n200\n (e.g., at a wellsite that may be onshore or offshore).', 'As shown, the wellsite system \n200\n can include a mud tank \n201\n for holding mud and other material (e.g., where mud can be a drilling fluid), a suction line \n203\n that serves as an inlet to a mud pump \n204\n for pumping mud from the mud tank \n201\n such that mud flows to a vibrating hose \n206\n, a drawworks \n207\n for winching drill line or drill lines \n212\n, a standpipe \n208\n that receives mud from the vibrating hose \n206\n, a kelly hose \n209\n that receives mud from the standpipe \n208\n, a gooseneck or goosenecks \n210\n, a traveling block \n211\n, a crown block \n213\n for carrying the traveling block \n211\n via the drill line or drill lines \n212\n (see, e.g., the crown block \n173\n of \nFIG. \n1\n), a derrick \n214\n (see, e.g., the derrick \n172\n of \nFIG. \n1\n), a kelly \n218\n or a top drive \n240\n, a kelly drive bushing \n219\n, a rotary table \n220\n, a drill floor \n221\n, a bell nipple \n222\n, one or more blowout preventors (BOPs) \n223\n, a drillstring \n225\n, a drill bit \n226\n, a casing head \n227\n and a flow pipe \n228\n that carries mud and other material to, for example, the mud tank \n201\n.', 'In the example system of \nFIG.', '2\n, a borehole \n232\n is formed in subsurface formations \n230\n by rotary drilling; noting that various example embodiments may also use directional drilling.', 'As shown in the example of \nFIG.', '2\n, the drillstring \n225\n is suspended within the borehole \n232\n and has a drillstring assembly \n250\n that includes the drill bit \n226\n at its lower end.', 'As an example, the drillstring assembly \n250\n may be a bottom hole assembly (BHA).', 'The wellsite system \n200\n can provide for operation of the drillstring \n225\n and other operations.', 'As shown, the wellsite system \n200\n includes the platform \n215\n and the derrick \n214\n positioned over the borehole \n232\n.', 'As mentioned, the wellsite system \n200\n can include the rotary table \n220\n where the drillstring \n225\n pass through an opening in the rotary table \n220\n.', 'As shown in the example of \nFIG.', '2\n, the wellsite system \n200\n can include the kelly \n218\n and associated components, etc., or a top drive \n240\n and associated components.', 'As to a kelly example, the kelly \n218\n may be a square or hexagonal metal/alloy bar with a hole drilled therein that serves as a mud flow path.', 'The kelly \n218\n can be used to transmit rotary motion from the rotary table \n220\n via the kelly drive bushing \n219\n to the drillstring \n225\n, while allowing the drillstring \n225\n to be lowered or raised during rotation.', 'The kelly \n218\n can pass through the kelly drive bushing \n219\n, which can be driven by the rotary table \n220\n.', 'As an example, the rotary table \n220\n can include a master bushing that operatively couples to the kelly drive bushing \n219\n such that rotation of the rotary table \n220\n can turn the kelly drive bushing \n219\n and hence the kelly \n218\n.', 'The kelly drive bushing \n219\n can include an inside profile matching an outside profile (e.g., square, hexagonal, etc.) of the kelly \n218\n; however, with slightly larger dimensions so that the kelly \n218\n can freely move up and down inside the kelly drive bushing \n219\n.', 'As to a top drive example, the top drive \n240\n can provide functions performed by a kelly and a rotary table.', 'The top drive \n240\n can turn the drillstring \n225\n.', 'As an example, the top drive \n240\n can include one or more motors (e.g., electric and/or hydraulic) connected with appropriate gearing to a short section of pipe called a quill, that in turn may be screwed into a saver sub or the drillstring \n225\n itself.', 'The top drive \n240\n can be suspended from the traveling block \n211\n, so the rotary mechanism is free to travel up and down the derrick \n214\n.', 'As an example, a top drive \n240\n may allow for drilling to be performed with more joint stands than a kelly/rotary table approach.', 'In the example of \nFIG.', '2\n, the mud tank \n201\n can hold mud, which can be one or more types of drilling fluids.', 'As an example, a wellbore may be drilled to produce fluid, inject fluid or both (e.g., hydrocarbons, minerals, water, etc.).', 'In the example of \nFIG.', '2\n, the drillstring \n225\n (e.g., including one or more downhole tools) may be composed of a series of pipes threadably connected together to form a long tube with the drill bit \n226\n at the lower end thereof.', 'As the drillstring \n225\n is advanced into a wellbore for drilling, at some point in time prior to or coincident with drilling, the mud may be pumped by the pump \n204\n from the mud tank \n201\n (e.g., or other source) via a the lines \n206\n, \n208\n and \n209\n to a port of the kelly \n218\n or, for example, to a port of the top drive \n240\n.', 'The mud can then flow via a passage (e.g., or passages) in the drillstring \n225\n and out of ports located on the drill bit \n226\n (see, e.g., a directional arrow).', 'As the mud exits the drillstring \n225\n via ports in the drill bit \n226\n, it can then circulate upwardly through an annular region between an outer surface(s) of the drillstring \n225\n and surrounding wall(s) (e.g., open borehole, casing, etc.), as indicated by directional arrows.', 'In such a manner, the mud lubricates the drill bit \n226\n and carries heat energy (e.g., frictional or other energy) and formation cuttings to the surface where the mud (e.g., and cuttings) may be returned to the mud tank \n201\n, for example, for recirculation (e.g., with processing to remove cuttings, etc.).', 'The mud pumped by the pump \n204\n into the drillstring \n225\n may, after exiting the drillstring \n225\n, form a mudcake that lines the wellbore which, among other functions, may reduce friction between the drillstring \n225\n and surrounding wall(s) (e.g., borehole, casing, etc.).', 'A reduction in friction may facilitate advancing or retracting the drillstring \n225\n.', 'During a drilling operation, the entire drill string \n225\n may be pulled from a wellbore and optionally replaced, for example, with a new or sharpened drill bit, a smaller diameter drill string, etc.', 'As mentioned, the act of pulling a drill string out of a hole or replacing it in a hole is referred to as tripping.', 'A trip may be referred to as an upward trip or an outward trip or as a downward trip or an inward trip depending on trip direction.', 'As an example, consider a downward trip where upon arrival of the drill bit \n226\n of the drill string \n225\n at a bottom of a wellbore, pumping of the mud commences to lubricate the drill bit \n226\n for purposes of drilling to enlarge the wellbore.', 'As mentioned, the mud can be pumped by the pump \n204\n into a passage of the drillstring \n225\n and, upon filling of the passage, the mud may be used as a transmission medium to transmit energy, for example, energy that may encode information as in mud-pulse telemetry.', 'As an example, mud-pulse telemetry equipment may include a downhole device configured to effect changes in pressure in the mud to create an acoustic wave or waves upon which information may modulated.', 'In such an example, information from downhole equipment (e.g., one or more modules of the drillstring \n225\n) may be transmitted uphole to an uphole device, which may relay such information to other equipment for processing, control, etc.', 'As an example, telemetry equipment may operate via transmission of energy via the drillstring \n225\n itself.', 'For example, consider a signal generator that imparts coded energy signals to the drillstring \n225\n and repeaters that may receive such energy and repeat it to further transmit the coded energy signals (e.g., information, etc.).', 'As an example, the drillstring \n225\n may be fitted with telemetry equipment \n252\n that includes a rotatable drive shaft, a turbine impeller mechanically coupled to the drive shaft such that the mud can cause the turbine impeller to rotate, a modulator rotor mechanically coupled to the drive shaft such that rotation of the turbine impeller causes said modulator rotor to rotate, a modulator stator mounted adjacent to or proximate to the modulator rotor such that rotation of the modulator rotor relative to the modulator stator creates pressure pulses in the mud, and a controllable brake for selectively braking rotation of the modulator rotor to modulate pressure pulses.', 'In such example, an alternator may be coupled to the aforementioned drive shaft where the alternator includes at least one stator winding electrically coupled to a control circuit to selectively short the at least one stator winding to electromagnetically brake the alternator and thereby selectively brake rotation of the modulator rotor to modulate the pressure pulses in the mud.', 'In the example of \nFIG.', '2\n, an uphole control and/or data acquisition system \n262\n may include circuitry to sense pressure pulses generated by telemetry equipment \n252\n and, for example, communicate sensed pressure pulses or information derived therefrom for process, control, etc.', 'The assembly \n250\n of the illustrated example includes a logging-while-drilling (LWD) module \n254\n, a measurement-while-drilling (MWD) module \n256\n, an optional module \n258\n, a rotary-steerable system (RSS) and/or motor \n260\n, and the drill bit \n226\n.', 'Such components or modules may be referred to as tools where a drillstring can include a plurality of tools.', 'As to a RSS, it involves technology utilized for direction drilling.', 'Directional drilling involves drilling into the Earth to form a deviated bore such that the trajectory of the bore is not vertical; rather, the trajectory deviates from vertical along one or more portions of the bore.', 'As an example, consider a target that is located at a lateral distance from a surface location where a rig may be stationed.', 'In such an example, drilling can commence with a vertical portion and then deviate from vertical such that the bore is aimed at the target and, eventually, reaches the target.', 'Directional drilling may be implemented where a target may be inaccessible from a vertical location at the surface of the Earth, where material exists in the Earth that may impede drilling or otherwise be detrimental (e.g., consider a salt dome, etc.), where a formation is laterally extensive (e.g., consider a relatively thin yet laterally extensive reservoir), where multiple bores are to be drilled from a single surface bore, where a relief well is desired, etc.', 'One approach to directional drilling involves a mud motor; however, a mud motor can present some challenges depending on factors such as rate of penetration (ROP), transferring weight to a bit (e.g., weight on bit, WOB) due to friction, etc.', 'A mud motor can be a positive displacement motor (PDM) that operates to drive a bit during directional drilling.', 'A PDM operates as drilling fluid is pumped through it where the PDM converts hydraulic power of the drilling fluid into mechanical power to cause the bit to rotate.', 'A PDM can operate in a so-called sliding mode, when the drillstring is not rotated from the surface.', 'A RSS can drill directionally where there is continuous rotation from surface equipment, which can alleviate the sliding of a steerable motor (e.g., a PDM).', 'A RSS may be deployed when drilling directionally (e.g., deviated, horizontal, or extended-reach wells).', 'A RSS can aim to minimize interaction with a borehole wall, which can help to preserve borehole quality.', 'A RSS can aim to exert a relatively consistent side force akin to stabilizers that rotate with the drillstring or orient the bit in the desired direction while continuously rotating at the same number of rotations per minute as the drillstring.', 'The LWD module \n254\n may be housed in a suitable type of drill collar and can contain one or a plurality of selected types of logging tools.', 'It will also be understood that more than one LWD and/or MWD module can be employed, for example, as represented at by the module \n256\n of the drillstring assembly \n250\n.', 'Where the position of an LWD module is mentioned, as an example, it may refer to a module at the position of the LWD module \n254\n, the module \n256\n, etc.', 'An LWD module can include capabilities for measuring, processing, and storing information, as well as for communicating with the surface equipment.', 'In the illustrated example, the LWD module \n254\n may include a seismic measuring device.', 'The MWD module \n256\n may be housed in a suitable type of drill collar and can contain one or more devices for measuring characteristics of the drillstring \n225\n and the drill bit \n226\n.', 'As an example, the MWD tool \n254\n may include equipment for generating electrical power, for example, to power various components of the drillstring \n225\n.', 'As an example, the MWD tool \n254\n may include the telemetry equipment \n252\n, for example, where the turbine impeller can generate power by flow of the mud; it being understood that other power and/or battery systems may be employed for purposes of powering various components.', 'As an example, the MWD module \n256\n may include one or more of the following types of measuring devices: a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device.\n \nFIG.', '2\n also shows some examples of types of holes that may be drilled.', 'For example, consider a slant hole \n272\n, an S-shaped hole \n274\n, a deep inclined hole \n276\n and a horizontal hole \n278\n.', 'As an example, a drilling operation can include directional drilling where, for example, at least a portion of a well includes a curved axis.', 'For example, consider a radius that defines curvature where an inclination with regard to the vertical may vary until reaching an angle between about 30 degrees and about 60 degrees or, for example, an angle to about 90 degrees or possibly greater than about 90 degrees.', 'As an example, a directional well can include several shapes where each of the shapes may aim to meet particular operational demands.', 'As an example, a drilling process may be performed on the basis of information as and when it is relayed to a drilling engineer.', 'As an example, inclination and/or direction may be modified based on information received during a drilling process.', 'As an example, deviation of a bore may be accomplished in part by use of a downhole motor and/or a turbine.', 'As to a motor, for example, a drillstring can include a positive displacement motor (PDM).', 'As an example, a system may be a steerable system and include equipment to perform method such as geosteering.', 'As mentioned, a steerable system can be or include an RSS.', 'As an example, a steerable system can include a PDM or of a turbine on a lower part of a drillstring which, just above a drill bit, a bent sub can be mounted.', 'As an example, above a PDM, MWD equipment that provides real time or near real time data of interest (e.g., inclination, direction, pressure, temperature, real weight on the drill bit, torque stress, etc.) and/or LWD equipment may be installed.', 'As to the latter, LWD equipment can make it possible to send to the surface various types of data of interest, including for example, geological data (e.g., gamma ray log, resistivity, density and sonic logs, etc.).', 'The coupling of sensors providing information on the course of a well trajectory, in real time or near real time, with, for example, one or more logs characterizing the formations from a geological viewpoint, can allow for implementing a geosteering method.', 'Such a method can include navigating a subsurface environment, for example, to follow a desired route to reach a desired target or targets.', 'As an example, a drillstring can include an azimuthal density neutron (ADN) tool for measuring density and porosity; a MWD tool for measuring inclination, azimuth and shocks; a compensated dual resistivity (CDR) tool for measuring resistivity and gamma ray related phenomena; one or more variable gauge stabilizers; one or more bend joints; and a geosteering tool, which may include a motor and optionally equipment for measuring and/or responding to one or more of inclination, resistivity and gamma ray related phenomena.', 'As an example, geosteering can include intentional directional control of a wellbore based on results of downhole geological logging measurements in a manner that aims to keep a directional wellbore within a desired region, zone (e.g., a pay zone), etc.', 'As an example, geosteering may include directing a wellbore to keep the wellbore in a particular section of a reservoir, for example, to minimize gas and/or water breakthrough and, for example, to maximize economic production from a well that includes the wellbore.\n \nReferring again to \nFIG.', '2\n, the wellsite system \n200\n can include one or more sensors \n264\n that are operatively coupled to the control and/or data acquisition system \n262\n.', 'As an example, a sensor or sensors may be at surface locations.', 'As an example, a sensor or sensors may be at downhole locations.', 'As an example, a sensor or sensors may be at one or more remote locations that are not within a distance of the order of about one hundred meters from the wellsite system \n200\n.', 'As an example, a sensor or sensor may be at an offset wellsite where the wellsite system \n200\n and the offset wellsite are in a common field (e.g., oil and/or gas field).', 'As an example, one or more of the sensors \n264\n can be provided for tracking pipe, tracking movement of at least a portion of a drillstring, etc.\n \nAs an example, the system \n200\n can include one or more sensors \n266\n that can sense and/or transmit signals to a fluid conduit such as a drilling fluid conduit (e.g., a drilling mud conduit).', 'For example, in the system \n200\n, the one or more sensors \n266\n can be operatively coupled to portions of the standpipe \n208\n through which mud flows.', 'As an example, a downhole tool can generate pulses that can travel through the mud and be sensed by one or more of the one or more sensors \n266\n.', 'In such an example, the downhole tool can include associated circuitry such as, for example, encoding circuitry that can encode signals, for example, to reduce demands as to transmission.', 'As an example, circuitry at the surface may include decoding circuitry to decode encoded information transmitted at least in part via mud-pulse telemetry.', 'As an example, circuitry at the surface may include encoder circuitry and/or decoder circuitry and circuitry downhole may include encoder circuitry and/or decoder circuitry.', 'As an example, the system \n200\n can include a transmitter that can generate signals that can be transmitted downhole via mud (e.g., drilling fluid) as a transmission medium.', 'As mentioned, a drillstring can include various tools that may make measurements.', 'As an example, a wireline tool or another type of tool may be utilized to make measurements.', 'As an example, a tool may be configured to acquire electrical borehole images.', 'As an example, the fullbore Formation MicroImager (FMI) tool (Schlumberger Limited, Houston, Texas) can acquire borehole image data.', 'A data acquisition sequence for such a tool can include running the tool into a borehole with acquisition pads closed, opening and pressing the pads against a wall of the borehole, delivering electrical current into the material defining the borehole while translating the tool in the borehole, and sensing current remotely, which is altered by interactions with the material.', 'Analysis of formation information may reveal features such as, for example, vugs, dissolution planes (e.g., dissolution along bedding planes), stress-related features, dip events, etc.', 'As an example, a tool may acquire information that may help to characterize a reservoir, optionally a fractured reservoir where fractures may be natural and/or artificial (e.g., hydraulic fractures).', 'As an example, information acquired by a tool or tools may be analyzed using a framework such as the TECHLOG framework.', 'As an example, the TECHLOG framework can be interoperable with one or more other frameworks such as, for example, the PETREL framework.\n \nFIG.', '3\n shows an example of a system \n300\n that includes a drilling workflow framework \n301\n, a seismic-to-simulation framework \n302\n, a drilling framework \n304\n, a client layer \n310\n, an applications layer \n340\n and a storage layer \n360\n.', 'As shown the client layer \n310\n can be in communication with the applications layer \n340\n and the applications layer \n340\n can be in communication with the storage layer \n360\n.', 'The client layer \n310\n can include features that allow for access and interactions via one or more private networks \n312\n, one or more mobile platforms and/or mobile networks \n314\n and via the “cloud” \n316\n, which may be considered to include distributed equipment that forms a network such as a network of networks.', 'In the example of \nFIG.', '3', ', the applications layer \n340\n includes the drilling workflow framework \n301\n.', 'The applications layer \n340\n also includes a database management component \n342\n that includes one or more search engines modules.', 'As an example, the database management component \n342\n can include one or more search engine modules that provide for searching one or more information that may be stored in one or more data repositories.', 'As an example, the STUDIO E&P knowledge environment (Schlumberger Ltd., Houston, Texas) includes STUDIO FIND search functionality, which provides a search engine.', 'The STUDIO FIND search functionality also provides for indexing content, for example, to create one or more indexes.', 'As an example, search functionality may provide for access to public content, private content or both, which may exist in one or more databases, for example, optionally distributed and accessible via an intranet, the Internet or one or more other networks.', 'As an example, a search engine may be configured to apply one or more filters from a set or sets of filters, for example, to enable users to filter out data that may not be of interest.', 'As an example, a framework may provide for interaction with a search engine and, for example, associated features such as features of the STUDIO FIND search functionality.', 'As an example, a framework may provide for implementation of one or more spatial filters (e.g., based on an area viewed on a display, static data, etc.).', 'As an example, a search may provide access to dynamic data (e.g., “live” data from one or more sources), which may be available via one or more networks (e.g., wired, wireless, etc.).', 'As an example, one or more modules may optionally be implemented within a framework or, for example, in a manner operatively coupled to a framework (e.g., as an add-on, a plug-in, etc.).', 'As an example, a module for structuring search results (e.g., in a list, a hierarchical tree structure, etc.) may optionally be implemented within a framework or, for example, in a manner operatively coupled to a framework (e.g., as an add-on, a plug-in, etc.).', 'In the example of \nFIG.', '3\n, the applications layer \n340\n can include communicating with one or more resources such as, for example, the seism ic-to-simulation framework \n302\n, the drilling framework \n304\n and/or one or more sites, which may be or include one or more offset wellsites.', 'As an example, the applications layer \n340\n may be implemented for a particular wellsite where information can be processed as part of a workflow for operations such as, for example, operations performed, being performed and/or to be performed at the particular wellsite.', 'As an example, an operation may involve directional drilling, for example, via geosteering.', 'In the example of \nFIG.', '3\n, the storage layer \n360\n can include various types of data, information, etc., which may be stored in one or more databases \n362\n.', 'As an example, one or more servers \n364\n may provide for management, access, etc., to data, information, etc., stored in the one or more databases \n362\n.', 'As an example, the database management component \n342\n may provide for searching as to data, information, etc., stored in the one or more databases \n362\n.', 'As an example, the database management component \n342\n may include features for indexing, etc.', 'As an example, information may be indexed at least in part with respect to wellsite.', 'For example, where the applications layer \n340\n is implemented to perform one or more workflows associated with a particular wellsite, data, information, etc., associated with that particular wellsite may be indexed based at least in part on the wellsite being an index parameter (e.g., a search parameter).', 'As an example, the system \n300\n of \nFIG.', '3\n may be implemented to perform one or more portions of one or more workflows associated with the system \n200\n of \nFIG.', '2\n.', 'As an example, the drilling workflow framework \n301\n may interact with a technical data framework and the drilling framework \n304\n before, during and/or after performance of one or more drilling operations.', 'In such an example, the one or more drilling operations may be performed in a geologic environment (see, e.g., the environment \n150\n of \nFIG.', '1\n) using one or more types of equipment (see, e.g., equipment of \nFIGS.', '1\n and \n2\n).', 'As an example, an architecture utilized in a system such as, for example, the system \n300\n may include features of the AZURE architecture (Microsoft Corporation, Redmond, WA).', 'As an example, a cloud portal block can include one or more features of an AZURE portal that can manage, mediate, etc. access to one or more services, data, connections, networks, devices, etc.', 'As an example, the system \n300\n may include features of the GOOGLE cloud architecture (Google, Mountain View, CA).', 'As an example, the system \n300\n can include a cloud computing platform and infrastructure, for example, for building, deploying, and managing applications and services (e.g., through a network of datacenters, etc.).', 'As an example, such a cloud platform may provide PaaS and IaaS services and support one or more different programming languages, tools and frameworks, etc.\n \nFIG.', '4\n shows an example of a wellsite system \n400\n, specifically, \nFIG.', '4\n shows the wellsite system \n400\n in an approximate side view and an approximate plan view along with a block diagram of a system \n470\n.', 'In the example of \nFIG.', '4\n, the wellsite system \n400\n can include a cabin \n410\n, a rotary table \n422\n, drawworks \n424\n, a mast \n426\n (e.g., optionally carrying a top drive, etc.), mud tanks \n430\n (e.g., with one or more pumps, one or more shakers, etc.), one or more pump buildings \n440\n, a boiler building \n442\n, an HPU building \n444\n (e.g., with a rig fuel tank, etc.), a combination building \n448\n (e.g., with one or more generators, etc.), pipe tubs \n462\n, a catwalk \n464\n, a flare \n468\n, etc.', 'Such equipment can include one or more associated functions and/or one or more associated operational risks, which may be risks as to time, resources, and/or humans.', 'As shown in the example of \nFIG.', '4\n, the wellsite system \n400\n can include a system \n470\n that includes one or more processors \n472\n, memory \n474\n operatively coupled to at least one of the one or more processors \n472\n, instructions \n476\n that can be, for example, stored in the memory \n474\n, and one or more interfaces \n478\n.', 'As an example, the system \n470\n can include one or more processor-readable media that include processor-executable instructions executable by at least one of the one or more processors \n472\n to cause the system \n470\n to control one or more aspects of the wellsite system \n400\n.', 'In such an example, the memory \n474\n can be or include the one or more processor-readable media where the processor-executable instructions can be or include instructions.', 'As an example, a processor-readable medium can be a computer-readable storage medium that is not a signal and that is not a carrier wave.\n \nFIG.', '', '4\n also shows a battery \n480\n that may be operatively coupled to the system \n470\n, for example, to power the system \n470\n.', 'As an example, the battery \n480\n may be a back-up battery that operates when another power supply is unavailable for powering the system \n470\n.', 'As an example, the battery \n480\n may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery \n480\n can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.', 'In the example of \nFIG.', '4\n, services \n490\n are shown as being available, for example, via a cloud platform.', 'Such services can include data services \n492\n, query services \n494\n and drilling services \n496\n.', 'As an example, the services \n490\n may be part of a system such as the system \n300\n of \nFIG.', '3\n.', 'As an example, a system such as, for example, the system \n300\n of \nFIG.', '3\n may be utilized to perform a workflow.', 'Such a system may be distributed and allow for collaborative workflow interactions and may be considered to be a platform (e.g., a framework for collaborative interactions, etc.).', 'As an example, a workflow can commence with an evaluation stage, which may include a geological service provider evaluating a formation.', 'As an example, a geological service provider may undertake the formation evaluation using a computing system executing a software package tailored to such activity; or, for example, one or more other suitable geology platforms may be employed (e.g., alternatively or additionally).', 'As an example, the geological service provider may evaluate the formation, for example, using earth models, geophysical models, basin models, petrotechnical models, combinations thereof, and/or the like.', 'Such models may take into consideration a variety of different inputs, including offset well data, seismic data, pilot well data, other geologic data, etc.', 'The models and/or the input may be stored in the database maintained by the server and accessed by the geological service provider.', 'As an example, a workflow may progress to a geology and geophysics (“G&G”) service provider, which may generate a well trajectory, which may involve execution of one or more G&G software packages.', 'Examples of such software packages include the PETREL framework.', 'As an example, a G&G service provider may determine a well trajectory or a section thereof, based on, for example, one or more model(s) provided by a formation evaluation, and/or other data, e.g., as accessed from one or more databases (e.g., maintained by one or more servers, etc.).', 'As an example, a well trajectory may take into consideration various “basis of design” (BOD) constraints, such as general surface location, target (e.g., reservoir) location, and the like.', 'As an example, a trajectory may incorporate information about tools, bottom-hole assemblies, casing sizes, etc., that may be used in drilling the well.', 'A well trajectory determination may take into consideration a variety of other parameters, including risk tolerances, fluid weights and/or plans, bottom-hole pressures, drilling time, etc.', 'As an example, a workflow may progress to a first engineering service provider (e.g., one or more processing machines associated therewith), which may validate a well trajectory and, for example, relief well design.', 'Such a validation process may include evaluating physical properties, calculations, risk tolerances, integration with other aspects of a workflow, etc.', 'As an example, one or more parameters for such determinations may be maintained by a server and/or by the first engineering service provider; noting that one or more model(s), well trajectory(ies), etc. may be maintained by a server and accessed by the first engineering service provider.', 'For example, the first engineering service provider may include one or more computing systems executing one or more software packages.', 'As an example, where the first engineering service provider rejects or otherwise suggests an adjustment to a well trajectory, the well trajectory may be adjusted or a message or other notification sent to the G&G service provider requesting such modification.', 'As an example, one or more engineering service providers (e.g., first, second, etc.) may provide a casing design, bottom-hole assembly (BHA) design, fluid design, and/or the like, to implement a well trajectory.', 'In some embodiments, a second engineering service provider may perform such design using one of more software applications.', 'Such designs may be stored in one or more databases maintained by one or more servers, which may, for example, employ STUDIO framework tools, and may be accessed by one or more of the other service providers in a workflow.', 'As an example, a second engineering service provider may seek approval from a third engineering service provider for one or more designs established along with a well trajectory.', "In such an example, the third engineering service provider may consider various factors as to whether the well engineering plan is acceptable, such as economic variables (e.g., oil production forecasts, costs per barrel, risk, drill time, etc.), and may request authorization for expenditure, such as from the operating company's representative, well-owner's representative, or the like.", 'As an example, at least some of the data upon which such determinations are based may be stored in one or more database maintained by one or more servers.', 'As an example, a first, a second, and/or a third engineering service provider may be provided by a single team of engineers or even a single engineer, and thus may or may not be separate entities.', 'As an example, where economics may be unacceptable or subject to authorization being withheld, an engineering service provider may suggest changes to casing, a bottom-hole assembly, and/or fluid design, or otherwise notify and/or return control to a different engineering service provider, so that adjustments may be made to casing, a bottom-hole assembly, and/or fluid design.', 'Where modifying one or more of such designs is impracticable within well constraints, trajectory, etc., the engineering service provider may suggest an adjustment to the well trajectory and/or a workflow may return to or otherwise notify an initial engineering service provider and/or a G&G service provider such that either or both may modify the well trajectory.', 'As an example, a workflow can include considering a well trajectory, including an accepted well engineering plan, and a formation evaluation.', 'Such a workflow may then pass control to a drilling service provider, which may implement the well engineering plan, establishing safe and efficient drilling, maintaining well integrity, and reporting progress as well as operating parameters.', 'As an example, operating parameters, formation encountered, data collected while drilling (e.g., using logging-while-drilling or measurement-while-drilling technology), may be returned to a geological service provider for evaluation.', 'As an example, the geological service provider may then re-evaluate the well trajectory, or one or more other aspects of the well engineering plan, and may, in some cases, and potentially within predetermined constraints, adjust the well engineering plan according to the real-life drilling parameters (e.g., based on acquired data in the field, etc.).', 'Whether the well is entirely drilled, or a section thereof is completed, depending on the specific embodiment, a workflow may proceed to a post review.', 'As an example, a post review may include reviewing drilling performance.', 'As an example, a post review may further include reporting the drilling performance (e.g., to one or more relevant engineering, geological, or G&G service providers).', 'Various activities of a workflow may be performed consecutively and/or may be performed out of order (e.g., based partially on information from templates, nearby wells, etc. to fill in gaps in information that is to be provided by another service provider).', 'As an example, undertaking one activity may affect the results or basis for another activity, and thus may, either manually or automatically, call for a variation in one or more workflow activities, work products, etc.', 'As an example, a server may allow for storing information on a central database accessible to various service providers where variations may be sought by communication with an appropriate service provider, may be made automatically, or may otherwise appear as suggestions to the relevant service provider.', 'Such an approach may be considered to be a holistic approach to a well workflow, in comparison to a sequential, piecemeal approach.', 'As an example, various actions of a workflow may be repeated multiple times during drilling of a wellbore.', 'For example, in one or more automated systems, feedback from a drilling service provider may be provided at or near real-time, and the data acquired during drilling may be fed to one or more other service providers, which may adjust its piece of the workflow accordingly.', 'As there may be dependencies in other areas of the workflow, such adjustments may permeate through the workflow, e.g., in an automated fashion.', 'In some embodiments, a cyclic process may additionally or instead proceed after a certain drilling goal is reached, such as the completion of a section of the wellbore, and/or after the drilling of the entire wellbore, or on a per-day, week, month, etc. basis.', 'Well planning can include determining a path of a well that can extend to a reservoir, for example, to economically produce fluids such as hydrocarbons therefrom.', 'Well planning can include selecting a drilling and/or completion assembly which may be used to implement a well plan.', 'As an example, various constraints can be imposed as part of well planning that can impact design of a well.', 'As an example, such constraints may be imposed based at least in part on information as to known geology of a subterranean domain, presence of one or more other wells (e.g., actual and/or planned, etc.) in an area (e.g., consider collision avoidance), etc.', 'As an example, one or more constraints may be imposed based at least in part on characteristics of one or more tools, components, etc.', 'As an example, one or more constraints may be based at least in part on factors associated with drilling time and/or risk tolerance.\n \nFIG.', '5\n shows an example of an environment \n501\n that includes a subterranean portion \n503\n where a rig \n510\n is positioned at a surface location above a bore \n520\n.', 'In the example of \nFIG.', '5\n, various wirelines services equipment can be operated to perform one or more wirelines services including, for example, acquisition of data from one or more positions within the bore \n520\n.', 'In the example of \nFIG.', '5\n, the bore \n520\n includes drillpipe \n522\n, a casing shoe, a cable side entry sub (CSES) \n523\n, a wet-connector adaptor \n526\n and an openhole section \n528\n.', 'As an example, the bore \n520\n can be a vertical bore or a deviated bore where one or more portions of the bore may be vertical and one or more portions of the bore may be deviated, including substantially horizontal.', 'In the example of \nFIG.', '5\n, the CSES \n523\n includes a cable clamp \n525\n, a packoff seal assembly \n527\n and a check valve \n529\n.', 'These components can provide for insertion of a logging cable \n530\n that includes a portion \n532\n that runs outside the drillpipe \n522\n to be inserted into the drillpipe \n522\n such that at least a portion \n534\n of the logging cable runs inside the drillpipe \n522\n.', 'In the example of \nFIG.', '5\n, the logging cable \n530\n runs past the wet-connect adaptor \n526\n and into the openhole section \n528\n to a logging string \n540\n.', 'As shown in the example of \nFIG.', '5\n, a logging truck \n550\n (e.g., a wirelines services vehicle) can deploy the wireline \n530\n under control of a system \n560\n.', 'As shown in the example of \nFIG.', '5\n, the system \n560\n can include one or more processors \n562\n, memory \n564\n operatively coupled to at least one of the one or more processors \n562\n, instructions \n566\n that can be, for example, stored in the memory \n564\n, and one or more interfaces \n568\n.', 'As an example, the system \n560\n can include one or more processor-readable media that include processor-executable instructions executable by at least one of the one or more processors \n562\n to cause the system \n560\n to control one or more aspects of equipment of the logging string \n540\n and/or the logging truck \n550\n.', 'In such an example, the memory \n564\n can be or include the one or more processor-readable media where the processor-executable instructions can be or include instructions.', 'As an example, a processor-readable medium can be a computer-readable storage medium that is not a signal and that is not a carrier wave.\n \nFIG.', '', '5\n also shows a battery \n570\n that may be operatively coupled to the system \n560\n, for example, to power the system \n560\n.', 'As an example, the battery \n570\n may be a back-up battery that operates when another power supply is unavailable for powering the system \n560\n (e.g., via a generator of the wirelines truck \n550\n, a separate generator, a power line, etc.).', 'As an example, the battery \n570\n may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery \n570\n can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.', 'As an example, the system \n560\n can be operatively coupled to a client layer \n580\n.', 'In the example of \nFIG.', '5', ', the client layer \n580\n can include features that allow for access and interactions via one or more private networks \n582\n, one or more mobile platforms and/or mobile networks \n584\n and via the “cloud” \n586\n, which may be considered to include distributed equipment that forms a network such as a network of networks.', 'As an example, the system \n560\n can include circuitry to establish a plurality of connections (e.g., sessions).', 'As an example, connections may be via one or more types of networks.', 'As an example, connections may be client-server types of connections where the system \n560\n operates as a server in a client-server architecture.', 'For example, clients may log-in to the system \n560\n where multiple clients may be handled, optionally simultaneously.', 'FIG.', '6\n shows an example of a graphical user interface (GUI) \n600\n that includes information associated with a well plan.', 'Specifically, the GUI \n600\n includes a panel \n610\n where surfaces representations \n612\n and \n614\n are rendered along with well trajectories where a location \n616\n can represent a position of a drillstring \n617\n along a well trajectory.', 'The GUI \n600\n may include one or more editing features such as an edit well plan set of features \n630\n.', 'The GUI \n600\n may include information as to individuals of a team \n640\n that are involved, have been involved and/or are to be involved with one or more operations.', 'The GUI \n600\n may include information as to one or more activities \n650\n.', 'As shown in the example of \nFIG.', '6', ', the GUI \n600\n can include a graphical control of a drillstring \n660\n where, for example, various portions of the drillstring \n660\n may be selected to expose one or more associated parameters (e.g., type of equipment, equipment specifications, operational history, etc.).', 'FIG.', '6\n also shows a table \n670\n as a point spreadsheet that specifies information for a plurality of wells.', 'For example, the point spreadsheet can include coordinates, dimensions, etc., that specify a trajectory of a well, spacing of wells, etc.\n \nFIG.', '7\n shows an example of a GUI \n700\n that includes various features that can be part of a workspace.', 'For example, a computational framework area \n710\n includes icons that represent various types of computational frameworks such as a drilling plan framework, a seismic-to-simulation framework (e.g., PETREL framework, Schlumberger Limited, Houston, Texas), a measurements framework (e.g., TECHLOG framework, Schlumberger Limited, Houston, Texas), a mechanical earth modeling (MEM) framework (PETROMOD framework, Schlumberger Limited, Houston, Texas), an exploration risk, resource, and value assessment framework (e.g., GEOX, Schlumberger Limited, Houston, Texas), and a reservoir simulation framework (INTERSECT, Schlumberger Limited, Houston, Texas).', 'As an example, one or more computational frameworks may be suitable for use in a system such as the system \n300\n of \nFIG.', '3\n, the wellsite system \n400\n of \nFIG.', '4\n, the system \n500\n of \nFIG.', '5\n, etc.', 'In the example of \nFIG.', '7\n, the GUI \n700\n can include a projects area \n720\n for various types of projects, a data intake area \n730\n for ingestion of data, a data storage area \n740\n for rendering graphics associated with data storage, a graph area \n750\n for rendering a graph, a query area \n760\n for entering and/or rendering a query, a query result(s) area \n770\n for rendering a query result or results.', 'As an example, a user of the GUI \n700\n may enter a query in the query area \n760\n that utilizes a graph rendered in the graph area \n750\n to generate one or more query results that can be rendered in the query result(s) area \n770\n.', 'In the example of \nFIG.', '7\n, a data file (e.g., as an icon, as a URL, etc.) can be loaded via the data intake area \n730\n such that data of the data file is ingested for utilization in one or more projects, which may utilize one or more of the computational frameworks.', 'In the example of \nFIG.', '7', ', the types of data or data files that can be ingested can be varied.', 'As an example, the data intake area \n730\n and underlying control(s) can be a portal, which may be a secure portal, through which data are to “pass” before they can be utilized via one or more of the computational frameworks and/or projects.', 'In the example of \nFIG.', '7\n, the data intake area \n730\n can be operatively coupled to one or more remote resources.', 'For example, the GUI \n700\n may expose a remote drive or drives such as a cloud-based drive.', 'As an example, a remote resource may be managed using a cloud platform.', 'For example, consider a GOOGLE cloud platform, an AMAZON WEB SERVICES (AWS) cloud platform, a MICROSOFT AZURE cloud platform, etc.', 'As an example, a cloud platform may provide for object storage, block storage, file storage (e.g., a shared filesystem), managed SQL databases, NoSQL databases, etc.', 'As to types of data, consider one or more of text, images, pictures, videos, audio, objects, blobs, structured data, unstructured data, low latency data, high-throughput data, time series data, semi-structured application data, hierarchical data, durable key-value data, etc.', 'For example, particular data may be utilized in visual renderings and demand low latency such that glitches do not occur during buffering, rendering, interactive manipulations, etc.', 'As an example, particular data may be generated as a binary large object (blob) for purposes of transmission, security, storage organization, etc.', 'As an example, a sensor may generate time series data, which may be regular and/or irregular in time and which may or may not include a “global” time marker (e.g., time stamps, etc.).', 'As an example, data may be in a wellsite information transfer standard markup language (WITSML) standard, which is a standard utilized in various operations including rig operations.', 'As an example, data may be serially transferred ASCII data.', 'In the example of \nFIG.', '7\n, one or more of the computational frameworks may be local and/or one or more of the computational frameworks may be remote.', 'For example, the GUI \n700\n may be rendered locally using a display operatively coupled to a workstation (e.g., laptop, desktop, etc.) where the workstation includes executable instructions for instantiating a computational framework and/or the GUI \n700\n may be rendered locally using a display operatively coupled to or part of a computing device that includes one or more network interfaces that can operatively couple to one or more remote resources that can instantiate a computational framework.', 'For example, consider a remote resource being a cloud-based resource.', 'As an example, controls of the data intake area \n730\n may operate in cloud-based resources that are in a cloud platform that is common with data to be ingested and/or one or more computational frameworks to be utilized, which may consume ingested data.', 'As an example, controls of the query related areas \n750\n, \n760\n and \n770\n may operate in cloud-based resources that are in a cloud platform that is common with one or more computational frameworks to be utilized.', 'As explained, some features may be local and some features may be remote and various features may be within a common platform such as a cloud platform.\n \nFIG.', '8\n shows an example of a system \n800\n that includes a workspace framework \n810\n, an interface \n820\n and a graph framework \n840\n.', 'As shown, the graph framework \n840\n can be operatively coupled to the workspace framework \n810\n via the interface.', 'As an example, a user may utilize the GUI \n700\n of \nFIG.', '7\n to cause the system \n800\n of \nFIG.', '8\n to generate and/or utilize a graph.', 'As an example, ingestion pipeline services can be utilized to dynamically orchestrate data curation through a configurable, extensible smart “pipeline” encompassing the breadth of data management stage gates (e.g., ingestion, enrichment, classification, data quality, indexing) and can be extensible beyond the stage gates, for example, to handle unforeseen datatypes and/or workflows.', 'As an example, an extensible pipeline service can be leveraged by documenting and persisting incoming data in a known, consistent, manner according to a schema, representing various aspects of the data.', 'For example, consider aspects such as source of data, data semantics (what the data represent such as an object and/or an entity of an Earth model, of a computational framework, etc.), representative properties (e.g., of an object, entity, etc.), representative attributes (e.g., of an object, entity, etc.), data frame of reference, data relationship(s), etc.', 'As to source of data, consider the PROSOURCE E&P data management system (Schlumberger Limited, Houston, Texas), which provides management, visualization, and delivery capabilities for various types of data to streamline various workflows.', 'Such a system can provide real-time capabilities to proactively manage wellbore operations using vendor-neutral data aggregation features.', 'As an example, an aggregator system can be an operations equipment ready system that can be integrated into a system for a desired location with data connectivity (e.g., rig equipment installation, logging equipment installation, seismic equipment installation, laboratory equipment installation, etc.).', 'As an example, a real-time data system can collect multiple data types, which may include customized data types according to customized data formats and/or one or more of the following data formats: WITS (serial, file, TCP, and http); WITSML (1.1, 1.2, 1.3.1.1 client and server); OPC-DA and OPC-UA (clients); DLIS; MAXWELL; and CSV.', 'As to a semantic understanding of what the data actually represents, consider data that represents a wellbore as an entity, which may be an object in an Earth model of a computational framework.', 'As to a deterministic understanding of the various properties or attributes of the entity, these may vary from source to source.', 'As to a deterministic understanding of the frame of reference of source data, such an understanding can help to facilitate frictionless (e.g., optionally lossless) consumption.', 'For example, various types of data may be compressed or uncompressed; in 6-bit, 12-bit, 24-bit, 32-bit, 48-bit, 64-bit or other bit depth; in a color standard (e.g., RGB, HCL, LUV, etc.)', '; in a time series, etc.', 'As an example, an ingestion service may provide for one or more options and may automatically select an option as to how data are to be ingested, which may depend on one or more types of computational frameworks that can consume the particular data.', 'For example, where a computational framework is limited to a particular bit-depth, the ingestion service may “downsize” the data (e.g., from 48-bit to 12-bit).', 'As an example, where a computational framework is limited to a particular file type (e.g., JPEG, BMP, TIFF, etc.), the ingestion service may include one or more filters, converters, etc., that act to assure the data ingested is provided in a manner suitable for direct use by the computational framework.', 'As to a deterministic understanding of how data relates to other data (e.g., in a common dataset or another dataset), such an approach may aim to heuristically determine (e.g., through relationship mining) one or more connection points of interest.', 'For example, a rig identifier may be utilized to establish a connection point of interest between data.', 'In such an example, it may be determined that the rig identifier corresponds to a wellsite with longitude and latitude and that the rig corresponding to the rig identifier was at that wellsite for a number of weeks.', 'In such an example, particular data associated with the rig identifier can be segmented in time for a time associated with the wellsite.', 'With the wellsite known for the particular data, it may be further associated with other data for that wellsite.', 'As an example, ingestion services can include GIS features, which can include GIS backend and frontend features.', 'For example, an ingestion service can access an ArcGIS server and can include an ArcGIS server compatible client.', 'In such an example, one or more ORACLE components may be included (e.g., a 64-bit ORACLE client such as the ORACLE client for an ArcGIS client.', 'As to a backend, consider the ArcGIS server for the MICROSOFT .NET framework.', 'As an example, resources local and/or remote can include multiple core processing equipment.', 'As an example, services can include an ArcGIS Desktop Basic component.', 'As an example, an ingestion service can access GIS resources during ingestion to provide for rendering of GIS data in text, graphical and/or image form to allow a user to see a geographic location as may be associated with data being ingested.', 'While a GIS type of system is mentioned, a lightweight mapping service may be utilized for an informative but a user experience that is of lesser richness.', 'For example, with a GIS type of system, a user may be able to see a wellsite at one or more times, which can include a past time from a past satellite or other image and a latest time from a latest satellite or other image.', 'As to imagery, it may be available in one or more forms (e.g., visible, IR, UV, microwave, etc.).', 'As an example, a system can include a dataset descriptor generator.', 'For example, consider a PYTHON language based utility for generating metadata for a given input file such that the input file can be processed effectively (e.g., ingested, enriched, indexed, etc.).', 'The PYTHON language is a multi-paradigm programming language that supports object-oriented programming and structured programming.', 'Features in the PYTHON language can support functional programming and aspect-oriented programming.', 'The PYTHON language uses dynamic typing, and a combination of reference counting and a cycle-detecting garbage collector for memory management.', 'It also features dynamic name resolution (late binding), which binds method and variable names during program execution.', 'The PYTHON language includes filter( ), map( ), and reduce( ) functions; list comprehensions, dictionaries, and sets; and generator expressions.', 'The PYTHON language library includes modules such as itertools and functools that can implement various functional tools.', 'As an example, a person may be represented as follows in the JSON format:\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n{\n \n \n \n \n \n \n \n \n \n \n“firstName”: “John”,\n \n \n \n \n“lastName”: “Smith”,\n \n \n \n \n“isAlive”: true,\n \n \n \n \n“age”: 27,\n \n \n \n \n“address”: {\n \n \n \n \n \n \n \n \n \n \n“streetAddress”: “21 2nd Street”\n \n \n \n \n“city”: “New York”,\n \n \n \n \n“state”: “NY”,\n \n \n \n \n“postalCode”: “10021-3100”\n \n \n \n \n \n \n \n \n \n \n},\n \n \n \n \n“phoneNumbers”: [\n \n \n \n \n \n \n \n \n \n \n{\n \n \n \n \n \n \n \n \n \n \n“type”: “home”,\n \n \n \n \n“number”: “212 555-1234”\n \n \n \n \n \n \n \n \n \n \n}\n \n \n \n \n \n \n \n \n \n \n}\n \n \n \n \n \n \n \n \n \n \nAs an example, a dataset descriptor can include generated metadata with details such as, for example, one or more of the following: \n \n \n \nList of column names and their data types;\n \nList of column names of type Latitude and Longitude to enable spatial indexing and discovery workflows;\n \nList of columns that will act as primary “key” columns while processing file to enable matching workflows (enrichment);\n \nList of columns frame of reference information (unit system, dimension, unit of measure, format, etc.);\n \nList of columns that participate in specialized entity representations, consider an example for a trajectory as follows: columns that will act as Depth, Azimuth and Inclination; and\n \nData type mapping block enabling a user to specify how each type of column can be processed by one or more consuming services, such as indexing (for example, “int”→“double”) for standardization.', 'As an example, a graph framework such as the graph framework \n840\n of \nFIG.', '8\n can utilize data as ingested and/or as otherwise accessible to generate a graph that includes vertices and edges where the edges represent relationships between vertices.', 'As explained, data can include and/or be processed to include descriptors.', 'As an example, a graph framework can utilize data and/or data descriptors to deterministically and/or probabilistically determine relationships of a graph.\n \nFIG.', '9\n shows an example of a method \n900\n that includes an access block \n910\n for accessing data generated during field operations; a generation block \n920\n for generating a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and a generation block \n930\n for generating a query result using the graph responsive to receipt of a query.', 'The method \n900\n is shown as including various computer-readable storage medium (CRM) blocks \n911\n, \n921\n, and \n931\n that can include processor-executable instructions that can instruct a computing system, which can be a control system, to perform one or more of the actions described with respect to the method \n900\n.', 'As shown in the example of \nFIG.', '9\n, a system \n990\n can include one or more computers \n992\n that include one or more processors \n993\n, memory \n994\n operatively coupled to at least one of the one or more processors \n993\n, instructions \n996\n that can be, for example, stored in the memory \n994\n, and one or more interfaces \n995\n.', 'As an example, the system \n990\n can include one or more processor-readable media that include processor-executable instructions executable by at least one of the one or more processors \n993\n to cause the system \n990\n to perform actions such as, for example, one or more actions of the method \n900\n.', 'As an example, the instructions \n996\n can include instructions of one or more of the CRM blocks \n911\n, \n921\n, and \n931\n.', 'The memory \n994\n can be or include the one or more processor-readable media where the processor-executable instructions can be or include instructions.', 'As an example, a processor-readable medium can be a computer-readable storage medium that is non-transitory that is not a signal and that is not a carrier wave.', 'As an example, a system can include relationship mining features.', 'For example, a dataset may be accessed that pertains to a particular wellsite, a particular field, a particular rig, a particular computational framework, etc., where such features perform relationship mining on the dataset.', 'As an example, consider a scenario where a BHA component indicated in a dataset can be related to one or more other items in that dataset and/or in one or more other datasets.', 'While a particular piece of equipment is mentioned in the foregoing example, other types of equipment may be of interest (e.g., seismic equipment, logging equipment, other drilling equipment, rig equipment, pipeline equipment, processing equipment, etc.).', 'As an example, a system can include one or more cloud-based resources (e.g., memory, computing cores, etc.), which can be utilized (e.g., provisioned, called-upon, etc.) to perform analyses over a broad array of data aggregated for the system where the system handles operations for a plurality of different computational frameworks.', 'As an example, a system can perform relationship mining and discovery between various types of data, which may include data in siloed data stores and/or locked within unstructured documents, and establishing links that enable advanced intelligence tools to discover previously unforeseen patterns between data, which may, to a person, appear innocuous or may not even appear.', 'As an example, a system can leveraging technologies and approaches such as, for example, one or more of explicit relationship declaration (e.g., during ingestion utilizing manifest files), implicit relationship detection (e.g., leveraging pre-defined rules and a system data catalog), and deep relationship mining (e.g., leveraging natural language processing (NLP), fact extraction, and other tools).', 'As an example, a system can be a multi-framework computational system that serves to enable an ecosystem for use of multiple frameworks.', 'Such a system can include one or more ingestion services for ingestion of data, one or more unstructured document content indexing services, one or more fact extraction services, and/or one or more data catalog services.', 'As an example, a system can include a logic engine that includes and/or accesses logical rules that can be utilized to mine relationships.', 'Such types of relationship can include implicit relationships and/or deeply detected and/or predicted relationships.', 'Such relationships may be in addition to explicitly defined relationship; noting that a logic engine can include features that can identify, test and/or confirm a relationship that may be explicitly defined.', 'As an example, a logic engine may operate in one or more modes, optionally with or without use of explicitly defined relationships.', 'For example, consider an explicitly defined relationship that may be stated in a manner that is specific to a particular dataset and/or framework (e.g., a statement as to a relationship).', 'Where a logic engine does not consume that type of statement, parse certain metadata as to the defined relationship, etc., the logic engine may operate in a mode that can nevertheless establish the relationship.', 'In such a manner, a system may optionally operate, to a desired degree, agnostically to explicitly defined relationships.', 'Such an approach may operate to confirm or otherwise verify that a relationship that is explicitly defined in one or more statements, etc., actually exists.', 'As a logic engine may operate in part in a “direction”, foregoing a starting point that uses explicitly defined relationships may, at times, help to mine implicit relationships, detect deep relationships and/or predict relationships.', 'As mentioned, an option may exist to utilize or to not utilize explicitly defined relationships.', 'Where both approaches are performed, a method may include comparing results and optionally augmenting results and/or re-running mining features to generate a robust set of relationships.', 'As an example, a system may operate according to one or more types of relationship models.', 'For example, consider a relationship model that includes vertices and edges.', 'In such an example, logical rules can be implemented to determine entities to a relationship as vertices and nature(s) and/or direction(s) of a relationship as one or more edges.', 'As an example, a system can enable intelligence via relationship discovery, for example, through previously unknown or unforeseen pathways (edges) between distributed entities (vertices).', 'As an example, consider the following convention of logical implication (where → implies a relationship):', 'a→b\n \nb→c\n \nc→ . .', '.\n \n. . .', '→n\n \nTherefore, a→ . . .', 'In the foregoing notation, where “→” is unknown, a dataset may not include indicia of the implied unknown relationship (e.g., not explicitly defined, etc.).', 'As an example, a system may operate to make such a relationship “known”, for example, in the context of domain specific entities, measurements and people.', 'As an example, relationship mining can include operating according to one or more aspects of discovery such as, for example: explicit (structured/pre-defined) relationships; implicit (rule-based) relationships; and deep relationship detection and prediction.', 'As an example, a relationship model can be an output of a system.', 'As an example, such a model may be rendered to a display as a visualization, optionally with vertices and edges.', 'As an example, such a visualization may be animated during a workflow, which may be a workflow that includes establishing at least a portion of the model and/or a workflow that includes utilizing at least a portion of the model.', 'For example, consider a workflow that includes utilizing the model to answer a query such as: “What is the volume of producible oil from a well in relationship to resources expended in producing the volume of producible oil from the well?”', 'In such an example, one or more queries may be issued that traverse the model to determine resources demanded for drilling and operating a well and to determine amounts of oil, water and gas.', 'In such an example, historical, present day and/or future values may be utilized as to resources and amounts to determine a value proposition upon which a decision may be made whether to drill and operate the well.', 'In such an example, a system can access one or more databases such as a pricing database that includes prices associated with fluids produced, separation of produced fluids, etc.', 'As an example, consider accessing one or more databases that may be specific to an entity such as an oilfield services entity where a database may include proprietary cost data.', 'As an example, an oilfield services entity may utilize a system to provide output where the output is then processed using data from a database.', 'As an example, an entity may utilize a system to provide output that can be distributed to one or more other entities, for example, to provide estimates, bids, etc., as to costs to perform one or more aspects of drilling, operating, etc.', 'As another example of utilizing a model, consider a query that asks: “Identify wells that cross the formation YZZ where the porosity is less than 0.2 and that have well logs”.', 'In such an example, a graph model can be utilized to provide an answer that lists such wells.', 'As an example, as the graph model generates results, the results may be visualized on a rendering of the graph model, which may become graphical controls that can be actuated to cause rendering of one or more of the well logs.', 'As an example, a system can organize results from a query, which may optionally be a natural language query, and render the results to a display.', 'For example, consider rendering a well logs to a display for purposes of viewing and comparing to understand how the formation YZZ can be drilled into to form a borehole to that formation, how the borehole can be completed as a well, etc.\n \nAs yet another example, consider a scenario where a producing well is producing oil with a certain fraction of water, which can demand resources for separation of the water from the oil.', 'In such an example, as the fraction of water increases (e.g., due to flooding, etc.), the demand for resources may make the current paradigm unfavorable.', 'However, one or more treatments (e.g., chemical, physical and/or other stimulation treatments) may be available to alter the producing well.', 'For example, consider estimated production being X and actual production being X/2, a query may be run using a system where a model is traversed to determine if a treatment can beneficially impact production.', 'Such an approach may utilize data available from an offset well or offset wells where such a treatment has been implemented with a corresponding physical impact on production.', 'The foregoing examples leverage relationships, which can be relationships that are beyond those that may be specified explicitly by a user or, for example, specified explicitly within a dataset.', 'As an example, a system may be implemented automatically responsive to one or more factors.', 'For example, consider automatically triggering a query in response to production from a well falling below an estimated production value for the well at a particular point in time.', 'In such an example, a query may be formulated for the well, which may utilize the “age” of the well (e.g., production time), to determine if one or more types of operations can address the drop in production.', 'For example, consider a query that may specify: “For a well that is 0.75 of estimated production after 3 years, can one or more of chemical treatment (e.g., acid wash), new perforations, new completion (e.g., packer, etc.), gas lift and electric submersible pump (ESP) artificial lift effectively benefit production for the next year?”', 'Results of such a query can provide results organized for the different types of technologies where a decision may be made to implement one or more of the types of technologies.', 'As mentioned, a system can be utilized for one or more purposes.', 'While datasets and/or databases are mentioned, input can include documents.', 'For example, images, scans, etc., can be input to a system.', 'For example, consider a user that is provided with a given a set of documents for which a bid is to be prepared, which can include a collection of publicly available data and private/corporate data.', 'As an example, a system can provide answers as to how the user can glean an understanding of how these data are connected to expeditiously make an accurate decision with accurate information.', 'The amounts and/or types of data can be beyond the physical mental capacity and capabilities of the user, particularly given a dynamic decision making environment.', 'As an example, a system can process various data and output a graph model that can allow for visualization, optionally animated, that helps a user understand relationships and answers based thereon.', 'Without a good understanding of how data correlates both on existing or known edges and also unforeseen or unknown edges, the user can render her own intelligent answers, decisions, instructions, etc.', 'As an example, model such as a graph model can be a multi-framework model.', 'For example, consider a graph model that includes features associated with a 3D earth model building framework and a drilling framework.', 'In such an example, features can be related via earth properties and drilling equipment and/or drilling operations.', 'Consider a drillstring that can include a measurement component that is particularly suited for making measurements in a formation modeled via the 3D earth model building framework where the drillstring, with that component, is still capable of drilling a desired borehole with a specific dogleg severity (DLS).', 'The relationship between the component and the planned well may not be apparent absent use of a logic engine, which may apply rules and/or operations for deep detection and/or prediction.', 'As an example, a system may provide for a large number of relationships, which can be utilized in expanding utility of a natural language process (NLP) approach to queries.', 'For example, where relationships are limited to those that may be pre-defined and generic to wells, a corresponding corpus for NLP and expressions thereof may be limited.', 'In contrast, where relationships are many, a corpus for NPL and expressions thereof can be expanded.', 'As an example, a system can include mining relationships and building a corpus (e.g., or augmenting a corpus) for making queries, where context may be also built.', 'As an example, consider a scenario where 30 relationships exist in a relational database for a dataset of a framework and where 15 relationships exist in a relational database for another dataset of another framework.', 'In such a scenario, a corpus can contextual expressions thereof can be limited.', 'In contrast, consider a scenario where a system can mine relationships from the two datasets such that 100 or more relationships may be identified where a corpus can be built and contextualized in a richer and deeper manner than the former scenario.', 'In the latter scenario, the number and type of queries can be more numerous (e.g., in terminology and context).', 'As an example, terminology and/or contextual information may be represented in a graph model or in association with a graph model.', 'As an example, a graph model can include a hierarchy.', 'As an example, a graph model can include duplicities.', 'As to a graph model, consider two people, Sally and John, who are friends, where both John and Sally have read the book YYZ.', 'In such an example, vertices (e.g., nodes) can be defined as John, Sally and Book YYZ.', 'Note that although John and Sally are people and book YYZ is a book, there are three vertices as each instance of an entity can be represented as a separate vertex.', 'As to labels, John and Sally can be labeled as “people” and the book YYZ can be labeled as a “book”.', 'Further, the graph model can include relationships where a relationship connects two vertices and provides for finding one or more related vertices of data.', 'A relationship can be defined to have a source vertex and a target vertex that can be indicated as source and target by a direction (e.g., an arrow).', 'As an example, a relationship can be stored to a data structure with a particular direction; noting that traversal can be uni-directional (e.g., along a specified direction) or bi-directional (e.g., in either direction), which can, for example, provide for querying a relationship without specifying direction.', 'As to the foregoing example, four relationships can be: John is friends with Sally; Sally is friends with John; John has read Book YYZ; and Sally has read Book YYZ.', 'Thus, a graph model can include John and Sally as vertices (labeled “people”) and can be connected to each other by an “is friends with” type of relationship; and John and Sally have both read the book YYZ such that each of their vertices (each labeled “people”) can be connected to the Book YYZ vertex with a “has read” type of relationship.', 'In the foregoing example, terminology can include, for example, people, people names, books, book names, friend, friends, “friends with”, and “read”.', 'A natural language query may ask one of: (a) “What people have read the book YYZ?” or (b) “Has a friend of John read the book YYZ?”.', "Such queries can provide answers: (a) “John and Sally have read the book YYZ” or (b) “Yes, Sally, a friend of John's, has read the book YYZ”.", 'As an example, one or more properties may be stored in association with one or more relationships.', 'For example, consider a date for which John and Sally became friends (“is friends with relationship”) or, for example, consider a rating given to the John to Book YYZ “has read” relationship and another rating given to the Sally to Book YYZ “has read” relationship.', 'As an example, an answer can utilize terms of a query and optionally one or more additional terms to assure that an answer is placed in a proper context.', 'Such an approach can help to assure that answers are read in a proper context.', 'As an example, for a system for multiple frameworks associated with oilfield operations, safety and costs can be concerns where miscommunication can result in unsafe conditions and/or unexpected costs.', 'As an example, a graph model approach can help to reduce miscommunication where answers are output in a context.', 'As an example, a system can include a context option that can provide for output in context or, for example, simple output.', 'As to simple output, consider the John/Sally example where simple output may be (a) “John, Sally”; or (b) “Yes”.', "As an example, where a query is no longer rendered or where a query may have been submitted where a considerable amount of time passes before an answer is returned, an “in context” format to an answer can be beneficial to refresh a user's mind as to the query.", 'As to a considerable amount of time, a multi-framework system may involve consideration of multiple dataset for multiple wells where a dataset may be of the order of a gigabyte or more.', 'In such an example, time to generate output (e.g., an answer) may be of the order of minutes or more.', 'As an example, a system can generate a graph model that abides by a rule such as no broken links.', 'Such a rule may be implemented to help ensure that an existing relationship will not point to a non-existing endpoint.', 'As an example, a relationship can be defined as having a start vertex and an end vertex.', 'As an example, a graph model may be user editable.', 'For example, consider a graphical user interface (GUI) that includes features for deleting a vertex, which can call for deleting its associated relationship or relationships.', 'In such an example, consider a graph mode that includes labels for wells such as Well A, Well B and Well C.', 'If a user understands that Well C is not a proper analog of a well under consideration (e.g., Well A, Well B or another well), the user may delete or otherwise cause Well C to be effectively deleted.', 'As another example, consider Well C being shut-in and no longer producing.', 'In such an example, one or more production vertices that have a relationship with Well C (e.g., prior production data for Well C) may be of less relevance to a query and hence deleted from the graph model.', 'In such an example, aspects (e.g., vertices) that are relevant to a query may be retained while some that are less or not relevant may be deleted, which may provide for answers in a more expeditious manner and/or more accurate answers (e.g., in context, etc.).', 'As an example, a query can be in a context that utilized negation.', 'For example, “and not in a vertical well”.', 'A system may interpret such language to negate “vertical well” vertices, which may expedite traversal of a graph model that includes labels, for example, as to “well type” where a “well type” may be selected as being vertical, deviated, etc.', 'As an example, depending on settings, a system may optionally execute a query in a manner that effectively deletes certain links (e.g., relationships) and/or vertices from a graph model and/or traversal thereof.', 'As an example, a user (e.g., a hybrid data scientist/data manager) can target a specific field, and opt to analyze relationships of data, for example, data that may pivot on rig or drilling contractor.', 'As an example, a system, fueled by the relationships discovered through aspect pillars (e.g., explicit, implicit, and deep relationships) can provide a context of a rig and/or rigging contractor.', 'Such a system can include mining features such that relationships can be discovered.', 'For example, consider one or more of the following examples: as stuck pipe is 40 percent more likely when the rig is X when crossing formation Y; or broken drill bits is 85 percent more likely when the drilling contractor is A but 70 percent less likely when the drilling contractor is B.\n \nAs an example, a system can include features that can be exposed across multiple users, which may be from different entities.', 'For example, consider a system that can detect trends in queries as to one or more types of data and that can issue notifications, optionally automatically, that can help to increase such data.', 'As an example, consider a system that enables data commoditization and/or marketplace business, e.g. “third party data in this area of interest is available for purchase from IHS and WelIDB”, or “There is a lot of active interest in this area.', 'Would you like to offer a dataset for sale to third parties?”', 'As an example, a system can include components that are operable to provide insights across structured and/or unstructured data, for example, between explicit, implicit, and deep relationships.', 'As an example, a system can include components operable to establish, maintain, etc., one or more relational databases, one or more graph databases, document content indexing and/or fact extraction.', 'As mentioned, explicit (e.g., structured/pre-defined) relationships may exist and be detectable or otherwise uncoverable.', 'An example of an explicit (structured/pre-defined) relationship can be one that is available through ingesting documents or sub-entities into a system and linking them directly with wellbores previously ingested into the system.', 'As an example, an ingestion process can ingest well data and associated artifacts like well tops, well logs, and documents into a system.', 'Such an approach may occur in a batch, periodic, semi-continuous and/or continuous manner, optionally in real-time during field operations.', 'As an example, an ingestion service may be implemented with an approach where one or more relationships can be defined, for example, in a manifest file.', 'As an example, consider the following data structure as being utilized to specify a relationship in a manifest file:\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nWellbore:\n \n \n \nName\n \nDesc.\n \nCreated\n \nModified\n \nType\n \nSize\n \nTitle\n \nAuthor\n \nAPI\n \n \n \n \n \n \n \n \nCSW-\n \nPIPESIM\n \n20XX-\n \n20XX-\n \nApp/pips\n \n590 kb\n \nPIPESIM\n \nSK\n \n500192\n \n \n \n101.pips\n \nModel\n \n02-12\n \n02-27\n \n \n \nModel\n \n \n \n \n \n \n \n \n \n \n \nfor Well\n \n \n \n \n \n \n \n \n \n \n \nCSW-101\n \n \n \n \n \n \n \n \n \n \nIn the foregoing example, the data structure can include: file-fileName (see “Name”), which includes the filename of the related file (e.g., document, log, top, model, etc.)', 'that is to be related to a target vertex; attribute-documentTitle (see “Title”), which includes pertinent metadata about the source vertex to enable discovery; and relationship-ingestion-test:wellbore:api (see “Wellbore:API”), which includes an explicitly defined relationship along with a target entity (wellbore) and target attribute to search/match against (API).', 'In the foregoing example, the file with name CSW-101.pips (e.g., a PIPESIM model of a surface network simulation framework) can be stored in a storage device (e.g., a remote device such as a cloud-based resource) and the corresponding file metadata that includes the attributes can be stored in a storage device of a system (e.g., local and/or remote).', 'At the time of ingestion process, records of type “wellbore” can be searched where the attribute “API” equals “500192”.', 'In such an example, if a record is found in the system, then the record metadata for CSW-101.pips will include a relationships data block with reference to “wellbore” record having the “API” attribute including the value of the manifest file.', 'Below is an example of code in the PYTHON language:\n \n \n \n \n \n \n \n \n \n \n \n \n \n“data”: {\n \n \n \n“fileName”: “CSW-101.pips”,\n \n \n \n“fileDescription”: “PIPESIM Model”,\n \n \n \n“dateCreated”: “20XX-02-12717:57:002”,\n \n \n \n“dateModified”: “20XX.02-27T12:07:002”,\n \n \n \n“mimeType”: “application/pips”,\n \n \n \n“fileSize”: “590 kb”,\n \n \n \n“documentTitle”: “PM” (e.g., “PIPESIM Model for Well CSW-101”),\n \n \n \n“documentauthor”: “SK”,\n \n \n \n“ingestion-test:wellbore:api”: “500192”,\n \n \n \n“bucketURI”: “gs://. . . /. . .', '/CSW-101.pips”,\n \n \n \n“relationships”: [\n \n \n \n{\n \n \n \n“wellbore”: [“slb: ingestion-test :wellbore-XXTTTA”], “confidence score”: 100\n \n \n \n}\n \n \n \n],\n \n \n \n“jobId”: “1231505971-20XX-09-19-16.43-22-927”\n \n \n \n},\n \n \n \n“id”: “slb:ingestion-test:wellbore-CSW-101.pips-20XX-09-19-16-43-39”,\n \n \n \n“version”: 1537375421235857,\n \n \n \n“kind”: “slb:ingestion-test:wellbore:1.0.0”,\n \n \n \n“acl”: {“viewers”: [“data.ingestion.test@slb.cloud.slbX.com”],\n \n \n \n“owners”: [“data.ingestion.test@slb.', 'cloud.slbX.com”]\n \n \n \n},\n \n \n \n“legal”: {“legaltags”: [“slb-CountryIndex”],\n \n \n \n“otherRelevantDataCountries”: [“BE”, “US” ],\n \n \n \n“status”: “compliant”\n \n \n \n}\n \n \n \n \n \n \n \n \n \n \nIn the foregoing example, as to the confidence score (see, e.g., value of “100”), if search results for the entity to which this artifact is to be connected is 1, then the confidence score is 100 percent.', 'A confidence score can be reduced with number of search results.', 'For example, if there are two results available in the system with a common “id”, then the confidence score can be determined to be 50 percent.', 'Such an approach allows users to understand that sometimes, relationships that are identified may be duplicates and/or of low value.', 'As mentioned, a system may include a feature that can utilize explicit relationships or not.', 'As an example, a system may include a feature that can analyze explicit relationships, which can include, for example, determining a confidence score that is based on a number of instances of an explicit relationship.', 'As to implicit (e.g., rule-based) relationships, a system can include relationship mining as a level that infers relationships, for example, based on values of data.', 'Such an approach may utilize a known/given set of relationship rules or inference points.', 'As an example, a system may operate according to a hierarchy where different types of levels can exist in the hierarchy.', 'For example, where explicit relationships are utilized, a level that corresponds to explicit relationships can be different than a level that corresponds to implicit relationships.', 'As an example, a system may operate in a sequential manner according to a hierarchy.', 'For example, consider executing operations to determine explicit relationships prior to executing operations to determine implicit relationships.', 'As mentioned, a hierarchy can include selectable operations where, for example, a user may select one or more levels of a hierarchy.', 'As to an example of implicit relationship discovery by a system, consider how digital well logs may be related to a corresponding wellbore, which may be a wellbore already ingested by the system.', 'In such an example, consider a digital well file that is stored in a LAS 2.0 format (e.g., “LAS file”) as associated with a computational framework.', 'In such an example, the system can parse the LAS file and attempt to relate it to an existing wellbore in the system, for example, given the following rule order and match rules.', 'In such an example, where a given rule condition is met, the system can specify the relationship and confidence score (e.g., and optionally exits the implicit workflow).', 'Example Rule Priority Order: (i) Link to WKE Wellbore; (ii) Link to Raw (unprocessed) Wellbore; (iii) Link to Raw Wellbore from the -W (wellbore) information block in the LAS file.', 'As to a rule match order, in the foregoing example, rule match attributes can be based on attribute names matching the LAS 2.0 format standard mapped against “Well Known Attributes” specified in a data catalog service of a system.', 'As an example, consider one or more of the following: Match based on UWI (Unique Well Identified); Match based on API (American Petroleum Institute Number); and Match based on WELL (mapped to “Well Name” as the WKA, mapped to source “Well Name” as per source/attribute).\n \nFIG.', '10\n shows an example of a graphical user interface (GUI) \n1000\n that includes data according to a data catalog service as mapping “WKA” for “Wellbore” entity to various “Raw” sources; noting that some sources include more or less attributes.', 'In the example GUI \n1000\n, consider “Well Name” (see also, e.g., “WellName”, “Well_Name”, etc.).', 'FIG.', '11\n shows an example of a graphical user interface (GUI) \n1100\n that includes various panels, including a file panel and linking component panels.', 'The GUI \n1100\n may be utilized as part of an ingestion and linking workflow.', 'As to the file panel (left side), it can render data from the ingested file, which, as mentioned, can be in a format that is associated with a particular computational framework (e.g., PIPESIM, PETREL, etc.).', 'As an example, data may be organized with a well heading, a curve heading and a parameter heading.', 'In such an example, the file can be parsed or organized with well data, log (e.g., curve) data, and measurement values (e.g., parameter values).', 'As to the linking component panels, these may include a log set panel, a wellbore panel, a log panel, a log channel measurement panel and/or one or more other panels.', 'The various linking panels may be particular to one or more types of files and, hence, for example, be particular to one or more types of computational frameworks.', 'As an example, a log set panel can provide for handling of raw, unprocessed log channels as may be grouped by a file that can be ingested.', 'In such an example, each channel can include an ID (e.g., LogStore ID) and link to a well (e.g., WKE or Raw).', 'As an example, a wellbore panel can provide for handing of linking such as linking a “Log Set” to a well per “Well WKE” by using indicators such as UWI, API and/or “Well Name”.', 'As to a log panel, it can provide for handling of channels such that each channel can be ingested into a data lake of a system\n \nFor example, consider intesting each channel as an individual raw log record.', 'Such an approach may follow one or more types of schema, for example, consider a Well-Known Scheme for ingestion based on a Log WKE', 'Well-Known Schema.', 'In such an example, each “Log” can include a LogStore ID and a link to a wellbore (e.g., WKE or Raw).', 'As to a log channel measurements panel, such a panel can provide for handling individual log channels.', 'For example, individual log channels (Log Channel) can be ingested into a log store (LogStore) with a corresponding ID (LogStore ID) written back to the Log Set and corresponding Log.', 'As an example, a confidence score can be associated with each implicitly derived relationship to allow a user a better understanding of the nature of a derived relationship.\n \nFIG.', '12\n shows an example of a graphical user interface (GUI) \n1200\n as in \nFIG.', '11\n where various relationships are indicated.', 'Specifically, a well name is shown as existing within a portion of the ingested file.', 'As an example, a file can include data that pertains to measurements such as, for example, data as in Table 1 below.\n \n \n \n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \n \n \n \n \nDEPT.', 'm\n \nDepth\n \n \n \n \nBS.', 'in\n \nBS\n \n \n \n \nCALI.', 'in\n \nCalibration\n \n \n \n \nDRHO.', 'g/cm3\n \nDensity\n \n \n \n \nDT.', 'us/ft\n \nDT\n \n \n \n \nGR.', 'gAPI\n \nGR\n \n \n \n \nIDPH. ohm · m\n \nIDPH\n \n \n \n \nIMPH. ohm · m\n \nIMPH\n \n \n \n \nNPHI.', 'm3/m3\n \nNPHI\n \n \n \n \nRHOB.', 'g/cm3\n \nRHOB\n \n \n \n \nILD. ohm · m\n \nILD\n \n \n \n \nILM. ohm · m\n \nILM\n \n \n \n \nSW.\n \nSW\n \n \n \n \nKLOG.', 'mD\n \nKLOG\n \n \n \n \n \n \n \n \n \n \n \nAs an example, the data in Table 1 may be in a file along with data such as the data of the GUI \n1200\n of \nFIG.', '12\n.', 'For example, the data in Table 1 can be in a “curve” portion of a file.', 'As mentioned, a parameter portion of a file can include measurements (e.g., measurement values) that can correspond to data such as the data in Table 1.', 'In \nFIG. \n11\n, the panel “-measurements” can include log channel measurements as may be specified according to the data in Table 1.', 'For example, measurements can be measurement values from sensors, which may be raw, processed, etc., by one or more tools (e.g., surface and/or downhole).', 'As explained, an explicit relationship can be deterministic and an implicit relationship may be deterministic.', 'As to deep mining of relationships, which can include detection and/or prediction, it can be probabilistic.', 'A probabilistic relationship can be derived from probability, which may account for randomness in occurrence of one or more entities, events, etc.', 'As an example, a deterministic relationship may be from a deterministic model that suggests there are known reasons and/or causes of relationships.\n \nFIG.', '13\n shows an example of a system \n1300\n that includes a data insight system \n1340\n and a fact extraction system \n1360\n.', 'As shown, the system \n1300\n can detect and/or predict and output a relationship \n1380\n, which is shown in the context of a document and an extracted fact.', 'The system \n1300\n can perform relationship mining that is probabilistic, and based on a combination of heuristics, fact extraction, natural language processing, and advanced relationship management enabled by technologies such as, for example, the GRAPHDB framework (Ontotext USA, Inc., Jersey City, New Jersey).', 'The GRAPHDB framework includes a semantic graph database, compliant with W3C standards.', 'As an example, a semantic graph database (e.g., a RDF triplestore, etc.) can provide a core infrastructure for solutions where modelling agility, data integration, relationship exploration and cross-enterprise data publishing and consumption are desired.', 'A framework can provide one or more of various types of support.', 'For example, consider SPARQL (a recursive acronym for SPARQL protocol and RDF query language), which is an RDF query language (e.g., a semantic query language for databases that is able to retrieve and handle data stored in the resource description framework (RDF) format).', 'FIG.', '14\n shows an example of a framework \n1400\n, which can include one or more features of the GRAPHDB framework.', 'As shown, the framework can include a workbench component, an engine and connectors.', 'The engine can include a query optimizer, a reasonser, storage and a plugin manager.', 'The storage can include an entity pool, statements indexes, a literal index and optional context indexes.', 'The plugin manager may provide for access to various plugins, optionally via one or more of the connectors.', 'For example, consider a geo-spatial plugin, a LUCENE plugin, a RDF Rank plugin, etc.', 'As to connectors, consider a LUCENE connector, a SOLR connector for APACHESOLR, and an elasticsearch (ES) connector for ELASTICSEARCH.', 'Various Apache Software Foundation (Forest Hill, Maryland) components may be utilized via a framework.', 'For example, consider a LUCENE core, which provides JAVA-based indexing and search technology, as well as spellchecking, hit highlighting and advanced analysis/tokenization capabilities.', 'As another example, consider SOLR, which is a high performance search server built using the LUCENE core, with XML/HTTP and JSON/PYTHON/RUBY APIs, hit highlighting, faceted search, caching, replication, and a web administration interface.', 'As another example, consider PYLUCENE, which is a PYTHON language capabilities port of a core project.', 'ELASTICSEARCH (“ES”) (Elastic B.V., Mountain View, California) is a search engine based on the LUCENE library.', 'ES provides a distributed, multitenant-capable full-text search engine with an HTTP web interface and schema-free JSON documents.', 'ES is developed in Java.', 'In a server-client architecture, clients are available in JAVA, .NET (C#), PHP, PYTHON, APACHE GROOVY, RUBY and other languages.', 'RDF Rank is an algorithm that can identify more relevant and/or more popular entities in a repository by examining their interconnectedness.', 'The popularity of entities can then be used to order query results (e.g., ranking results).', 'The RDF Rank component computes a numerical weighting for nodes (e.g., vertices) in an entire RDF graph stored in a repository, including URIs, blank nodes and literals.', "The weights can be floating point numbers with values between 0 and 1 that can be interpreted as a measure of a node's relevance/popularity.", 'In the framework \n1400\n, the query optimizer can be configured to attempt to determine an efficient way to execute a given query by considering one or more possible query plans.', 'As an example, once queries are submitted and parsed, they can then be passed to the query optimizer where optimization occurs.', 'As an example, hints can be utilized for guiding a query optimizer.', 'As to a reasoner, the framework \n1400\n can include a TRREE engine for triple reasoning and rule entailment.', 'Such an engine can perform reasoning based on forward-chaining of entailment rules over RDF triple patterns with variables.', "TRREE's reasoning strategy can involve total materialization; noting that various optimizations can be used.", 'As to storage, the framework \n1400\n may store its data in files in a configured storage directory, which can include indices on statements predicate-object-subject (POS) and predicate-subject-object (PSO), context index CPSO, literal index and page cache, where indices on statements for use in inference and query evaluation can include, for example, a predicate-object-subject (POS) index and/or a predicate-subject-object (PSO) index.', 'As to an entity pool, the framework \n1400\n can include such a pool and features to convert entities (e.g., URIs, blank nodes and literals) to internal IDs (e.g., 32-, 40-bit integers, etc.).', 'As an example, an entity pool may support transactional behavior, which can improve space usage and cluster behavior.', 'As to connectors, the framework \n1400\n can include one or more connectors that provide rapid keyword and faceted (e.g., aggregation) searches that can be implemented by an external component or service, which may have an ability of staying automatically up-to-date with GRAPHDB repository data.', 'Referring again to the system \n1300\n, it shows a probabilistic relationship discovered through fact extraction from unstructured documents and relating the relationship to structured data that exists in a multi-framework system such as the system \n800\n of \nFIG.', '8\n.', 'FIG.', '15\n shows an example of a graphical user interface (GUI) \n1500\n in a table form where probabilistic relationships can be discovered through natural language processing of structured data that exists in a multi-framework system such as the system \n800\n of \nFIG.', '8\n.', 'FIG.', '16\n shows an example of a graphical user interface (GUI) \n1600\n in a graphical form.', 'The graphical form includes various types of relationships as may be determined using one or more of explicit, implicity and deep technologies.', 'Such a graphic form can be extremely complex as to its relationship, which can be both deterministically and probabilistically generated.', 'As an example, a method may include autogeneration of a structure such as a graph structure.', 'For example, where data include a number of entities of one type that exceeds a number of entities of another, different type, a method can include autogeneration of a graph structure where the more numerous entities are positioned at a different level (e.g., radially outwardly, etc.).', 'As shown in \nFIG.', '16\n, oil, water and gas volumes are more numerous than wellheads such that a graphical representation may place fluid volume entities in a direction that is outward from a center or outward from a wellhead.', 'As an example, relationships such as “has” relationships may be automatically established (e.g., “has production volume”, “has oil volume”, “has water volume”, “has gas volume”, etc.).', 'FIG.', '17\n shows an example of a graphical user interface (GUI) \n1700\n in a graphical form of a technical problem with a technical solution.', 'As shown, a user can readily find well logs in the context of one or more workflows.', 'In the example of \nFIG.', '17\n, various types of subsurface data can be understood in relationship to various types of production data.', 'For example, consider a well “A10” being in a graph or graph database such that various types of relationships can be determined and assigned where the well A10 can be represented as a vertex (e.g., a node) with various relationships (e.g., edges).', 'In such an example, deterministic and/or probabilistic techniques can be utilized to establish the relationships.', 'As an example, a corpus of terminology and contextual information may be generated by a relationship mining process such that the formulation of various queries may be guided by such a corpus.', 'As an example, a query can be submitted via a graphical user interface (e.g., a search field or search fields) and/or can be submitted automatically (e.g., by a piece of equipment).', 'As to the latter, consider a piece of equipment that includes or is operatively coupled to a sensor or sensors.', 'In such an example, sensor data may indicate that a limit may be reached (e.g., an alarm limit, etc.)', 'such that a notification and/or a control action is to be taken.', 'A trigger can cause issuance of a query, optionally including one or more measurement values, equipment type, etc., where a query results may be communicated to a computing device for rendering to a display or other action.', 'As an example, a trigger, query and query results can be in a “machine” understandable language.', 'For example, consider a controller that is operatively coupled to one or more sensors and one or more actuators where the controller operates according to a programming language executable in an operating system environment established by a processor of the controller.', 'The controller may issue a code as a query where a search engine can translate the code into a natural language query.', 'For example, consider a database (e.g., a table, etc.) that can associate the code with a natural language query.', 'In such an example, the codes and/or queries may be programmed in advance, for example, by a user of equipment during and/or prior to operations.', 'For example, as to data that include data from a downhole tool for a particular wireline job in a borehole, a user may have some questions in mind prior to performing the job where those questions can be related to codes.', 'As an example, consider “does an offset well have lithology Y at a true vertical depth between X meters and Z meters?”', 'Such a query may be issued responsive to a measurement acquired by the downhole tool that is germane to the query (e.g., a depth, a lithology measure, etc.).', 'Results from a natural language query may be translated back into a code for communication to and consumption by the controller to take one or more control actions.', 'In the foregoing example, consider a result that pertains to an offset well that gives the downhole tool a code to start acquiring data at a greater resolution, with greater frequency, to slow down movement of the downhole tool (e.g., via surface equipment), etc.', 'For example, consider a result being translated into a code YZY that instructs circuitry of the downhole tool to increase frequency of measurements (e.g., rather than once per minute, taking measurements twice per minute, etc.).', 'As an example, where a code has been translated into a natural language query, that query may be rendered to a display of an operator such that the operator can readily determine what the controller is doing (e.g., a controller of a downhole tool and/or another piece of equipment or pieces of equipment, etc.).', 'Similarly, query results in natural language form may be rendered to a display such that an operator can readily determine what a controller is being instructed to do.', 'In such an example, a computing device accessible by the operator may provide for a confirmation of the query result/control action prior to implementation thereof by the controller.', 'Consider an example as to pump rate of drilling fluid for drilling a wellbore X, where a controller issues a query as a code such as \n1047\n, which, in natural language, asks “Is a pump rate of 2000 gallons per minute too high?”.', 'In response, a framework can generate a natural language answer of “At the measured depth of 1500 feet in wellbore X, the maximum is to be 1800 gallons per minute, so, yes, the pump rate is too high”.', 'In translation to a code, consider a code \n2475\n, which instructs the controller to reduce the pump rate to a maximum of 1800 gallons per minute for the next 500 feet of drilling in wellbore X.', 'The answer can be based on one or more other wellbores, which can be “related” to the wellbore X, along with their pump rates for particular depths (e.g., in a particular formation) with particular equipment.', 'In such an example, as an option, an operator station can see the transaction of the controller via a graphical user interface that can include a graphical control that is actuatable to allow the query result to be translated into a code for communication to and consumption by the controller.', 'Upon actuation, the translation can occur and the controller can effectuate the control action.', 'Such an example may be implemented in a system such as the system \n470\n of \nFIG.', '4\n (see, e.g., the mud tanks \n430\n, the pump buildings \n440\n, etc.).', 'Such an example can include one or more operations associates with the system \n800\n of \nFIG. \n8\n.', 'For example, a construction framework may provide for acquiring and processing drilling data, which includes drilling fluid data and measured depth data, along with equipment data, etc.', 'A framework such as the framework \n1400\n can generate a graph with relationships using such data, optionally along with formation types of data as may be from an exploration framework (see, e.g., wireline logging operations systems of \nFIG. \n5\n).', 'As mentioned, well logs can be considered in forming a graph, which can include detailed property data as recorded with respect to depth for one or more formations.', 'As an example, relationships can be established between formation properties, measured depth, true vertical depth, drilling, etc., which can be utilized by people and/or machines to control one or more types of field operations.', 'As an example, a system may operate in real-time where queries and query results are generated by the system where such queries may be entered via a graphical user interface, a natural language interface, a machine interface, etc.', 'As an example, an interface can include a speech-to-text interface and/or a text-to-speech interface.', 'In such an example, a user may have a cellphone that can be used to call and/or text a query interface in a natural language manner.', 'For example, consider a driller at a wellsite calling a query interface and being prompted to speak a query.', 'In such an example, the driller can speak a query in a particular format, which may commence with a wellsite ID, for example, “I am at wellsite \n3757\n, is a production volume of oil of XYZ barrels per day too low?”.', "In response, the driller's cellphone may receive a speech answer and/or a text answer.", "In such an example, a text message answer may be stored to a database, along with the driller's query in the form of a text message (e.g., where speech-to-text conversion is applied).", 'FIG.', '18\n shows an example of a GUI \n1800\n that can be part of a process that involves searching to uncover relationships, data, etc.', 'For example, consider a natural language search such as “show me actual aggregate oil, gas, and water production volumes for completions that were active in 20XX”.', 'In such an example, output may be generated and rendered via a GUI such as the GUI \n1800\n.', 'In the example of \nFIG.', '18\n, a field includes the following: “$ MATCH (w:wellBore)-[r:Has_Complet.]-(c:complet.)-[:Has_Prod._Vol.]-(v) where r.startDate>‘12/31/20XY’ AND rendDate>=‘1/1/20XX’ RETURN v.name, sum(v.volume)”.', 'Such information may be generated in response to a natural language query.', 'As shown, an oil volume actual field includes a sum of 1000, a water volume actual field includes a sum of 1800 and a gas volume actual field includes a sum of 1400.', 'The information rendered is responsive to the query and quantitative.', 'For example, computations may be performed on data accessed responsive to the query to provide for the sums shown in the GUI \n1800\n of \nFIG.', '18\n.', 'In \nFIG.', '18\n, the results of the query are shown in row form, noting that one or more other forms may be utilized for presentation of results (e.g., and/or intermediate results such as individual amounts of oil, water and gas from individual wells, regions, etc.).', 'FIG.', '19\n shows an example of a GUI \n1900\n that pertains to a natural language query: “Show me daily drilling reports for wellbores that cross the Bakken formation where porosity is <0.2”.', 'The example output is rendered in a graphical form.', 'For example, responsive to receipt of the natural language query a framework can logically uncover documents that are daily drilling reports with information germane to the query.', 'In such an example, the one or more graphics can be graphical controls that can be actuated to, for example, access details of a report, render one or more additional vertices, exposed and/or render one or more edges, etc.', 'With reference to the GUI \n700\n of \nFIG.', '7\n, one or more features of the GUIs \n1700\n and \n1800\n may be utilized.', 'For example, consider one or more of the graph area \n750\n, the query field \n760\n, and the query result(s) field \n770\n as corresponding to one or more of the graph area of the GUI \n1800\n, the formulated query (e.g., “match” statement) of the GUIs \n1700\n and \n1800\n, and the row area of the GUI \n1700\n (e.g., table format, etc.), respectively.', 'Before the claims, an example computer program listing appears, which is more than 60 lines and less than 300 lines.', 'The example listing includes examples of some schemas that may be utilized for one or more relationships.', 'As an example, a method can include utilizing a natural key (e.g., name, etc.) approach to relationships.', 'As an example, a method can include calculating confidence scores as part of a relationship process.', 'In the example computer program listing an example is also given, which pertains to relationships as to wellbores that includes confidence information.', 'In the example computer program listing, the attribute “names” may be an optional attribute for a relationship producer to indicate a natural key by which a relationship can be identified.', 'For example, name may be identified by “featured attribute” for a particular entity.', 'As to confidence score, a heuristic relationship context may be used for calculation thereof.', 'For example, consider confidence score being equal to 1/X % where X is the number of relationships discovered.', 'As an example, a GUI such as the GUI \n700\n may be utilized to make queries that return results where results can include those that may be expected for a relational database search (e.g., using SQL) and can include those that are beyond what a relational database search can provide.', 'For example, rather than using a structured query language (SQL), the GUI \n700\n can provide for natural language types of queries such as one or more of the examples illustrated in the GUI \n1800\n of \nFIG.', '18\n and the GUI \n1900\n of \nFIG.', '19\n.', 'As an example, a natural language query may pertain to production operations and query data for production volumes subject to dates, ranges of dates, production composition, etc.', 'As an example, a natural language query may pertain to one or more drilling operations such as stuck pipe, drilling operators, etc.', 'As an example, a result from a query can be in one or more forms, which may be text, tabular, graphical, animated, etc.', 'As an example, consider a graphical user interface that includes one or more sliders that can alter a date, a composition, a region, etc., in real-time where results are generated and rendered.', 'Such an approach can allow for a natural language query and identification of information in the natural language query that may be quantified in one or more manners.', 'For example, where a query includes a date range, a GUI may be rendered with a date slider such that adjustment of the date using the date slider causes display or highlighting of results that pertain to a date or range of dates.', 'As another example, consider a production query with amount of gas in produced fluid, which may be quantified as a percentage or a fraction.', 'In such an example, a GUI may be rendered based on the natural language query being parsed for quantifiable information that includes the gas percentage or gas fraction.', 'A GUI may be rendered that includes a slider control for gas percentage or gas fraction where a user may adjust the slider of the slider control to cause the GUI to display or highlight particular results.', 'As an example, where a natural language query includes multiple quantifiable aspects, a multi-slider approach may be utilized.', 'As mentioned, an animated approach may be implemented, for example, to animate with respect to time for a series of dates, whether rendering results forward in time and/or backward in time (e.g., temporal navigation, etc.).', 'As an example, a query may be made that operates in an ongoing or periodic manner.', 'For example, consider a query as to stuck pipe where incoming drilling data are analyzed and added to results where the analyzed drilling data indicate that a stuck pipe condition has occurred.', 'As an example, a query may have no results and be set to run on future data.', 'For example, consider a query including a phrase as to an oil fraction in produced fluid where existing production data do not indicate that such an oil fraction has been achieved (e.g., whether low or high or between two values).', 'In such an example, the query may be ongoing and generate a result once such an oil fraction has been achieved per available production data.', 'As an example, a query may generate results using explicit relationships and/or implicit relationships.', 'For example, an explicit relationship may be between a wellbore and a formation characteristic where an implicit relationship may be via an extended approach that includes relationships such as the aforementioned “has” types of relationships in a vertices and edges framework (e.g., a graph approach, a graph like approach, etc.).', 'As mentioned, “has” types of relationships may be with respect to vertices and can include, for example, for production data “has production volume”, “has oil volume”, “has water volume”, “has gas volume”, etc.', 'As to drilling operations data, “has” may be for one or more of the following examples: “has stuck pipe”, “has BHA XYZ”, “has drilling fluid YYZ”, “has perforations”, “has cement”, etc.', 'As to types of production equipment, consider one or more of the following examples: “has artificial lift”, “has electric submersible pump”, “has gas lift”, “has steam assisted gravity drainage”, etc.', 'As to logging, consider one or more of the following examples: “has GR”, “has images”, “has resistivity”, “has temperature”, “has pressure”, “has used tool YY”, “has NMR”, etc.', 'As an example, a method can include accessing data generated during field operations; generating a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and generating a query result using the graph responsive to receipt of a query.', 'In such an example, the field operations can include drilling operations and logging operations.', 'As an example, vertices can include well-related vertices and, for example, relationships can include one or more of well equipment-based relationships, well production-based relationships, formation-based relationships, and well log-based relationships.', 'As an example, a method can include generating a corpus based at least in part on labels of vertices and natural language of relationships.', 'In such an example, a method can include guiding formulation of a query using the corpus.', 'As an example, a method can include rendering a graph to a display.', 'In such an example, the graph may be animated, include a slider control, include slider controls, etc.', 'As an example, a graph may be adjustable with respect to time, which may be via an animation, a slider control, a play control, a reverse play control, etc.', 'As an example, a method can include receiving the query from a controller operatively coupled to field equipment.', 'In such an example, the method can include translating the query from the controller to a natural language form and/or translating the query result from a natural language form to a code and transmitting the code to the controller.', 'In such an example, a method can include receiving a signal responsive to actuation of a graphic control of a graphical user interface where the signal triggers transmitting the code to the controller.', 'As an example, relationships can include probabilistic relationships, for example, where the relationships include deterministic relationships.', 'As an example, relationships can include explicitly defined relationships, implicitly defined relationships and probabilistically defined relationships.', 'As an example, relationships can include probabilistically defined relationships between sensor data and well identification data.', 'As an example, a system can include a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: access data generated during field operations; generate a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and generate a query result using the graph responsive to receipt of a query.', 'As an example, one or more computer-readable storage media can include computer-executable instructions executable to instruct a computing system to: access data generated during field operations; generate a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and generate a query result using the graph responsive to receipt of a query.', 'In some embodiments, a method or methods may be executed by a computing system.', 'FIG.', '20\n shows an example of a system \n2000\n that can include one or more computing systems \n2001\n-\n1\n, \n2001\n-\n2\n, \n2001\n-\n3\n and \n2001\n-\n4\n, which may be operatively coupled via one or more networks \n2009\n, which may include wired and/or wireless networks.', 'As an example, a system can include an individual computer system or an arrangement of distributed computer systems.', 'In the example of \nFIG. \n20\n, the computer system \n2001\n-\n1\n can include one or more modules \n2002\n, which may be or include processor-executable instructions, for example, executable to perform various tasks (e.g., receiving information, requesting information, processing information, simulation, outputting information, etc.).', 'As an example, a module may be executed independently, or in coordination with, one or more processors \n2004\n, which is (or are) operatively coupled to one or more storage media \n2006\n (e.g., via wire, wirelessly, etc.).', 'As an example, one or more of the one or more processors \n2004\n can be operatively coupled to at least one of one or more network interface \n2007\n.', 'In such an example, the computer system \n2001\n-\n1\n can transmit and/or receive information, for example, via the one or more networks \n2009\n (e.g., consider one or more of the Internet, a private network, a cellular network, a satellite network, etc.).', 'As an example, the computer system \n2001\n-\n1\n may receive from and/or transmit information to one or more other devices, which may be or include, for example, one or more of the computer systems \n2001\n-\n2\n, etc.', 'A device may be located in a physical location that differs from that of the computer system \n2001\n-\n1\n.', 'As an example, a location may be, for example, a processing facility location, a data center location (e.g., server farm, etc.), a rig location, a wellsite location, a downhole location, etc.', 'As an example, a processor may be or include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'As an example, the storage media \n2006\n may be implemented as one or more computer-readable or machine-readable storage media.', 'As an example, storage may be distributed within and/or across multiple internal and/or external enclosures of a computing system and/or additional computing systems.', 'As an example, a storage medium or storage media may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLUERAY disks, or other types of optical storage, or other types of storage devices.', 'As an example, a storage medium or media may be located in a machine running machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'As an example, various components of a system such as, for example, a computer system, may be implemented in hardware, software, or a combination of both hardware and software (e.g., including firmware), including one or more signal processing and/or application specific integrated circuits.', 'As an example, a system may include a processing apparatus that may be or include a general purpose processors or application specific chips (e.g., or chipsets), such as ASICs, FPGAs, PLDs, or other appropriate devices.\n \nFIG.', '21\n shows components of a computing system \n2100\n and a networked system \n2110\n.', 'The system \n2100\n includes one or more processors \n2102\n, memory and/or storage components \n2104\n, one or more input and/or output devices \n2106\n and a bus \n2108\n.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components \n2104\n).', 'Such instructions may be read by one or more processors (e.g., the processor(s) \n2102\n) via a communication bus (e.g., the bus \n2108\n), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device \n2106\n).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.', 'According to an embodiment, components may be distributed, such as in the network system \n2110\n.', 'The network system \n2110\n includes components \n2122\n-\n1\n, \n2122\n-\n2\n, \n2122\n-\n3\n, . . .', '2122\n-N.', 'For example, the components \n2122\n-\n1\n may include the processor(s) \n2102\n while the component(s) \n2122\n-\n3\n may include memory accessible by the processor(s) \n2102\n.', 'Further, the component(s) \n2122\n-\n2\n may include an I/O device for display and optionally interaction with a method.', 'The network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.', 'As an example, a device may be a mobile device that includes one or more network interfaces for communication of information.', 'For example, a mobile device may include a wireless network interface (e.g., operable via IEEE 802.11, ETSI GSM, BLUETOOTH, satellite, etc.).', 'As an example, a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM slot, audio/video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery.', 'As an example, a mobile device may be configured as a cell phone, a tablet, etc.', 'As an example, a method may be implemented (e.g., wholly or in part) using a mobile device.', 'As an example, a system may include one or more mobile devices.', 'As an example, a system may be a distributed environment, for example, a so-called “cloud” environment where various devices, components, etc. interact for purposes of data storage, communications, computing, etc.', 'As an example, a device or a system may include one or more components for communication of information via one or more of the Internet (e.g., where communication occurs via one or more Internet protocols), a cellular network, a satellite network, etc.', 'As an example, a method may be implemented in a distributed environment (e.g., wholly or in part as a cloud-based service).', 'As an example, information may be input from a display (e.g., consider a touchscreen), output to a display or both.', 'As an example, information may be output to a projector, a laser device, a printer, etc. such that the information may be viewed.', 'As an example, information may be output stereographically or holographically.', 'As to a printer, consider a 2D or a 3D printer.', 'As an example, a 3D printer may include one or more substances that can be output to construct a 3D object.', 'For example, data may be provided to a 3D printer to construct a 3D representation of a subterranean formation.', 'As an example, layers may be constructed in 3D (e.g., horizons, etc.), geobodies constructed in 3D, etc.', 'As an example, holes, fractures, etc., may be constructed in 3D (e.g., as positive structures, as negative structures, etc.).', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words “means for” together with an associated function.', 'Example Computer Program Listing\n \nBelow, an example of a computer program listing is presented with various examples of parameters, attributes, instructions, etc., where the number of lines is more than 60 lines and less than 300 lines.', '“toOneRelationship”:{\n \n \n \n \n“$id”:“definitiens/toOneRelationship”,\n \n \n \n \n“description”:“Arelationshipfromthisentitytoone\n \n \n \n \notherentityeitherbynaturalkey(name)orid,\n \n \n \n \noptionallyclassifiedbyconfidencelevel”,\n \n \n \n \n“properties”:{\n \n \n \n \n“id”:{\n \n \n \n \n“description”:“Theidoftherelatedobject”,\n \n \n \n \n“example”:“slb:petrel:seismic_survey_845934c40e8d922\n \n \n \n \nbc57b678990d55722”,\n \n \n \n \n“format”:“link”,\n \n \n \n \n“title”:“RelatedObjectId”,\n \n \n \n \n“type”:“string”\n \n \n \n \n},\n \n \n \n \n“name”:{\n \n \n \n \n“description”:“Thenameornaturalkeyoftherelatedobject”,\n \n \n \n \n“example”:“SurveyST2016”,\n \n \n \n \n“title”:“RelatedObjectName”,\n \n \n \n \n“type”:“string”\n \n \n \n \n},\n \n \n \n \n“confidence”:{\n \n \n \n \n“description”:“Theconfidenceoftherelationship”,\n \n \n \n \n“example”:1.0,\n \n \n \n \n“title”:“RelationshipConfidence”,\n \n \n \n \n“type”:“number”\n \n \n \n \n}\n \n \n \n \n},\n \n \n \n \n“title”:“ToOneReiationship”,\n \n \n \n \n“type”:“object”\n \n \n \n \n},\n \n \n \n \n{\n \n \n \n \n“toManyRelationship”:{\n \n \n \n \n“$id”:“definitions/toManyRelationship”,\n \n \n \n \n“description”:“Arelationshipfromthisentityto\n \n \n \n \nmanyotherentitieseitherbynaturalkey(name)orexplicitid,\n \n \n \n \noptionallyclassifiedbyconfidencelevel.”,\n \n \n \n \n“properties”:{\n \n \n \n \n“ids”:{\n \n \n \n \n“description”:“Theidsoftherelatedobjects.\n \n \n \n \nItispopulatedforanexplicitrelationshipwherethetargetentity\n \n \n \n \nispresentasarecordinthedataecosystem.\n \n \n \n \nKeepallthearraysorderedandaligned.”,\n \n \n \n \n“format”:“link”,\n \n \n \n \n“title”:“RelatedObjectId”,\n \n \n \n \n“items”:{\n \n \n \n \n“type”:“string”\n \n \n \n \n},\n \n \n \n \n“type”:“array”\n \n \n \n \n},\n \n \n \n \n“names”:{\n \n \n \n \n“description”:“Thenamesornaturalkeysoftherelatedobjects.\n \n \n \n \nKeepallthearraysorderedandaligned.”,\n \n \n \n \n“title”:“RelatedObjectNames”,\n \n \n \n \n“items”:{\n \n \n \n \n“type”:“string”\n \n \n \n \n},\n \n \n \n \n“type”:“array”\n \n \n \n \n},\n \n \n \n \n“confidences”:{\n \n \n \n \n“description”:“Theconfidencesoftherelationships.\n \n \n \n \nKeepallthearraysorderedandaligned.”,\n \n \n \n \n“title”:“RelationshipConfidences”,\n \n \n \n \n“items”:{\n \n \n \n \n“type”:“number”\n \n \n \n \n},\n \n \n \n \n“type”:“array”\n \n \n \n \n}\n \n \n \n \n}\n \n \n \n \n}\n \n \n \n \n}\n \n \n \n \n \n \n \n \n \n \nExample\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n\u2003\n \n“data”:{\n \n \n \n \n \n\u2003“relationships”:{\n \n \n \n \n \n\u2003\u2003“wellbores”:{\n \n \n \n \n \n\u2003\u2003“ids”:[\n \n \n \n \n \n\u2003\u2003\u2003“slb:prosource:wellbore-0f1a5219-4640-50af-9f63-\n \n \n \n \n \n\u2003\u2003\u2003c09140d57c4d”,\n \n \n \n \n \n\u2003\u2003\u2003“slb:prosource:wellbore-5c57b3cc-69a6-5f30-afcb-\n \n \n \n \n \n\u2003\u2003\u20037f0d12e60c77”\n \n \n \n \n \n\u2003\u2003],\n \n \n \n \n \n\u2003\u2003“names”:[\n \n \n \n \n \n\u2003\u2003\u2003“58-1”,\n \n \n \n \n \n\u2003\u2003\u2003“17-2”\n \n \n \n \n \n“confidences”:[50,50]\n \n \n \n \n \n\u2003\u2003}\n \n \n \n \n \n\u2003}\n \n \n \n \n \n}']

['1.', 'A method comprising:\naccessing data generated during field operations using a computational framework, wherein the data comprise structured data within database structures and unstructured data within digitally stored documents, and wherein the data comprise entity data for entities and field data from measurements;\napplying deterministic rules to the data using the computational framework, wherein meeting a condition of one of the deterministic rules establishes a deterministic relationship for a portion of the data and associates a confidence score to the deterministic relationship;\ndiscovering probabilistic relationships for the data using the computational framework, wherein the probabilistic relationships comprise descriptions generated through natural language processing of the structured data that describe relationships within the structured data and comprise descriptions generated through fact extraction from the unstructured data that describe relationships between extracted facts and portions of the structured data;\ngenerating a data structure representable as a graph that comprises vertices and edges using at least the portion of the data, wherein each of the vertices represents one of the entities or one of the measurements, wherein the edges represent the relationships between the vertices, wherein one or more of the vertices positioned at a center of the graph are representative of one or more geological formations, and wherein the edges disposed radially from the center of the graph and connecting corresponding vertices are representative of different geological formations, wellheads, wellbores, well completions, formation tops, reports, and fluid volumes at different hierarchy levels; and\ngenerating a query result using the data structure responsive to receipt of a query, wherein the query result depends at least in part on one or more of the descriptions that describe the relationships between the vertices.', '2.', 'The method of claim 1 wherein the field operations comprise drilling operations and logging operations.', '3.', 'The method of claim 1 wherein the vertices comprise well-related vertices.', '4.', 'The method of claim 3 wherein the relationships comprise well equipment-based relationships.', '5.', 'The method of claim 3 wherein the relationships comprise well production-based relationships.', '6.', 'The method of claim 3 wherein the relationships comprise formation-based relationships.\n\n\n\n\n\n\n7.', 'The method of claim 3 wherein the relationships comprise well log-based relationships.\n\n\n\n\n\n\n8.', 'The method of claim 1 comprising generating a corpus based at least in part on labels of the vertices and natural language of the relationships.\n\n\n\n\n\n\n9.', 'The method of claim 8 comprising guiding formulation of a query using the corpus.', '10.', 'The method of claim 1 comprising rendering the graph to a display.', '11.', 'The method of claim 1 comprising receiving the query from a controller operatively coupled to field equipment.\n\n\n\n\n\n\n12.', 'The method of claim 11 comprising translating the query from the controller to a natural language form.', '13.', 'The method of claim 11 comprising translating the query result from a natural language form to a code and transmitting the code to the controller.', '14.', 'The method of claim 13 comprising receiving a signal responsive to actuation of a graphic control of a graphical user interface wherein the signal triggers transmitting the code to the controller.', '15.', 'The method of claim 1 wherein the probabilistic relationships comprise probabilistically defined relationships between sensor data the field data and the entity data, wherein the field data comprise sensor data and wherein the entity data comprise well identification data.', '16.', 'A system comprising:\na processor;\nmemory accessible to the processor;\nprocessor-executable instructions stored in the memory and executable by the processor to instruct the system to: access data generated during field operations, wherein the data comprise structured data within database structures and unstructured data within digitally stored documents, and wherein the data comprise entity data for entities and field data from measurements; apply deterministic rules to the data, wherein meeting a condition of one of the deterministic rules establishes a deterministic relationship for a portion of the data and associates a confidence score to the deterministic relationship; discover probabilistic relationships for the data using the system, wherein the probabilistic relationships comprise descriptions generated through natural language processing of the structured data that describe relationships within the structured data and comprise descriptions generated through fact extraction from the unstructured data that describe relationships between extracted facts and portions of the structured data; generate a data structure representable as a graph that comprises vertices and edges using at least a portion of the data, wherein each of the vertices represents one of the entities or one of the measurements, wherein the edges represent the relationships between the vertices, wherein one or more of the vertices positioned at a center of the graph are representative of one or more geological formations, and wherein the edges disposed radially from the center of the graph and connecting corresponding vertices are representative of different geological formations, wellheads, wellbores, well completions, formation tops, reports, and fluid volumes at different hierarchy levels; and generate a query result using the data structure responsive to receipt of a query, wherein the query result depends at least in part on one or more of the descriptions that describe the relationships between the vertices.', '17.', 'One or more computer-readable storage media comprising computer-executable instructions executable to instruct a computing system to:\naccess data generated during field operations, wherein the data comprise structured data within database structures and unstructured data within digitally stored documents, and wherein the data comprise entity data for entities and field data from measurements;\napply deterministic rules to the data, wherein meeting a condition of one of the deterministic rules establishes a deterministic relationship for a portion of the data and associates a confidence score to the deterministic relationship;\ndiscover probabilistic relationships for the data using the computing system, wherein the probabilistic relationships comprise descriptions generated through natural language processing of the structured data that describe relationships within the structured data and comprise descriptions generated through fact extraction from the unstructured data that describe relationships between extracted facts and portions of the structured data;\ngenerate a data structure representable as a graph that comprises vertices and edges using at least a portion of the data, wherein each of the vertices represents one of the entities or one of the measurements, wherein the edges represent the relationships between the vertices, wherein one or more of the vertices positioned at a center of the graph are representative of one or more geological formations, and wherein the edges disposed radially from the center of the graph and connecting corresponding vertices are representative of different geological formations, wellheads, wellbores, well completions, formation tops, reports, and fluid volumes at different hierarchy levels; and\ngenerate a query result using the data structure responsive to receipt of a query, wherein the query result depends at least in part on one or more of the descriptions that describe the relationships between the vertices.', '18.', 'The method of claim 1, wherein the entities comprise one or more of formation entities, wellbore entities and completion entities.', '19.', 'The method of claim 1, wherein the measurements comprise one or more of oil measurements, water measurements, gas measurements and downhole log measurements.', '20.', 'The method of claim 1, wherein the entities comprise wellbores and formations and wherein the measurements comprise fluid production measurements from one or more of the formations as produced via one or more of the wellbores.']

['FIG. 1 illustrates examples of equipment in a geologic environment;; FIG.', '2 illustrates an example of a system and examples of types of holes;; FIG.', '3 illustrates an example of a system;; FIG.', '4 illustrates an example of a system;; FIG.', '5 illustrates an example of a system;; FIG.', '6 illustrates an example of a graphical user interface;; FIG.', '7 illustrates an example of a graphical user interface;; FIG. 8 illustrates an example of a system;; FIG. 9 illustrates an example of a method;; FIG.', '10 illustrates an example of a graphical user interface;; FIG.', '11 illustrates an example of a graphical user interface;; FIG.', '12 illustrates an example of a graphical user interface;; FIG.', '13 illustrates an example of a system;; FIG.', '14 illustrates an example of a framework;; FIG.', '15 illustrates an example of a graphical user interface;; FIG.', '16 illustrates an example of a graphical user interface;; FIG.', '17 illustrates an example of a graphical user interface;; FIG.', '18 illustrates an example of a graphical user interface;; FIG.', '19 illustrates an example of a graphical user interface;; FIG.', '20 illustrates examples of computing and networking equipment; and; FIG.', '21 illustrates example components of a system and a networked system.; FIG.', '1 shows an example of a geologic environment 120.', 'In FIG.', '1, the geologic environment 120 may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir 121 and that may be, for example, intersected by a fault 123 (e.g., or faults).', 'As an example, the geologic environment 120 may be outfitted with a variety of sensors, detectors, actuators, etc.', 'For example, equipment 122 may include communication circuitry to receive and/or to transmit information with respect to one or more networks 125.', 'Such information may include information associated with downhole equipment 124, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment 126 may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more pieces of equipment may provide for measurement, collection, communication, storage, analysis, etc. of data (e.g., for one or more produced resources, etc.).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, geolocation, etc.', 'For example, FIG. 1 shows a satellite in communication with the network 125 that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', '; FIG. 1 also shows the geologic environment 120 as optionally including equipment 127 and 128 associated with a well that includes a substantially horizontal portion that may intersect with one or more fractures 129.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 127 and/or 128 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, injection, production, etc.', 'As an example, the equipment 127 and/or 128 may provide for measurement, collection, communication, storage, analysis, etc. of data such as, for example, production data (e.g., for one or more produced resources).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.; FIG. 1 also shows an example of equipment 170 and an example of equipment 180.', 'Such equipment, which may be systems of components, may be suitable for use in the geologic environment 120.', 'While the equipment 170 and 180 are illustrated as land-based, various components may be suitable for use in an offshore system.', 'As shown in FIG.', '1, the equipment 180 can be mobile as carried by a vehicle; noting that the equipment 170 can be assembled, disassembled, transported and re-assembled, etc.; FIG.', '2 shows an example of a wellsite system 200 (e.g., at a wellsite that may be onshore or offshore).', 'As shown, the wellsite system 200 can include a mud tank 201 for holding mud and other material (e.g., where mud can be a drilling fluid), a suction line 203 that serves as an inlet to a mud pump 204 for pumping mud from the mud tank 201 such that mud flows to a vibrating hose 206, a drawworks 207 for winching drill line or drill lines 212, a standpipe 208 that receives mud from the vibrating hose 206, a kelly hose 209 that receives mud from the standpipe 208, a gooseneck or goosenecks 210, a traveling block 211, a crown block 213 for carrying the traveling block 211 via the drill line or drill lines 212 (see, e.g., the crown block 173 of FIG. 1), a derrick 214 (see, e.g., the derrick 172 of FIG. 1), a kelly 218 or a top drive 240, a kelly drive bushing 219, a rotary table 220, a drill floor 221, a bell nipple 222, one or more blowout preventors (BOPs) 223, a drillstring 225, a drill bit 226, a casing head 227 and a flow pipe 228 that carries mud and other material to, for example, the mud tank 201.; FIG.', '2 also shows some examples of types of holes that may be drilled.', 'For example, consider a slant hole 272, an S-shaped hole 274, a deep inclined hole 276 and a horizontal hole 278.; FIG.', '3 shows an example of a system 300 that includes a drilling workflow framework 301, a seismic-to-simulation framework 302, a drilling framework 304, a client layer 310, an applications layer 340 and a storage layer 360.', 'As shown the client layer 310 can be in communication with the applications layer 340 and the applications layer 340 can be in communication with the storage layer 360.; FIG.', '4 shows an example of a wellsite system 400, specifically, FIG.', '4 shows the wellsite system 400 in an approximate side view and an approximate plan view along with a block diagram of a system 470.; FIG.', '4 also shows a battery 480 that may be operatively coupled to the system 470, for example, to power the system 470.', 'As an example, the battery 480 may be a back-up battery that operates when another power supply is unavailable for powering the system 470.', 'As an example, the battery 480 may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery 480 can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.; FIG.', '5 shows an example of an environment 501 that includes a subterranean portion 503 where a rig 510 is positioned at a surface location above a bore 520.', 'In the example of FIG.', '5, various wirelines services equipment can be operated to perform one or more wirelines services including, for example, acquisition of data from one or more positions within the bore 520.; FIG. 5 also shows a battery 570 that may be operatively coupled to the system 560, for example, to power the system 560.', 'As an example, the battery 570 may be a back-up battery that operates when another power supply is unavailable for powering the system 560 (e.g., via a generator of the wirelines truck 550, a separate generator, a power line, etc.).', 'As an example, the battery 570 may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery 570 can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.; FIG.', '6 shows an example of a graphical user interface (GUI) 600 that includes information associated with a well plan.', 'Specifically, the GUI 600 includes a panel 610 where surfaces representations 612 and 614 are rendered along with well trajectories where a location 616 can represent a position of a drillstring 617 along a well trajectory.', 'The GUI 600 may include one or more editing features such as an edit well plan set of features 630.', 'The GUI 600 may include information as to individuals of a team 640 that are involved, have been involved and/or are to be involved with one or more operations.', 'The GUI 600 may include information as to one or more activities 650.', 'As shown in the example of FIG.', '6, the GUI 600 can include a graphical control of a drillstring 660 where, for example, various portions of the drillstring 660 may be selected to expose one or more associated parameters (e.g., type of equipment, equipment specifications, operational history, etc.).', 'FIG.', '6 also shows a table 670 as a point spreadsheet that specifies information for a plurality of wells.', 'For example, the point spreadsheet can include coordinates, dimensions, etc., that specify a trajectory of a well, spacing of wells, etc.; FIG.', '7 shows an example of a GUI 700 that includes various features that can be part of a workspace.', 'For example, a computational framework area 710 includes icons that represent various types of computational frameworks such as a drilling plan framework, a seismic-to-simulation framework (e.g., PETREL framework, Schlumberger Limited, Houston, Texas), a measurements framework (e.g., TECHLOG framework, Schlumberger Limited, Houston, Texas), a mechanical earth modeling (MEM) framework (PETROMOD framework, Schlumberger Limited, Houston, Texas), an exploration risk, resource, and value assessment framework (e.g., GEOX, Schlumberger Limited, Houston, Texas), and a reservoir simulation framework (INTERSECT, Schlumberger Limited, Houston, Texas).', 'As an example, one or more computational frameworks may be suitable for use in a system such as the system 300 of FIG.', '3, the wellsite system 400 of FIG. 4, the system 500 of FIG. 5, etc.; FIG.', '8 shows an example of a system 800 that includes a workspace framework 810, an interface 820 and a graph framework 840.', 'As shown, the graph framework 840 can be operatively coupled to the workspace framework 810 via the interface.', 'As an example, a user may utilize the GUI 700 of FIG.', '7 to cause the system 800 of FIG.', '8 to generate and/or utilize a graph.; FIG.', '9 shows an example of a method 900 that includes an access block 910 for accessing data generated during field operations; a generation block 920 for generating a graph that includes vertices and edges using at least a portion of the data, where the edges represent relationships between vertices; and a generation block 930 for generating a query result using the graph responsive to receipt of a query.; FIG.', '10 shows an example of a graphical user interface (GUI) 1000 that includes data according to a data catalog service as mapping “WKA” for “Wellbore” entity to various “Raw” sources; noting that some sources include more or less attributes.', 'In the example GUI 1000, consider “Well Name” (see also, e.g., “WellName”, “Well_Name”, etc.).', '; FIG.', '11 shows an example of a graphical user interface (GUI) 1100 that includes various panels, including a file panel and linking component panels.', 'The GUI 1100 may be utilized as part of an ingestion and linking workflow.', 'As to the file panel (left side), it can render data from the ingested file, which, as mentioned, can be in a format that is associated with a particular computational framework (e.g., PIPESIM, PETREL, etc.).', 'As an example, data may be organized with a well heading, a curve heading and a parameter heading.', 'In such an example, the file can be parsed or organized with well data, log (e.g., curve) data, and measurement values (e.g., parameter values).', '; FIG.', '12 shows an example of a graphical user interface (GUI) 1200 as in FIG.', '11 where various relationships are indicated.', 'Specifically, a well name is shown as existing within a portion of the ingested file.; FIG.', '13 shows an example of a system 1300 that includes a data insight system 1340 and a fact extraction system 1360.', 'As shown, the system 1300 can detect and/or predict and output a relationship 1380, which is shown in the context of a document and an extracted fact.', '; FIG.', '14 shows an example of a framework 1400, which can include one or more features of the GRAPHDB framework.', 'As shown, the framework can include a workbench component, an engine and connectors.', 'The engine can include a query optimizer, a reasonser, storage and a plugin manager.', 'The storage can include an entity pool, statements indexes, a literal index and optional context indexes.', 'The plugin manager may provide for access to various plugins, optionally via one or more of the connectors.', 'For example, consider a geo-spatial plugin, a LUCENE plugin, a RDF Rank plugin, etc.', 'As to connectors, consider a LUCENE connector, a SOLR connector for APACHESOLR, and an elasticsearch (ES) connector for ELASTICSEARCH.; FIG.', '15 shows an example of a graphical user interface (GUI) 1500 in a table form where probabilistic relationships can be discovered through natural language processing of structured data that exists in a multi-framework system such as the system 800 of FIG.', '8.; FIG.', '16 shows an example of a graphical user interface (GUI) 1600 in a graphical form.', 'The graphical form includes various types of relationships as may be determined using one or more of explicit, implicity and deep technologies.', 'Such a graphic form can be extremely complex as to its relationship, which can be both deterministically and probabilistically generated.', '; FIG.', '17 shows an example of a graphical user interface (GUI) 1700 in a graphical form of a technical problem with a technical solution.', 'As shown, a user can readily find well logs in the context of one or more workflows.', 'In the example of FIG.', '17, various types of subsurface data can be understood in relationship to various types of production data.', 'For example, consider a well “A10” being in a graph or graph database such that various types of relationships can be determined and assigned where the well A10 can be represented as a vertex (e.g., a node) with various relationships (e.g., edges).', 'In such an example, deterministic and/or probabilistic techniques can be utilized to establish the relationships.', 'As an example, a corpus of terminology and contextual information may be generated by a relationship mining process such that the formulation of various queries may be guided by such a corpus.', 'As an example, a query can be submitted via a graphical user interface (e.g., a search field or search fields) and/or can be submitted automatically (e.g., by a piece of equipment).', 'As to the latter, consider a piece of equipment that includes or is operatively coupled to a sensor or sensors.', 'In such an example, sensor data may indicate that a limit may be reached (e.g., an alarm limit, etc.)', 'such that a notification and/or a control action is to be taken.', 'A trigger can cause issuance of a query, optionally including one or more measurement values, equipment type, etc., where a query results may be communicated to a computing device for rendering to a display or other action.', '; FIG.', '18 shows an example of a GUI 1800 that can be part of a process that involves searching to uncover relationships, data, etc.', 'For example, consider a natural language search such as “show me actual aggregate oil, gas, and water production volumes for completions that were active in 20XX”.', 'In such an example, output may be generated and rendered via a GUI such as the GUI 1800.', 'In the example of FIG.', '18, a field includes the following: “$ MATCH (w:wellBore)-[r:Has_Complet.]-(c:complet.)-[:Has_Prod._Vol.]-(v) where r.startDate>‘12/31/20XY’ AND rendDate>=‘1/1/20XX’ RETURN v.name, sum(v.volume)”.', 'Such information may be generated in response to a natural language query.', 'As shown, an oil volume actual field includes a sum of 1000, a water volume actual field includes a sum of 1800 and a gas volume actual field includes a sum of 1400.', 'The information rendered is responsive to the query and quantitative.', 'For example, computations may be performed on data accessed responsive to the query to provide for the sums shown in the GUI 1800 of FIG.', '18.', 'In FIG.', '18, the results of the query are shown in row form, noting that one or more other forms may be utilized for presentation of results (e.g., and/or intermediate results such as individual amounts of oil, water and gas from individual wells, regions, etc.).', '; FIG.', '19 shows an example of a GUI 1900 that pertains to a natural language query: “Show me daily drilling reports for wellbores that cross the Bakken formation where porosity is <0.2”.', 'The example output is rendered in a graphical form.', 'For example, responsive to receipt of the natural language query a framework can logically uncover documents that are daily drilling reports with information germane to the query.', 'In such an example, the one or more graphics can be graphical controls that can be actuated to, for example, access details of a report, render one or more additional vertices, exposed and/or render one or more edges, etc.; FIG.', '21 shows components of a computing system 2100 and a networked system 2110.', 'The system 2100 includes one or more processors 2102, memory and/or storage components 2104, one or more input and/or output devices 2106 and a bus 2108.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components 2104).', 'Such instructions may be read by one or more processors (e.g., the processor(s) 2102) via a communication bus (e.g., the bus 2108), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device 2106).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.']

US11920438

Intelligent power management system

Oct 17, 2019

Mateo Garcia, Shunfeng Zheng, Seetharam Kothuru

SCHLUMBERGER TECHNOLOGY CORPORATION

Search Report and Written Opinion of counterpart International Patent Application No. PCT/2020/070654, dated Jan. 29, 2021, 11 pages.; International Preliminary Report on Patentability of counterpart International Patent Application No. PCT/2020/070654, dated Apr. 28, 2022, 8 pages.

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106598720; April 2017; CN; 2018213925; November 2018; WO; WO 2019/051439; March 2019; WO

['A method may include obtaining, from a digital drilling program and by a drilling management network, a drilling operation sequence of the drilling rig.', 'The drilling management network is coupled to a drilling rig, rig equipment, and various electric power generators.', 'The method may further include determining, by the drilling management network, a power management sequence that matches an electric power capacity of the drilling rig to an electric power consumption of the rig equipment.', 'The method may further include executing, by the drilling management network, the power management sequence to the rig equipment and the electric power generators.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nVarious network devices, electric power generators and motors may be disposed throughout a drilling rig in order to control various operations on the drilling rig.', 'These network devices may control drilling equipment, monitor the performance of the drilling rig, and/or perform various maintenance operations with respect to the drilling rig.', 'In particular, these network devices may include sensors that collect sensor measurements, system requirement, and fuel requirement around the drilling rig.', 'Accordingly, various problems exist in regard to effective utilization of power management system based on sensor data between different network devices and electric power generators on the drilling rig.', 'SUMMARY\n \nIn general, in one aspect, embodiments relate to a method that includes obtaining, from a digital drilling program and by a drilling management network, a drilling operation sequence of the drilling rig.', 'The drilling management network is coupled to a drilling rig, rig equipment, and various electric power generators.', 'The method includes determining, by the drilling management network, a power management sequence that matches an electric power capacity of the drilling rig to an electric power consumption of the rig equipment.', 'The method further includes executing, by the drilling management network, the power management sequence to the rig equipment and the electric power generators.', 'In general, in one aspect, embodiments relate to a system that includes a sensor device.', 'The system includes various electric power generators and rig equipment.', 'The system further includes a drilling management network coupled to the sensor device, the electric power generators, rig equipment, and a drilling rig, the drilling management network comprising various network elements.', 'and a power manager coupled to the drilling management network.', 'The power manager includes a computer processor and includes functionality for obtaining a drilling operation sequence of the drilling rig from a digital drilling program.', 'The power manager includes functionality for determining a power management sequence that matches an electric power capacity of the drilling rig to an electric power consumption of the rig equipment.', 'The power manager further includes functionality for executing the power management sequence to the rig equipment and the electric power generators.', 'In general, in one aspect, embodiments relate to a non-transitory computer readable medium storing instructions executable by a computer processor.', 'The instructions include functionality for obtaining, over a drilling management network, a drilling operation sequence from a digital drilling program.', 'The drilling management network is coupled to a drilling rig, rig equipment, and various electric power generators.', 'The instructions include functionality for determining a power management sequence that matches an electric power capacity of the drilling rig to an electric power consumption of the rig equipment.', 'The instructions further include functionality for executing, over the drilling management network, the power management sequence to the rig equipment and the electric power generators.', 'Other aspects of the disclosure will be apparent from the following description and the appended claims.', 'BRIEF DESCRIPTION OF DRAWINGS\n \nFIGS.', '1\n, \n2\n and \n3\n show systems in accordance with one or more embodiments.', 'FIG.', '4\n shows a flowchart in accordance with one or more embodiments.\n \nFIG.', '5\n shows an example in accordance with one or more embodiments.', 'FIGS.', '6\n.', '1\n and \n6\n.', '2\n show a computing system in accordance with one or more embodiments.', 'DETAILED DESCRIPTION\n \nSpecific embodiments of the disclosure will now be described in detail with reference to the accompanying figures.', 'Like elements in the various figures are denoted by like reference numerals for consistency.', 'In the following detailed description of embodiments of the disclosure, numerous specific details are set forth in order to provide a more thorough understanding of the disclosure.', 'However, it will be apparent to one of ordinary skill in the art that the disclosure may be practiced without these specific details.', 'In other instances, well-known features have not been described in detail to avoid unnecessarily complicating the description.', 'Throughout the application, ordinal numbers (e.g., first, second, third, etc.) may be used as an adjective for an element (i.e., any noun in the application).', 'The use of ordinal numbers is not to imply or create any particular ordering of the elements nor to limit any element to being only a single element unless expressly disclosed, such as by the use of the terms “before”, “after”, “single”, and other such terminology.', 'Rather, the use of ordinal numbers is to distinguish between the elements.', 'By way of an example, a first element is distinct from a second element, and the first element may encompass more than one element and succeed (or precede) the second element in an ordering of elements.', 'In general, embodiments of the disclosure include a system and various methods for managing electric power consumption throughout a drilling rig and/or drilling management network.', 'Specifically the system may implement an automated process for managing transient power spike(s) and loads by turning on and off electric power generators.', 'This automated process may be orchestrated by a power manager, for example.', 'As such, a power manager may change the number of online electric power generators/motors based on the future power consumption requirements of the drilling rig.', 'Accordingly, the power manager may regulate the automated startup process of various electric power generators, electric motors, and/or drilling operations through the drilling management network using commands.', 'Thus, a drilling management network may execute a power management sequence with rig equipment and electric power generators according to various drilling operations described within a digital drilling program.', 'In particular, the power manager may estimate a projected power consumption of the drilling rig using current power consumption, transient loads, various equipment operation states.', 'For example, the power management may adjust a power management sequence in real time.', 'Where sudden transient loads result from changes in rig equipment or electric generators, the power management may address these changes by automatically changing electric power capacity of a drilling rig.', 'Thus, the power manager may efficiently manage the start and stop times of rig equipment to reduce transient loads for optimized drilling operation and manage device timings within a drilling rig to match power supply (such as to prevent blackouts or reduce electromagnetic or pressure pulse noise during various operations).', 'Further, the power manager may determine the future power consumption requirements through a digital drilling program.\n \nFIG.', '1\n shows a block diagram of a system in accordance with one or more embodiments. \nFIG.', '1\n shows a drilling system (\n10\n) according to one or more embodiments.', 'Drill string (\n58\n) is shown within borehole (\n46\n).', 'Borehole (\n46\n) may be located in the earth (\n40\n) having a surface (\n42\n).', 'Borehole (\n46\n) is shown being cut by the action of drill bit (\n54\n).', 'Drill bit (\n54\n) may be disposed at the far end of the bottom hole assembly (\n56\n) that is attached to and forms the lower portion of drill string (\n58\n).', 'Bottom hole assembly (\n56\n) may include a number of devices including various subassemblies.', 'Measurement-while-drilling (MWD) subassemblies may be included in subassemblies (\n62\n).', 'Examples of MWD measurements may include direction, inclination, survey data, downhole pressure (inside the drill pipe, and/or outside and/or annular pressure), resistivity, density, and porosity.', 'Subassemblies (\n62\n) may also include a subassembly for measuring torque and weight on the drill bit (\n54\n).', 'The signals from the subassemblies (\n62\n) may be processed in a processor (\n66\n).', 'After processing, the information from processor (\n66\n) may be communicated to pulser assembly (\n64\n).', 'Pulser assembly (\n64\n) may convert the information from the processor (\n66\n) into pressure pulses in the drilling fluid.', 'The pressure pulses may be generated in a particular pattern which represents the data from the subassemblies (\n62\n).', 'The pressure pulses may travel upwards through the drilling fluid in the central opening in the drill string and towards the surface system.', 'The subassemblies in the bottom hole assembly (\n56\n) may further include a turbine or motor for providing power for rotating and steering drill bit (\n54\n).', 'Alternatively, the signals from subassembly \n62\n may be transmitted to the surface via other telemetry means, such as EM telemetry, or wired drillpipe, etc.', 'The drilling rig (\n12\n) may include a derrick (\n68\n) and hoisting system, a rotating system, and/or a mud circulation system, for example.', 'The hoisting system may suspend the drill string (\n58\n) and may include draw works (\n70\n), fast line (\n71\n), crown block (\n75\n), drilling line (\n79\n), traveling block and hook (\n72\n), swivel (\n74\n), and/or deadline (\n77\n).', 'The rotating system may include a kelly (\n76\n), a rotary table (\n88\n), and/or engines (not shown).', 'The rotating system may impart a rotational force on the drill string (\n58\n).', 'Likewise, the embodiments shown in \nFIG.', '1\n may be applicable to top drive drilling arrangements as well.', 'Although the drilling system (\n10\n) is shown being on land, those of skill in the art will recognize that the described embodiments are equally applicable to marine environments as well.', 'The mud circulation system may pump drilling fluid down an opening in the drill string.', 'The drilling fluid may be called mud, which may be a mixture of water and/or diesel fuel, special clays, and/or other chemicals.', 'The mud may be stored in mud pit (\n78\n).', 'The mud may be drawn into mud pumps (not shown), which may pump the mud though standpipe (\n86\n) and into the kelly (\n76\n) through swivel (\n74\n), which may include a rotating seal.', 'Likewise, the described technologies may also be applicable to underbalanced drilling.', 'If underbalanced drilling is used, at some point prior to entering the drill string, gas may be introduced into the mud using an injection system (not shown).', 'The mud may pass through drill string (\n58\n) and through drill bit (\n54\n).', 'As the cutting elements of the drill bit (\n54\n) grind and gouge the earth formation into cuttings, the mud may be ejected out of openings or nozzles in the drill bit (\n54\n).', 'These jets of mud may lift the cuttings off the bottom of the hole and away from the drill bit (\n54\n), and up towards the surface in the annular space between drill string (\n58\n) and the wall of borehole (\n46\n).', 'At the surface, the mud and cuttings may leave the well through a side outlet at bellnipper (not shown) above blowout preventer (\n99\n) and through mud return line (not shown).', 'Blowout preventer (\n99\n) comprises a pressure control device and associated seal.', 'The mud return line may feed the mud into one or more separator (not shown) which may separate the mud from the cuttings.', 'From the separator, the mud may be returned to mud pit (\n78\n) for storage and re-use.', 'Various sensor devices may be placed on the drilling rig (\n12\n) to take measurements of the rig equipment.', 'In particular, a hookload may be measured by hookload sensor (\n94\n) mounted on deadline (\n77\n), block position and the related block velocity may be measured by a block sensor (\n95\n) which may be part of the draw works (\n70\n).', 'Surface torque may be measured by a sensor device on the rotary table (\n88\n).', 'In another embodiment, surface torque may be measured through instrumentation on or below the top drive, or through measuring top drive current.', 'Standpipe pressure may be measured by pressure sensor (\n92\n), located on standpipe (\n86\n).', 'Signals from these measurements may be communicated to a surface processor (\n96\n) or other network elements (not shown) disposed around the drilling rig (\n12\n).', 'In addition, mud pulses traveling up the drill string may be detected by pressure sensor (\n92\n).', 'For example, pressure sensor (\n92\n) may include a transducer that converts the mud pressure into electronic signals.', 'The pressure sensor (\n92\n) may be connected to surface processor (\n96\n) that converts the signal from the pressure signal into digital form, stores and demodulates the digital signal into useable MWD data.', 'According to various embodiments described above, surface processor (\n96\n) may be programmed to automatically detect one or more rig states based on the various input channels described.', 'Surface processor (\n96\n) may be programmed, for example, to carry out an automated event detection as described above.', 'Surface processor (\n96\n) may transmit a particular rig state and/or event detection information to user interface system (\n97\n) which may be designed to warn various drilling personnel of events occurring on the rig and/or suggest activity to the drilling personnel to avoid specific events.', 'All of the above described components of a drilling system consume power, and embodiments of the present disclosure relate to a system and method for intelligently managing the power requirements for these and other rig equipment.', 'Turning to \nFIG.', '2\n, \nFIG.', '2\n shows a block diagram of a system in accordance with one or more embodiments.', 'As shown in \nFIG.', '2\n, a drilling management network (\n230\n) may include various sensors (e.g., sensors (\n220\n)), a human machine interface (HMI) (e.g., HMI (\n233\n)), a historian (e.g., historian (\n237\n)), and various network elements (e.g., network elements (\n231\n)).', 'The drilling management network (\n230\n) may further include rig equipment (e.g., rig equipment (\n232\n))', 'such as draw works (\n70\n), top drive, mud pumps and other components described above in \nFIG. \n1\n and the accompanying description).', 'The drilling management network (\n230\n) may further include various drilling operation control systems (e.g., drilling operation control systems (\n235\n)) and various maintenance control systems (e.g., maintenance control systems (\n236\n)).', 'Drilling operation control systems and/or maintenance control systems may include, for example, programmable logic controllers (PLCs) that include hardware and/or software with functionality to control one or more processes performed by the rig equipment (\n232\n), including, but not limited to the components described in \nFIG.', '1\n.', 'Specifically, a programmable logic controller may control valve states, fluid levels, pipe pressures, warning alarms, and/or pressure releases throughout a drilling rig.', 'In particular, a programmable logic controller may be a ruggedized computer system with functionality to withstand vibrations, extreme temperatures, wet conditions, and/or dusty conditions, for example, around a drilling rig.', 'Without loss of generality, the term “control system” may refer to a drilling operation control system that is used to operate and control the rig equipment, a drilling data acquisition and monitoring system that is used to acquire drilling process and equipment data and to monitor the operation of the drilling process, or a drilling interpretation software system that is used to analyze and understand drilling events and progress.', 'In one or more embodiments, a drilling management network may include a digital drilling program (e.g., digital drilling program (\n254\n)) that describes one or more drilling operation sequences (e.g., drilling operation sequence (\n256\n)).', 'For example, a digital drilling program may be a digital description of drilling operations using rig equipment operation for a well construction.', 'The digital description may include an estimated power consumption of rig equipment at different drilling operations.', 'Thus, the digital drilling program may be operated by one or more network devices in the drilling management network (e.g., a human machine interface (\n233\n), a power manager (\n250\n)), etc.).', 'Furthermore, the drilling operations in a digital drilling program may be automated based on various detected conditions around the drilling rig and sensor data.', 'Likewise, the digital drilling program may include various user inputs from a human operator for controlling drilling operations.', 'In some embodiments, a digital drilling program may include operation parameters that may be static or variable during a drilling operation sequence based on changes in drilling operation states around the drilling management network.', 'In some embodiments, a drilling operation sequence may include a predetermined order of scheduled events at a drilling rig or drilling management network to perform one or more drilling operations along with the corresponding operation parameters.', 'For example, a drilling operation sequence may include a mud pump operation, a drill bit operation, reaming of a borehole, etc.', 'Likewise, a drilling operation sequence may correspond to events at different drilling depths of a borehole.', 'In one or more embodiments, the power manager may determine the operation sequence in order to manage the timings of the start and stop of various equipment to reduce transient loads for optimized drilling operation and manage the timings of the start and stop of various equipment to match power supply (such as to prevent blackout).', 'In one or more embodiments, the drilling management network (\n230\n) may include a power manager (e.g., power manager (\n250\n)).', 'For example, the power manager may be a centralized processing device that includes hardware and/or software.', 'The power manager may be coupled to a digital drilling program or be part of the digital drilling program.', 'A power manager may include functionality for determining various equipment operation states, managing the timings of the start and stop of various equipment to manage sudden transient power spike to optimize drilling operation, managing the timings of the start and stop of various equipment to match power supply, and transmitting various generator commands and/or motor commands to coordinate with the generators.', 'Likewise, the power manager (\n250\n) may obtain sensor data from various devices, e.g., sensors (\n220\n) and various control systems on the drilling management network (\n230\n).', 'Moreover, the power manager (\n250\n) may include a computer processor similar to the computer processor (\n602\n) described below in \nFIG. \n6\n.\n1\n and the accompanying description.', 'Moreover, the drilling management network (\n230\n) may include various network elements (e.g., network elements (\n231\n)) and/or various electric motors (e.g., electric motors (\n234\n)).', 'For example, the electric motors (\n234\n) may be a continuous-duty universal motors, brushless DC motors, and/or synchronous single phase AC motors.', 'The drilling management network (\n230\n) may further include a fuel supply (\n240\n) and various electric power generators (e.g., electric power generators (\n238\n)).', 'A fuel supply may include hardware and/or software that includes functionality for monitoring the amount of fuel stored in the fuel supply.', 'In one or more embodiments, the fuel supply is a moveable container that includes functionality for distributing fuel to various devices around a drilling rig and/or drilling management network.', 'An electric power generator may include hardware and/or software for converting fuel into electric energy for operating one or more devices around a drilling rig.', 'For example, an electric power generator may be a diesel engine-generator.', 'Further, the fuel supply (\n240\n) may send fuel to the electric power generators (\n238\n) which transmit electricity to run the electric motors (\n234\n) of the drilling management network (\n230\n).', 'Keeping with \nFIG.', '2\n, sensors may include hardware and/or software that includes functionality to obtain one or more sensor measurements, e.g., a sensor measurement of an environment condition proximate the sensors (\n220\n).', 'The sensors may process the sensor measurements into various types of sensor data.', 'For example, the sensors may include functionality to convert sensor measurements obtained from sensor data into a communication protocol format for the drilling management network (\n230\n).', 'The sensors may include pressure sensors, torque sensors, rotary switches, weight sensors, position sensors, microswitches, etc.', 'The sensors may include smart sensors.', 'In some embodiments, the sensors may include sensor circuitry without a communication interface or memory.', 'For example, the sensors may be coupled with a computer device that transmits sensor data over a drilling management network.', 'In one or more embodiments, sensor data may be sent over the drilling management network (\n230\n) in data packets using a communication protocol.', 'Sensor data may include sensor measurements, processed sensor data based on one or more underlying sensor measurements or parameters, metadata regarding the sensors such as timestamps and sensors identification information, content attributes, sensor configuration information such as offset, conversion factors, etc.', 'As such, the sensors (\n220\n) may act as a network node and/or an endpoint on the drilling management network (\n230\n).', 'In one embodiment, one or more sensors may connect to the drilling management network through a power-over-Ethernet network.', 'In one or more embodiments, the human machine interface (\n233\n) may be hardware and/or software coupled to the drilling management network (\n230\n).', 'For example, the HMI (\n233\n) may allow the operator to interact with the drilling system, e.g., to send a command to operate an equipment, or to view sensor information from rig equipment.', 'The human machine interface may include functionality for presenting data and/or receiving inputs from a user regarding various drilling operations and/or maintenance operations.', 'For example, a human machine interface may include software to provide a graphical user interface (GUI) for presenting data and/or receiving control commands for operating a drilling rig.', 'A network element may refer to various hardware components within a network, such as switches, routers, hubs or any other logical entities for uniting one or more physical devices on the network.', 'In particular, a network element, the human machine interface, and/or the historian may be a computing system similar to the computing system (\n600\n) described in \nFIGS.', '6\n.', '1\n and \n6\n.', '2\n, and the accompanying description.', 'While \nFIGS.', '1\n and \n2\n show various configurations of components, other configurations may be used without departing from the scope of the disclosure.', 'For example, various components in \nFIGS. \n1\n and \n2\n may be combined to create a single component.', 'As another example, the functionality performed by a single component may be performed by two or more components.', 'Turning to \nFIG.', '3\n, \nFIG.', '3\n shows a block diagram of a system in accordance with one or more embodiments.', 'The following example is for explanatory purposes only and not intended to limit the scope of the invention.', 'As shown in \nFIG. \n3\n, a drilling management network (\n330\n) may include various user devices (e.g., user device (\n390\n)), various network elements (e.g., network elements (\n331\n)), various fuel supplies (e.g., fuel supply (\n340\n)), a power manager (e.g., power manager (\n350\n)), a digital drilling program (e.g., digital drilling program (\n354\n)), and various control systems (e.g., control system N (\n312\n) and control systems (\n313\n)).', 'The user devices may include hardware and/or software coupled to the drilling management network (\n330\n), and which includes functionality for presenting data and/or receiving inputs from a user regarding various drilling operations and/or maintenance operations performed within the drilling management network (\n330\n).', 'For example, a user device may include personal computers, smartphones, human machine interfaces, and any other devices coupled to a network that obtain inputs from one or more users, e.g., by providing a graphical user interface (GUI).', 'Likewise, a user device may present data and/or receive control commands from a user for communicating with a digital drilling program for operating a drilling rig.', 'In one or more embodiments, the drilling management network (\n330\n) includes various electric power generators (e.g., electric power generator A (\n311\n)) operating on the fuel supply (\n340\n) and electric motors (e.g., electric motor A (\n314\n).', 'As shown in \nFIG. \n3\n, the electric power generator A (\n311\n) provides electric power (e.g., electric power X (\n360\n)) to the rig equipment N (\n332\n).', 'Accordingly, one or more devices and/or systems on the drilling management network (\n330\n) may transmit data packets, e.g., sensor data or power consumption data, to the user device (\n390\n) and/or receive data packets from the control systems N (\n312\n) regarding the power requirements and consumption.', 'For example, power consumption data (e.g., power consumption data B (\n373\n)) may be sent over the drilling management network (\n330\n) to the power manager (\n350\n) using a communication protocol.', 'Power consumption data may include estimation of a projected power consumption of the drilling rig based on a current power consumption, various equipment operation states and design parameters, number of electric power generators, generator and motor working conditions (on/off, ready or under or needing repair or maintenance, etc.), timing of the start and stop of various equipment to optimize drilling operation and so forth.', 'In some embodiments, the power manager may manage sudden transient loads by transmitting various commands (e.g., electric generator command A (\n372\n) and', 'motor command A (\n371\n)) over the drilling management network to implement the adjusted power management sequence.', 'For example, sudden transient loads may result when an insufficient number of electric power generators and/or electric motors are online, or are running very close to the rated load, which may lead the startup transients to overload the system.', 'In particular, the power manager may transmit the electric generator command A (\n372\n) to the electric power generator based on the power consumption data B (\n373\n).', 'Using the motor command A (\n371\n), for example, the power manager determines whether to enable, disable, or bypass an electric motor to a drilling operation sequence in accordance with one or more embodiments.', 'In one or more embodiments, a power manager may transmit generator commands to various electric power generators to manage usage within a drilling management network.', 'More specifically, the power manager may determine a drilling operation sequence from the digital drilling program in order to match an electric power capacity of a drilling rig to an electric power consumption of the drilling rig.', 'Based on the electric power consumption, the power manager may use generator commands to distribute electric power generation among various generators evenly to avoid hardware malfunctions and/or extend the lifetime of each individual generator.', 'Thus, a power manager may equalize the number of hours that an electric power generator is online.', 'In some embodiments, a power manager performs similar tasks with motors and motor commands in the drilling rig.', 'Likewise, if one electric power generator is overused in contrast to other electric power generators, the overused electric power generator may fail prematurely.', 'Turning to \nFIG.', '4\n, \nFIG.', '4\n shows a flowchart in accordance with one or more embodiments.', 'Specifically, \nFIG.', '4\n describes a general method for executing a power management sequence.', 'One or more blocks in \nFIG.', '4\n may be performed by one or more components (e.g., power manager (\n250\n)) as described in \nFIGS.', '1\n and/or \n2\n.', 'While the various blocks in \nFIG.', '4\n are presented and described sequentially, one of ordinary skill in the art will appreciate that some or all of the blocks may be executed in different orders, may be combined or omitted, and some or all of the blocks may be executed in parallel.', 'Furthermore, the blocks may be performed actively or passively.', 'In Block \n400\n, one or more drilling operation sequences are obtained from a digital drilling program in accordance with one or more embodiments.', 'For example, various well input parameters may be determined for a wellbore.', 'Using the well input parameters, a digital drilling program may be obtained for a sequence of drilling operations to construct the wellbore.', 'For example, a power manager may select a digital drilling program that corresponds to a particular drilling operation sequence from multiple preexisting drilling operation sequences.', 'Likewise, a user may select and/or modify a preexisting drilling operation sequence within a digital drilling program based on the well input parameters.', 'In Block \n410\n, a power management sequence is determined that matches an electric power capacity of a drilling rig to an electric power consumption of rig equipment in accordance with one or more embodiments.', 'For example, a power management sequence may correspond to a predetermined order defining different amounts of electric power for use by equipment.', 'An initial power management sequence may be obtained from a digital drilling program, for example.', 'Likewise, a digital drilling program may specify a particular number of electric generators at different points in time of a drilling operation sequence.', 'Accordingly, a power manager can match the electric capacity of a drilling rig to these different points in time.', 'In one or more embodiments, a power manager may automatically adjust a drilling operation sequence to match electric power capacity of a drilling rig.', 'For example, a power manager may determine the availability of actual power and fuel in the drilling rig, including, for example, the number of electric power generators and their equipment operation status (on/off, ready or under repair, etc.).', 'Thus, the power manager may use information to produce an adjusted drilling operation sequence, e.g., in order to calibrate and/or update the power consumption for future drilling operations.', 'Likewise, the power manager may also determine different power management sequences based on changes and variable operations in a drilling operation sequence.', 'Accordingly, as an electric power consumption increases or decreases at a drilling rig, the power manager may increase or decrease the electric power capacity of the drilling rig to match the electric power consumption.', 'In some embodiments, a power management sequence may be determined using power consumption data and one or more pre-stored algorithms.', 'In one or more embodiments, for example, the power manager of the drilling management network adjusts the drilling operation sequence based on one or more changes in a drilling path performed by the drilling rig to produce an adjusted drilling operation sequence.', 'Further, the power manager determines whether to change the number of electric power generators and adjusts the power management sequence (e.g., by changing operation parameters, order of the drilling operations, etc.).', 'The power manager may then produce an adjusted power management sequence based on an adjusted drilling operation sequence and the updated power consumption within a job package.', 'In other words, the power manager determines adequate power by analyzing the allocation of electric power generators and/or the timing of events in a drilling operation sequence.', 'In one embodiment, the power manager may use the software application to estimate power consumption at different drilling operation sequences in a job package based on design parameters of various equipment.', 'The power manager may obtain the fuel data, e.g., an amount of fuel located in a fuel supply at a drilling rig.', 'The fuel data may be used in conjunction with power consumption data to manage electric power over a drilling management network.', 'In some embodiments, a power manager may obtain power consumption data in order to evaluate a projected electric power consumption of rig equipment.', 'For example, a power manager may calculate a required electric power capacity within a drilling operation sequence.', 'Based on the required electric power capacity, the power manager may compare the projected power consumption with the current power management sequence.', 'For example, power consumption data may include anticipated power demand, electromagnetic and/or pressure pulse noise readings for certain operation, and electric power readings in real time, over a predetermined time interval.', 'Likewise, power consumption data may correspond to various parameter values, such as voltage levels, amounts of current, and quantities of power, e.g., in kilojoules.', 'The power consumption data for various network devices may be aggregated by a power manager in a form of a job package or software application in order to determine historical trends within a drilling rig.', 'In Block \n420\n, a power management sequence is executed on a drilling rig in accordance with one or more embodiments.', 'In particular, the power manager may apply the power management sequence to rig equipment and electric power generators coupled to a drilling management network.', 'In some embodiments, for example, the power manager increases the number of electric power generators at a drilling rig to match projected electric power consumption of rig equipment in a drilling operation sequence.', 'In another embodiment, the power manager disables or shuts down active electric power generators if the upcoming drilling operation requires less power than the existing power level.', 'In some other embodiments, the power manager manages changes in the number of online electric power generators in order avoid the startup transients (e.g., that last for a few seconds) that might push the system over the edge.', 'In some embodiments, the power manager may coordinate the start and stop times of various equipment by transmitting various commands.', 'As such, a power manager may transmit generator commands to electric power generators and motor commands to electric motors for managing a power management sequence.', 'If a motor is removed from a drilling operation sequence, for example, a power manager may transmit another generator command to remove an electric generator.', 'In particular, the length of how long it takes to reach rated speeds on the motor (e.g., larger motors or slow starting equipment) may be taken into account for inhibiting the start of the electric motor to protect engine overload.', 'Based on different power requirements of the power management sequence, the power manager may transmit a second generator command that causes the second electric power generator to provide electric power to the drilling rig.', 'Further, in response to the second electric power generator providing electric power, the power manager transmits a motor command that causes the electric motor to initiate operations in accordance with one or more embodiments.', 'In one or more embodiments, based on the amount of fuel, the power manager transmits various generator commands to one or more electric power generators to manage automatically a projected amount of electric power for one or more drilling operations.', 'In one or more embodiments, the power manager may use a job package or software application to adjust the start times and/or stop times and/or the timing of changing operation parameters of various equipment to reduce electromagnetic and/or pressure pulse noises during various operations, such as telemetry operations.', 'For example, the start times and/or stop time and/or the timing of changing operation parameters may be adjusted in response to various amounts of noise detected during previous operations, so as to minimize the interference with ongoing telemetry operations.', 'Thus, the power manager may automatically update the power management sequence based on changes in a drilling operation sequence or new issues detected by sensor devices around the drilling management network.', 'In some embodiments, the power manager gives different rig equipment levels of precedence during the power management sequence.', 'In particular, where rig equipment is identified with a higher degree of precedence, the power manager may allocate power to the rig equipment with a higher precedence under conditions where electric capacity cannot be adjusted.', 'Moreover, the power manager may also transmit commands to shutdown rig equipment in order that precedential rig equipment can obtain a desired amount of electric power within the drilling management network.', 'Turning to \nFIG.', '5\n, \nFIG.', '5\n provides an example of a power management sequence R (\n512\n) for a drilling operation sequence Q (\n511\n).', 'The following example is for explanatory purposes only and not intended to limit the scope of the disclosure.', 'Turning to \nFIG.', '5', ', the drilling operation sequence Q (\n511\n) includes a sequential series of time events (e.g., event A (\n520\n), event B (\n530\n), event C (\n540\n), event D (\n550\n), event E (\n560\n), event F (\n570\n), and event G (\n580\n)).', 'For example, during drilling, a drill bit on the end of a drill string is rotated to cut the earth formation, while a drilling mud is pumped through the drill string and bit into the hole.', 'As the drill bit cuts the rock, the mud moves those cuttings up the well.', 'The rock cuttings are put through a “shaker” that removes them from the mud.', 'The mud is then reused by the mud pump.', 'After a first section of the well is drilled, the bit and drill string may be pulled out of the hole, and a casing string may be run into the hole and cemented in place to ensure that the well maintains its shape and structure.', 'Upon setting, the well may be drilled to further depths with multiple sections until total depth is reached.', 'It is understood that the drilling operation sequence Q shown in \nFIG.', '5\n may be substantially longer to drill to total depth, and that the example set forth here may represent one part of a drilling operation sequence.', 'For example, at event A (\n520\n), a drill string is activated, e.g., a power and fuel requirement increase occurs at a drilling rig and thus the required number of online electric power generators (\n502\n) is increased.', 'Besides normal system requirements, a stuck drill string, reaming, or pulling out of hole, may increase the sudden requirement of online electric power generators or motors.', 'For example, the stuck drill may occur due to adhesion on not moving the drill string for a significant amount of time, keyhole sticking during tripping, differentially due to a large difference between formation pressure and wellbore pressure, and so forth.', 'In one or more embodiments, between event B (\n530\n) and event C (\n540\n), the power manager detects the requirement of fuel and electric power generators increases as a drill string goes deeper into a borehole.', 'As shown, between event C (\n540\n) to event F (\n570\n), the number of online electric power generators (\n502\n) remains the same.', 'As shown in \nFIG. \n5\n, at event D (\n550\n), event E (\n560\n) and event F (\n570\n), the power manager detects the power consumption (\n503\n) remains same and thus there is no increase in number of electric power generators.', 'In some embodiments, after event F (\n570\n), the power manager detects a sharp drop in the requirement of number of electric power generators, for example, as a drill string is re-run into a hole.', 'At event G (\n580\n), the power manager carries out maintenance operation A and shuts down/ramp down/bypass the number of online electric power generators (\n502\n) in case there is no need to maintain existing power level.', 'With respect to event F (\n570\n) and event G (\n580\n), these may be well-timed events to allow some time for the electric power generators to shutdown gracefully.', 'As such, the deactivation of operations in event D (\n550\n), event E (\n560\n), event F (\n570\n), and event G (\n580\n) may include graceful shutdowns and/or forceful shutdowns.', 'While the drilling operation sequence Q (\n511\n) in \nFIG.', '5\n illustrates one sequence of events for an orchestrated power management, other sequences of events are contemplated that include adding and/or removing events from a drilling operation sequence.', 'Likewise, operations of various components may be terminated in a different order from the drilling operation sequence Q (\n511\n).', 'Embodiments may be implemented on a computing system.', 'Any combination of mobile, desktop, server, router, switch, embedded device, or other types of hardware may be used.', 'For example, as shown in \nFIG. \n6\n.\n1\n, the computing system (\n600\n) may include one or more computer processors (\n602\n), non-persistent storage (\n604\n) (e.g., volatile memory, such as random access memory (RAM), cache memory), persistent storage (\n606\n) (e.g., a hard disk, an optical drive such as a compact disk (CD) drive or digital versatile disk (DVD) drive, a flash memory, etc.), a communication interface (\n612\n) (e.g., Bluetooth interface, infrared interface, network interface, optical interface, etc.), and numerous other elements and functionalities.', 'The computer processor(s) (\n602\n) may be an integrated circuit for processing instructions.', 'For example, the computer processor(s) may be one or more cores or micro-cores of a processor.', 'The computing system (\n600\n) may also include one or more input devices (\n610\n), such as a touchscreen, keyboard, mouse, microphone, touchpad, electronic pen, or any other type of input device.', 'The communication interface (\n612\n) may include an integrated circuit for connecting the computing system (\n600\n) to a network (not shown) (e.g., a local area network (LAN), a wide area network (WAN) such as the Internet, mobile network, or any other type of network) and/or to another device, such as another computing device.', 'Further, the computing system (\n600\n) may include one or more output devices (\n608\n), such as a screen (e.g., a liquid crystal display (LCD), a plasma display, touchscreen, cathode ray tube (CRT) monitor, projector, or other display device), a printer, external storage, or any other output device.', 'One or more of the output devices may be the same or different from the input device(s).', 'The input and output device(s) may be locally or remotely connected to the computer processor(s) (\n602\n), non-persistent storage (\n604\n), and persistent storage (\n606\n).', 'Many different types of computing systems exist, and the aforementioned input and output device(s) may take other forms.', 'Software instructions in the form of computer readable program code to perform embodiments of the disclosure may be stored, in whole or in part, temporarily or permanently, on a non-transitory computer readable medium such as a CD, DVD, storage device, a diskette, a tape, flash memory, physical memory, or any other computer readable storage medium.', 'Specifically, the software instructions may correspond to computer readable program code that, when executed by a processor(s), is configured to perform one or more embodiments of the disclosure.', 'The computing system (\n600\n) in \nFIG.', '6\n.\n1\n may be connected to or be a part of a network.', 'For example, as shown in \nFIG. \n6\n.', '2\n, the network (\n620\n) may include multiple nodes (e.g., node X (\n622\n), node Y (\n624\n)).', 'Each node may correspond to a computing system, such as the computing system shown in \nFIG.', '6\n.', '1\n, or a group of nodes combined may correspond to the computing system shown in \nFIG.', '6\n.', '1\n.', 'By way of an example, embodiments of the disclosure may be implemented on a node of a distributed system that is connected to other nodes.', 'By way of another example, embodiments of the disclosure may be implemented on a distributed computing system having multiple nodes, where each portion of the disclosure may be located on a different node within the distributed computing system.', 'Further, one or more elements of the aforementioned computing system (\n600\n) may be located at a remote location and connected to the other elements over a network.', 'Although not shown in \nFIG. \n6\n.\n2\n, the node may correspond to a blade in a server chassis that is connected to other nodes via a backplane.', 'By way of another example, the node may correspond to a server in a data center.', 'By way of another example, the node may correspond to a computer processor or micro-core of a computer processor with shared memory and/or resources.', 'The nodes (e.g., node X (\n622\n), node Y (\n624\n)) in the network (\n620\n) may be configured to provide services for a client device (\n626\n).', 'For example, the nodes may be part of a cloud computing system.', 'The nodes may include functionality to receive requests from the client device (\n626\n) and transmit responses to the client device (\n626\n).', 'The client device (\n626\n) may be a computing system, such as the computing system shown in \nFIG.', '6\n.', '1\n.', 'Further, the client device (\n626\n) may include and/or perform all or a portion of one or more embodiments of the disclosure.', 'The computing system or group of computing systems described in \nFIGS.', '6\n.', '1\n and \n6\n.', '2\n may include functionality to perform a variety of operations disclosed herein.', 'For example, the computing system(s) may perform communication between processes on the same or different systems.', 'A variety of mechanisms, employing some form of active or passive communication, may facilitate the exchange of data between processes on the same device.', 'Examples representative of these inter-process communications include, but are not limited to, the implementation of a file, a signal, a socket, a message queue, a pipeline, a semaphore, shared memory, message passing, and a memory-mapped file.', 'Further details pertaining to a couple of these non-limiting examples are provided below.', 'Based on the client-server networking model, sockets may serve as interfaces or communication channel end-points enabling bidirectional data transfer between processes on the same device.', 'Foremost, following the client-server networking model, a server process (e.g., a process that provides data) may create a first socket object.', 'Next, the server process binds the first socket object, thereby associating the first socket object with a unique name and/or address.', 'After creating and binding the first socket object, the server process then waits and listens for incoming connection requests from one or more client processes (e.g., processes that seek data).', 'At this point, when a client process wishes to obtain data from a server process, the client process starts by creating a second socket object.', 'The client process then proceeds to generate a connection request that includes at least the second socket object and the unique name and/or address associated with the first socket object.', 'The client process then transmits the connection request to the server process.', 'Depending on availability, the server process may accept the connection request, establishing a communication channel with the client process, or the server process, busy in handling other operations, may queue the connection request in a buffer until the server process is ready.', 'An established connection informs the client process that communications may commence.', 'In response, the client process may generate a data request specifying the data that the client process wishes to obtain.', 'The data request is subsequently transmitted to the server process.', 'Upon receiving the data request, the server process analyzes the request and gathers the requested data.', 'Finally, the server process then generates a reply including at least the requested data and transmits the reply to the client process.', 'The data may be transferred, more commonly, as datagrams or a stream of characters (e.g., bytes).', 'Shared memory refers to the allocation of virtual memory space in order to substantiate a mechanism for which data may be communicated and/or accessed by multiple processes.', 'In implementing shared memory, an initializing process first creates a shareable segment in persistent or non-persistent storage.', 'Post creation, the initializing process then mounts the shareable segment, subsequently mapping the shareable segment into the address space associated with the initializing process.', 'Following the mounting, the initializing process proceeds to identify and grant access permission to one or more authorized processes that may also write and read data to and from the shareable segment.', 'Changes made to the data in the shareable segment by one process may immediately affect other processes, which are also linked to the shareable segment.', 'Further, when one of the authorized processes accesses the shareable segment, the shareable segment maps to the address space of that authorized process.', 'Often, one authorized process may mount the shareable segment, other than the initializing process, at any given time.', 'Other techniques may be used to share data, such as the various data described in the present application, between processes without departing from the scope of the disclosure.', 'The processes may be part of the same or different application and may execute on the same or different computing system.', 'Rather than or in addition to sharing data between processes, the computing system performing one or more embodiments of the disclosure may include functionality to receive data from a user.', 'For example, in one or more embodiments, a user may submit data via a graphical user interface (GUI) on the user device.', 'Data may be submitted via the graphical user interface by a user selecting one or more graphical user interface widgets or inserting text and other data into graphical user interface widgets using a touchpad, a keyboard, a mouse, or any other input device.', 'In response to selecting a particular item, information regarding the particular item may be obtained from persistent or non-persistent storage by the computer processor.', "Upon selection of the item by the user, the contents of the obtained data regarding the particular item may be displayed on the user device in response to the user's selection.", 'By way of another example, a request to obtain data regarding the particular item may be sent to a server operatively connected to the user device through a network.', 'For example, the user may select a uniform resource locator (URL) link within a web client of the user device, thereby initiating a Hypertext Transfer Protocol (HTTP) or other protocol request being sent to the network host associated with the URL.', 'In response to the request, the server may extract the data regarding the particular selected item and send the data to the device that initiated the request.', "Once the user device has received the data regarding the particular item, the contents of the received data regarding the particular item may be displayed on the user device in response to the user's selection.", 'Further to the above example, the data received from the server after selecting the URL link may provide a web page in Hyper Text Markup Language (HTML) that may be rendered by the web client and displayed on the user device.', 'Once data is obtained, such as by using techniques described above or from storage, the computing system, in performing one or more embodiments of the disclosure, may extract one or more data items from the obtained data.', 'For example, the extraction may be performed as follows by the computing system (\n600\n) in \nFIG.', '6\n.', '1\n.', 'First, the organizing pattern (e.g., grammar, schema, layout) of the data is determined, which may be based on one or more of the following: position (e.g., bit or column position, Nth token in a data stream, etc.), attribute (where the attribute is associated with one or more values), or a hierarchical/tree structure (consisting of layers of nodes at different levels of detail—such as in nested packet headers or nested document sections).', 'Then, the raw, unprocessed stream of data symbols is parsed, in the context of the organizing pattern, into a stream (or layered structure) of tokens (where each token may have an associated token “type”).', 'Next, extraction criteria are used to extract one or more data items from the token stream or structure, where the extraction criteria are processed according to the organizing pattern to extract one or more tokens (or nodes from a layered structure).', 'For position-based data, the token(s) at the position(s) identified by the extraction criteria are extracted.', 'For attribute/value-based data, the token(s) and/or node(s) associated with the attribute(s) satisfying the extraction criteria are extracted.', 'For hierarchical/layered data, the token(s) associated with the node(s) matching the extraction criteria are extracted.', 'The extraction criteria may be as simple as an identifier string or may be a query presented to a structured data repository (where the data repository may be organized according to a database schema or data format, such as XML).', 'The extracted data may be used for further processing by the computing system.', 'For example, the computing system of \nFIG.', '6\n.', '1\n, while performing one or more embodiments of the disclosure, may perform data comparison.', 'Data comparison may be used to compare two or more data values (e.g., A, B).', 'For example, one or more embodiments may determine whether A>B, A=B, A !=B, A B, B may be subtracted from A (i.e., A−B), and the status flags may be read to determine if the result is positive (i.e., if A>B, then A−B>0).', 'In one or more embodiments, B may be considered a threshold, and A is deemed to satisfy the threshold if A=B or if A>B, as determined using the ALU.', 'In one or more embodiments of the disclosure, A and B may be vectors, and comparing A with B includes comparing the first element of vector A with the first element of vector B, the second element of vector A with the second element of vector B, etc.', 'In one or more embodiments, if A and B are strings, the binary values of the strings may be compared.', 'The computing system in \nFIG.', '6\n.\n1\n may implement and/or be connected to a data repository.', 'For example, one type of data repository is a database.', 'A database is a collection of information configured for ease of data retrieval, modification, re-organization, and deletion.', 'Database Management System (DBMS) is a software application that provides an interface for users to define, create, query, update, or administer databases.', 'The user, or software application, may submit a statement or query into the DBMS.', 'Then the DBMS interprets the statement.', 'The statement may be a select statement to request information, update statement, create statement, delete statement, etc.', 'Moreover, the statement may include parameters that specify data, or data container (database, table, record, column, view, etc.), identifier(s), conditions (comparison operators), functions (e.g. join, full join, count, average, etc.), sort (e.g. ascending, descending), or others.', 'The DBMS may execute the statement.', 'For example, the DBMS may access a memory buffer, a reference or index a file for read, write, deletion, or any combination thereof, for responding to the statement.', 'The DBMS may load the data from persistent or non-persistent storage and perform computations to respond to the query.', 'The DBMS may return the result(s) to the user or software application.', 'The computing system of \nFIG.', '6\n.\n1\n may include functionality to present raw and/or processed data, such as results of comparisons and other processing.', 'For example, presenting data may be accomplished through various presenting methods.', 'Specifically, data may be presented through a user interface provided by a computing device.', 'The user interface may include a GUI that displays information on a display device, such as a computer monitor or a touchscreen on a handheld computer device.', 'The GUI may include various GUI widgets that organize what data is shown as well as how data is presented to a user.', 'Furthermore, the GUI may present data directly to the user, e.g., data presented as actual data values through text, or rendered by the computing device into a visual representation of the data, such as through visualizing a data model.', 'For example, a GUI may first obtain a notification from a software application requesting that a particular data object be presented within the GUI.', 'Next, the GUI may determine a data object type associated with the particular data object, e.g., by obtaining data from a data attribute within the data object that identifies the data object type.', 'Then, the GUI may determine any rules designated for displaying that data object type, e.g., rules specified by a software framework for a data object class or according to any local parameters defined by the GUI for presenting that data object type.', 'Finally, the GUI may obtain data values from the particular data object and render a visual representation of the data values within a display device according to the designated rules for that data object type.', 'Data may also be presented through various audio methods.', 'In particular, data may be rendered into an audio format and presented as sound through one or more speakers operably connected to a computing device.', 'Data may also be presented to a user through haptic methods.', 'For example, haptic methods may include vibrations or other physical signals generated by the computing system.', 'For example, data may be presented to a user using a vibration generated by a handheld computer device with a predefined duration and intensity of the vibration to communicate the data.', 'The above description of functions presents only a few examples of functions performed by the computing system of \nFIG.', '6\n.', '1\n and the nodes and/or client device in \nFIG.', '6\n.', '2\n.', 'Other functions may be performed using one or more embodiments of the disclosure.', 'While the disclosure has been described with respect to a limited number of embodiments, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments can be devised which do not depart from the scope of the disclosure as disclosed herein.', 'Accordingly, the scope of the disclosure should be limited only by the attached claims.']

['1.', 'A method, comprising:\nobtaining, from a digital drilling program and by a drilling management network, a drilling operation sequence indicating a predetermined order of scheduled events of a drilling rig, wherein the drilling management network is coupled to the drilling rig, rig equipment, and a plurality of electric power generators;\ndetermining, by the drilling management network, a projected electric power consumption of the rig equipment based on the drilling operation sequence;\ndetermining, by the drilling management network, a power management sequence that matches an electric power capacity of the drilling rig to an electric power consumption of the rig equipment, wherein determining the power management sequence comprises determining to change a number of online electric power generators to match the projected electric power consumption of the rig equipment;\nexecuting, by the drilling management network, the power management sequence to the rig equipment and the plurality of electric power generators, wherein executing the power management sequence comprises changing the number of online electric power generators; and\nadjusting, in real-time, the power management sequence of the rig equipment in response to a change in the electric power capacity of the drilling rig or a change in the electric power consumption of the rig equipment, wherein adjusting the power management sequence of the rig equipment comprises adjusting the drilling operation sequence of the drilling rig based on the change in the electric power consumption of the rig equipment or the change in the electric power capacity of the drilling rig, and wherein adjusting the power management sequence of the rig equipment further comprises allocating available electric power capacity to particular rig equipment in order of a priority of the rig equipment.', '2.', 'The method of claim 1, wherein executing the power management sequence comprises transmitting, to an electric power generator among the plurality of electric power generators, a generator command based on the power management sequence.', '3.', 'The method of claim 1, wherein the digital drilling program comprises a digital description of the drilling operation sequence for a well construction.', '4.', 'The method of claim 3, wherein the digital description comprises an estimated power consumption of the rig equipment within the drilling operation sequence.', '5.', 'The method of claim 1, wherein the digital drilling program comprises operation parameters for the rig equipment within the drilling operation sequence.', '6.', 'The method of claim 1, wherein executing the power management sequence comprises automatically adjusting the drilling operation sequence based on power consumption data and rig power supply to produce an adjusted drilling operation sequence, adjusting operation parameters in the adjusted drilling operation sequence, and executing the adjusted drilling operation sequence on the drilling management network.', '7.', 'The method of claim 1, further comprising detecting the change in the electric power consumption of the rig equipment based on a change in a drilling path, a stuck drill bit, a reaming operation, pulling out of a borehole, or rerunning into the borehole.', '8.', 'A system, comprising:\na sensor device;\na plurality of electric power generators; rig equipment;\na drilling management network coupled to the sensor device, the plurality of electric power generators, the rig equipment, and a drilling rig, the drilling management network comprising a plurality of network elements; and\na power manager coupled to the drilling management network, wherein the power manager comprises a computer processor and is configured to: obtain, from a digital drilling program, a drilling operation sequence indicating a predetermined order of scheduled events of the drilling rig; determine a projected electric power consumption of the rig equipment based on the drilling operation sequence; determine a power management sequence that matches an electric power capacity of the drilling rig to an electric power consumption of the rig equipment, wherein determining the power management sequence comprises determining to change a number of online electric power generators to match the projected electric power consumption of the rig equipment; execute the power management sequence to the rig equipment and the plurality of electric power generators; and adjust, in real-time, the power management sequence of the rig equipment in response to a change in the electric power capacity of the drilling rig or a change in the electric power consumption of the rig equipment, wherein adjusting the power management sequence of the rig equipment comprises adjusting the drilling operation sequence of the drilling rig based on the change in the electric power consumption of the rig equipment or the change in the electric power capacity of the drilling rig, and wherein adjusting the power management sequence of the rig equipment further comprises allocating available electric power capacity to particular rig equipment in order of a priority of the rig equipment.\n\n\n\n\n\n\n9.', 'The system of claim 8, wherein the power manager is further configured to transmit, to an electric power generator among the plurality of electric power generators, a generator command based on the power management sequence.', '10.', 'The system of claim 8, wherein the digital drilling program comprises a digital description of the drilling operation sequence for a well construction, and wherein the digital description comprises an estimated power consumption of the rig equipment within the drilling operation sequence.', '11.', 'The system of claim 8, wherein the power manager is further configured to detect the change in the electric power consumption of the rig equipment based on a change in a drilling path, a stuck drill bit, a reaming operation, pulling out of a borehole, or rerunning into the borehole.', '12.', 'A non-transitory computer readable medium storing instructions, the instructions executable by a computer processor and comprising functionality for:\nobtaining, over a drilling management network, a drilling operation sequence indicating a predetermined order of scheduled events of a drilling rig from a digital drilling program, wherein the drilling management network is coupled to the drilling rig, rig equipment, and a plurality of electric power generators;\ndetermining, over the drilling management network, a projected electric power consumption of the rig equipment based on the drilling operation sequence;\ndetermining a power management sequence that matches an electric power capacity of the drilling rig to an electric power consumption of the rig equipment, wherein determining the power management sequence comprises determining to change a number of online electric power generators to match the projected electric power consumption of the rig equipment;\nexecuting, over the drilling management network, the power management sequence to the rig equipment and the plurality of electric power generators, wherein executing the power management sequence comprises changing the number of online electric power generators; and\nadjusting, in real-time, the power management sequence of the rig equipment in response to a change in the electric power capacity of the drilling rig or a change in the electric power consumption of the rig equipment, wherein adjusting the power management sequence of the rig equipment comprises adjusting the drilling operation sequence of the drilling rig based on the change in the electric power consumption of the rig equipment or the change in the electric power capacity of the drilling rig, and wherein adjusting the power management sequence of the rig equipment further comprises allocating available electric power capacity to particular rig equipment in order of a priority of the rig equipment.\n\n\n\n\n\n\n13.', 'The non-transitory computer readable medium of claim 12, wherein the digital drilling program comprises a digital description of the drilling operation sequence for a well construction, and wherein the digital description comprises an estimated power consumption of the rig equipment within the drilling operation sequence.', '14.', 'The non-transitory computer readable medium of claim 12, wherein the instructions further comprise functionality for detecting the change in the electric power consumption of the rig equipment based on a change in a drilling path, a stuck drill bit, a reaming operation, pulling out of a borehole, or rerunning into the borehole.']

['FIGS. 1, 2 and 3 show systems in accordance with one or more embodiments.; FIG.', '4 shows a flowchart in accordance with one or more embodiments.; FIG.', '5 shows an example in accordance with one or more embodiments.; FIGS.', '6.1 and 6.2 show a computing system in accordance with one or more embodiments.; FIG.', '1 shows a block diagram of a system in accordance with one or more embodiments.', 'FIG.', '1 shows a drilling system (10) according to one or more embodiments.', 'Drill string (58) is shown within borehole (46).', 'Borehole (46) may be located in the earth (40) having a surface (42).', 'Borehole (46) is shown being cut by the action of drill bit (54).', 'Drill bit (54) may be disposed at the far end of the bottom hole assembly (56) that is attached to and forms the lower portion of drill string (58).', 'Bottom hole assembly (56) may include a number of devices including various subassemblies.', 'Measurement-while-drilling (MWD) subassemblies may be included in subassemblies (62).', 'Examples of MWD measurements may include direction, inclination, survey data, downhole pressure (inside the drill pipe, and/or outside and/or annular pressure), resistivity, density, and porosity.', 'Subassemblies (62) may also include a subassembly for measuring torque and weight on the drill bit (54).', 'The signals from the subassemblies (62) may be processed in a processor (66).', 'After processing, the information from processor (66) may be communicated to pulser assembly (64).', 'Pulser assembly (64) may convert the information from the processor (66) into pressure pulses in the drilling fluid.', 'The pressure pulses may be generated in a particular pattern which represents the data from the subassemblies (62).', 'The pressure pulses may travel upwards through the drilling fluid in the central opening in the drill string and towards the surface system.', 'The subassemblies in the bottom hole assembly (56) may further include a turbine or motor for providing power for rotating and steering drill bit (54).', 'Alternatively, the signals from subassembly 62 may be transmitted to the surface via other telemetry means, such as EM telemetry, or wired drillpipe, etc.']

US11939867

Downhole directional drilling tool

Feb 14, 2020

Andrew Mueller, Dennis Patrick Chesnutt, Ke Chen, Xiaoge Gan, Venkatesh Karuppiah

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent application PCT/US2020/018227 dated Jun. 23, 2020, 18 pages.; International Preliminary Report on Patentability issued in International Patent application PCT/US2020/018227, dated Aug. 10, 2021, 11 pages.

6484825; November 26, 2002; Watson; 8066085; November 29, 2011; Johnson et al.; 8534380; September 17, 2013; Sheppard et al.; 8720604; May 13, 2014; Sheppard; 8727036; May 20, 2014; Johnson; 8757294; June 24, 2014; Johnson et al.; 8763726; July 1, 2014; Johnson et al.; 8899352; December 2, 2014; Johnson et al.; 10597942; March 24, 2020; Caresta; 11118406; September 14, 2021; Caresta et al.; 20020079139; June 27, 2002; Mensa-Wilmot et al.; 20090044977; February 19, 2009; Johnson et al.; 20090044980; February 19, 2009; Sheppard; 20090188720; July 30, 2009; Johnson; 20110015911; January 20, 2011; Chen; 20110253457; October 20, 2011; Shen et al.; 20140014413; January 16, 2014; Niina; 20150107902; April 23, 2015; Downton; 20180283103; October 4, 2018; Caresta; 20190316420; October 17, 2019; Russell; 20200003010; January 2, 2020; Bittleston; 20200003011; January 2, 2020; Sihler et al.; 20200141188; May 7, 2020; Marshall; 20220112770; April 14, 2022; Mueller

2011002993; January 2011; WO

['A downhole tool has a directional pad that contacts a wellbore wall at a pad contact location and a drill bit with at least one active cutting element that contacts the wellbore wall at a cutting element contact location.', 'A contact distance between the pad contact location and the cutting element contact location being 3 in.', '(7.6 cm) or less.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is the U.S. national phase of International Patent Application No. PCT/US2020/018227, filed Feb. 14, 2020, and entitled, “Downhole Directional Drilling Tool” which claims the benefit of, and priority to, U.S. Patent Application No. 62/805,977 filed on Feb. 15, 2019, which is incorporated herein by this reference in its entirety.', 'BACKGROUND\n \nWellbores may be drilled into a surface location or seabed for a variety of exploratory or extraction purposes.', 'For example, a wellbore may be drilled to access fluids, such as liquid and gaseous hydrocarbons, stored in subterranean formations and to extract the fluids from the formations.', 'Wellbores used to produce or extract fluids may be lined with casing around the walls of the wellbore.', 'A variety of drilling methods may be utilized depending partly on the characteristics of the formation through which the wellbore is drilled.', 'The wellbores may be drilled by a drilling system that drills through earthen material downward from the surface.', 'Some wellbores are drilled vertically downward, and some wellbores have one or more curves in the wellbore to follow desirable geological formations, avoid problematic geological formations, or a combination of the two.', 'SUMMARY', 'In some aspects, a downhole tool includes a directional pad configured to contact a wellbore wall at a pad contact location and a drill bit having at least one active cutting element.', 'The at least one active cutting element contacts the wellbore wall at a cutting element contact location, and a contact distance between the pad contact location and the cutting element contact location being 3 in.', '(7.6 cm) or less.', 'According to some aspects, a downhole tool includes a directional pad configured to contact a wellbore wall at a pad contact location and a drill bit having at least one active cutting element.', 'A contact ratio between a bit diameter and a contact length between the pad contact location and the at least one active cutting element being greater than 3:1.', 'According to further aspects, a downhole tool includes a directional pad configured to contact a wellbore wall at a pad contact location and a drill bit having at least one active cutting element.', 'A directional pad angle between the contact location and the at least one active cutting element relative to the longitudinal axis is greater than 0° and less than or equal to 5°.', 'Additional aspects include a downhole tool having a directional pad configured to contact a wellbore wall at a pad contact location and a drill bit having a first active cutting element and a second active cutting element.', 'The first active cutting element is located further uphole than any other cutting element and the second active cutting element is located further uphole than any other cutting element except the first active cutting element.', 'An angle between the first active cutting element and the second active cutting element being greater than 0° and less than or equal to 5°.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Rather, additional features and aspects of embodiments of the disclosure will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by the practice of such embodiments.', 'The features and aspects of such embodiments may be realized and obtained by means of the instruments and combinations particularly pointed out in the appended claims.', 'These and other features will become more fully apparent from the following description and appended claims, or may be learned by the practice of such embodiments as set forth hereinafter.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'In order to describe the manner in which the above-recited and other features of the disclosure can be obtained, a more particular description will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings.', 'For better understanding, the like elements have been designated by like reference numbers throughout the various accompanying figures.', 'While some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale.', 'Understanding that the drawings depict some example embodiments, the embodiments will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:\n \nFIG.', '1\n is a representation of a drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n is a representation of a prior art directional drilling system;\n \nFIG.', '3\n is a representation of a directional drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '4\n is a cross-sectional view of a directional drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '5\n is another cross-sectional view of a directional drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '6\n is a partial side view of a bit, according to at least one embodiment of the present disclosure;\n \nFIG.', '7\n is another partial side view of a bit, according to at least one embodiment of the present disclosure;\n \nFIG.', '8\n is side view of a bit, according to at least one embodiment of the present disclosure;\n \nFIG.', '9\n is a representation of a composite cutting profile, according to at least one embodiment of the present disclosure;\n \nFIG.', '10\n is another representation of a composite cutting profile, according to at least one embodiment of the present disclosure;\n \nFIG.', '11\n is a side view of an assembly tool usable to connect a drive shaft to a drill bit, according to at least one embodiment of the present disclosure;\n \nFIG.', '12\n-\n1\n is a perspective view of another assembly tool usable to connect a drive shaft to a drill bit, according to at least one embodiment of the present disclosure; and\n \nFIG.', '12\n-\n2\n is a perspective view of the assembly tool of \nFIG.', '12\n-\n1\n, with the drill bit removed.', 'DETAILED DESCRIPTION', 'This disclosure generally relates to devices, systems, and methods for a downhole directional drilling tool.\n \nFIG.', '1\n shows one example of a drilling system \n100\n for drilling an earth formation \n101\n to form a wellbore \n102\n.', 'The drilling system \n100\n includes a drill rig \n103\n used to turn a drilling tool assembly \n104\n which extends downward into the wellbore \n102\n.', 'The drilling tool assembly \n104\n may include a drill string \n105\n, a bottomhole assembly (“BHA”) \n106\n, and a bit \n110\n, attached to the downhole end of drill string \n105\n.', 'The drill string \n105\n may include several joints of drill pipe \n108\n a connected end-to-end through tool joints \n109\n.', 'The drill string \n105\n transmits drilling fluid through a central bore and transmits rotational power from the drill rig \n103\n to the BHA \n106\n.', 'In some embodiments, the drill string \n105\n may further include additional components such as subs, pup joints, etc.', 'The drill pipe \n108\n provides a hydraulic passage through which drilling fluid is pumped from the surface.', 'The drilling fluid discharges through selected-size nozzles, jets, or other orifices in the bit \n110\n for the purposes of cooling the bit \n110\n and cutting structures thereon, and for lifting cuttings out of the wellbore \n102\n as it is being drilled.', 'The BHA \n106\n may include the bit \n110\n or other components.', 'An example BHA \n106\n may include additional or other components (e.g., coupled between to the drill string \n105\n and the bit \n110\n).', 'Examples of additional BHA components include drill collars, stabilizers, measurement-while-drilling (“MWD”) tools, logging-while-drilling (“LWD”) tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'In general, the drilling system \n100\n may include other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves).', 'Additional components included in the drilling system \n100\n may be considered a part of the drilling tool assembly \n104\n, the drill string \n105\n, or a part of the BHA \n106\n depending on their locations in the drilling system \n100\n.', 'The bit \n110\n in the BHA \n106\n may be any type of bit suitable for degrading downhole materials.', 'For instance, the bit \n110\n may be a drill bit suitable for drilling the earth formation \n101\n.', 'Example types of drill bits used for drilling earth formations are fixed-cutter or drag bits.', 'Swarf or other cuttings formed by use of a mill may be lifted to surface, or may be allowed to fall downhole.', 'The bit \n110\n may be guided by a directional drilling assembly \n112\n.\n \nFIG.', '2\n is a representation of a prior art directional drilling assembly \n212\n including a bit \n210\n.', 'The bit \n210\n may be connected to a directional drilling sub \n214\n having one or more selectively directional pads \n216\n configured to contact a wall \n218\n of the wellbore \n202\n.', 'The directional pads may be expandable, such as where the directional drilling sub \n214\n is a rotary steerable system.', 'As the directional pads \n216\n selectively expand and contact the wall \n218\n, the bit \n210\n experiences a greater force at a bit contact location \n224\n on an opposite side of the wall \n218\n, thereby forcing a radial deflection, or dog leg, of the wellbore \n202\n.', 'The bit \n210\n is stabilized by a contact of the stabilizer \n220\n with the wall \n218\n at a stabilizer contact location, thereby encouraging a consistent radial deflection, or dog leg severity (DLS).', 'The DLS is increased the closer the directional pads \n216\n are located to the bit contact location \n224\n.', 'In the shown directional drilling assembly \n212\n (e.g., including a rotary steerable system), the internal structural mechanics of selectively extending the directional pads \n216\n limits how close to the bit \n210\n the directional pads \n216\n may be placed.', 'As shown, the distance between the directional pads \n216\n and the bit contact location \n224\n is large.', 'For example, as shown the distance between the directional pads \n216\n and the bit contact location \n224\n is greater than 12 in.', '(30.5 cm).', 'FIG.', '3\n is a representation of an embodiment of a directional drilling assembly \n312\n.', 'A bit \n310\n may be connected to a directional drilling sub \n314\n with a bit connection \n328\n.', 'A directional pad \n316\n may be connected to a downhole end of the directional drilling sub \n314\n.', 'The directional pad \n316\n may be located or housed in directional pad housing \n330\n located on the directional drilling sub \n314\n.', 'In some embodiments, the directional pad \n316\n (and optionally the portion of the directional pad housing \n330\n supporting the directional pad \n316\n) may be located on or toward the lower end of the directional drilling sub \n314\n, and may extend past a downhole end \n332\n of the directional pad housing \n330\n and/or the directional drilling sub \n314\n.', 'In particular, a distance referred to as an overhang \n334\n is shown as the distance the directional pad \n316\n (and/or associated portion of the directional pad housing \n330\n) extends past, or overhangs, the downhole end \n332\n of another portion of the directional pad housing \n330\n.', 'As shown in \nFIG.', '3\n, the portion of the directional pad housing \n330\n at which downhole end \n332\n is located may be directly opposed to the directional pad \n316\n; however, this is not limiting.', 'In the same or other embodiments, the downhole end \n332\n may be the downhole end of a portion of the directional pad housing \n330\n supporting a second pad \n317\n.', 'In some embodiments, the second pad \n317\n does not extend axially as far downhole as the direction pad \n316\n.', 'In the same or other embodiments, the second pad \n317\n also may extend radially from the portion of the directional pad housing \n330\n.', 'The amount of radial extension of the second pad \n317\n may vary, and in some embodiments the distance between a longitudinal axis of the directional pad housing \n330\n and the outer surface of the second pad \n317\n is less than the distance between the longitudinal axis of the directional pad housing \n330\n and the outer surface of the directional pad \n316\n.', 'In further example embodiments, the distance between the longitudinal axis of the directional pad housing \n330\n and the outer surface of the second pad \n317\n may be less than or equal to a cutting element radius at the final cutting element contact location \n338\n.', 'In some embodiments, the second pad \n317\n is a discrete component attached to the directional pad housing \n330\n.', 'In other embodiments, the second pad \n317\n is integrally formed with the directional pad housing \n330\n (see \nFIG.', '4\n).', 'Further, any number of second pads \n317\n may be used.', 'For instance, in at least some embodiments, the directional pad housing \n330\n includes or is attached to one directional pad \n316\n and two, three, four, or more second pads \n317\n.', 'The directional pad \n316\n may engage or contact the wall \n318\n of the wellbore \n302\n at a pad contact location \n336\n.', 'Cutting elements \n337\n located on the bit \n310\n may engage the formation \n301\n, degrading or cutting the formation \n301\n to form the wellbore \n302\n.', 'Some of the cutting elements \n337\n are active cutting elements \n337\n, meaning that they actively engage and remove the formation \n301\n, or cut a path through the formation \n301\n.', 'At least one of the active cutting elements \n337\n may be at a position defining a final active cutting element contact location \n338\n.', 'In some embodiments, a contact length \n340\n between the pad contact location \n336\n and the final cutting element contact location \n338\n may directly influence the DLS achievable using the directional drilling assembly \n312\n.', 'In other words, a shorter contact length \n340\n may increase the DLS, and a longer contact length \n340\n may decrease the DLS.', 'In some embodiments, the bit \n310\n may rotate independently of, or relative to, the directional pad housing \n330\n.', 'In other words, the bit \n310\n may be driven by a downhole motor (not shown), such as a mud turbine or a Moineau pump.', 'The directional pad \n316\n may retain an absolute angular orientation (e.g., relative to a gravitational force and/or a cardinal direction such as magnetic north).', 'As the wellbore \n302\n advances, the directional pad \n316\n may slide along the wellbore wall \n318\n, constantly pushing the bit \n310\n opposite the pad contact location \n336\n.', 'Thus, the directional drilling assembly \n312\n may form a dog leg by slide drilling.', 'The direction of the dog leg may be changed by rotating the directional pad housing \n330\n.', 'Moreover, the magnitude of DLS can be adjusted by adjusting by switching between the drilling modes from sliding to rotating.', 'At least a portion of a downhole tool (such as a downhole motor drive shaft, not shown) extends from the downhole end \n332\n of the directional pad housing \n330\n to form the bit connection \n328\n.', 'The bit connection \n328\n may extend a connection length \n342\n, thereby moving (e.g., extending) the directional pad housing \n330\n, and potentially the directional pad \n316\n, away from the bit \n310\n.', 'In some embodiments, including an overhang \n334\n extending or protruding past the downhole end \n332\n of another portion of the directional pad housing \n330\n may allow the directional pad \n316\n to be positioned closer to the drill bit \n310\n, without interfering with the bit connection \n328\n.', 'In this manner, the contact length \n340\n may be decreased, thereby increasing the DLS.\n \nFIG.', '4\n is a cross-sectional view of an embodiment of a portion of a directional drilling assembly \n412\n.', 'In some embodiments, the directional drilling assembly \n412\n may be an enlarged view of a portion of the directional drilling assembly \n312\n of \nFIG.', '3\n.', 'In \nFIG.', '4\n, a bit \n410\n is connected to a downhole tool \n444\n at a bit connection \n428\n.', 'A directional pad \n416\n may be attached to a directional pad housing \n430\n, and the directional pad \n416\n may contact the wall \n418\n of the wellbore \n402\n at one or more pad contact locations \n436\n.', 'In some embodiments, the directional pad \n416\n contacts the wall \n418\n in a single location, or at a point location, or along a single line.', 'In other embodiments, the directional pad \n416\n may contact the wall \n418\n over an area of the directional pad \n416\n.', 'In some embodiments, there is a significant contact area, such as half, a majority, or an entirety of the area of the outer surface of the directional pad \n416\n.', 'The pad contact location \n436\n may be the downhole-most location where the directional pad \n416\n contacts the wall \n418\n.', 'The bit \n410\n may include a plurality of cutting elements \n437\n.', 'Some of the cutting elements \n437\n may be active cutting elements \n437\n.', 'Active cutting elements \n437\n are cutting elements that actively degrade and remove a volume of the formation \n401\n while the bit \n410\n rotates and weight on bit is applied downhole.', 'Thus, a cutting element that is uphole of a cutting element at a greater or equal radial distance may not be considered an active cutting element \n437\n as the volume that could be removed by that cutting element may be removed by the time the cutting element is moved to the location of the removed rock.', 'Rather, such a cutting element may instead be used to protect gauge, stabilize the bit, or for backreaming, rather than for active cutting while advancing the drill bit \n410\n.', 'A final active cutting element \n437\n-\n1\n may be the uphole-most active cutting element \n437\n.', 'Accordingly, the final active cutting element \n437\n-\n1\n may be located further uphole than every other active cutting element \n437\n of the plurality of cutting elements \n437\n.', 'In some examples, the final active cutting element \n437\n-\n1\n element may be the furthest uphole cutting element \n437\n.', 'In other examples, one or more cutting elements \n437\n, which are not active, may be uphole of the final active cutting element \n437\n.', 'For instance, one or more cutting elements \n437\n may be used for backreaming when the bit \n410\n is removed from the borehole.', 'The final active cutting element \n437\n-\n1\n may engage the formation \n401\n at a final cutting element contact location \n438\n and remove a volume of rock from the formation \n401\n.', 'The final cutting element contact location \n438\n may be at approximately the center (e.g., longitudinal center for cylindrical shaped cutters) of the final active cutting element \n437\n-\n1\n, measured lengthwise down a longitudinal axis \n446\n of the directional drilling assembly \n412\n.', 'Thus, the contact length \n440\n may be the distance between the pad contact location \n436\n and the final cutting element contact location \n438\n.', 'In the illustrated embodiment, the contact length \n440\n may be the distance between the downhole-most location where the directional pad \n416\n contacts the wall \n418\n and the center of the final active cutting element \n437\n-\n1\n.', 'In some embodiments, the contact length \n440\n may be in a range having a lower value, an upper value, or lower and upper values including any of 0.25 in.', '(0.6 cm), 0.5 in.', '(1.3 cm), 0.75 in.', '(1.9 cm), 1.0 in.', '(2.5 cm), 1.25 in.', '(3.2 cm), 1.5 in.', '(3.8 cm), 1.75 in.', '(4.4 cm), 2.0 in.', '(5.1 cm), 2.25 in.', '(5.7 cm), 2.5 (6.4 cm), 2.75 in.', '(7.0 cm), 3.0 in.', '(7.6 cm), 4.0 in.', '(10.2 cm), 5.0 in.', '(12.7 cm), 6.0 in.', '(15.2 cm), 7.0 in.', '(17.8 cm), 8.0 in.', '(20.3 cm), or any value therebetween.', 'For example, the contact length \n440\n may be greater than 0.25 in.', '(0.6 cm).', 'In other examples, the contact length \n440\n may be less than 8.0 in.', '(2.3 cm).', 'In still other examples, the contact length \n440\n may be any value in a range between 0.25 in.', '(0.6 cm) and 8.0 in.', '(2.3 cm).', 'In other examples, the contact length \n440\n may be less than 6.0 in.', '(15.2 cm).', 'In still other examples, the contact length \n440\n may be less than 3.0 in.', '(7.6 cm).', 'In at least some embodiments, contact lengths \n440\n of less than 3.0 in.', '(7.6 cm) may be critical to achieve a desired DLS increase of the directional drilling assembly \n412\n.', 'In some embodiments, the maximum DLS achievable by the directional drilling assembly \n412\n may be in a range having a lower value, an upper value, or lower and upper values including any of 1° per 100 ft. (30 m), 2° per 100 ft. (30 m), 3° per 100 ft. (30 m), 4° per 100 ft. (30 m), 5° per 100 ft. (30 m), 6° per 100 ft. (30 m), 7° per 100 ft. (30 m), 8° per 100 ft. (30 m), 9° per 100 ft. (30 m), 10° per 100 ft. (30 m), or any value therebetween.', 'Some analysis has further been done to show that the maximum DLS achievable by the directional assembly \n412\n may even exceed 10° per 100 ft. (30 m), and may even be up to 20° per 100 ft. (30 m), up to 25° per 100 ft. (30 m), up to 40° per 100 ft. (30 m), or even up to 60° per 100 ft. (30 m).', 'Accordingly, the maximum DLS may be greater than 1° per 100 ft. (30 m), greater than 10° per 100 ft. (30 m), greater than 20° per 100 ft. (30 m), greater than 30° per 100 ft. (30 m), or greater than 40° per 100 ft. (30 m).', 'In the same or other examples, the maximum DLS may be less than 60° per 100 ft. (30 m), less than 50° per 100 ft. (30 m), less than 40° per 100 ft. (30 m), less than 25° per 100 ft. (30 m), less than 20° per 100 ft. (30 m), or less than 10° per 100 ft. (30 m).', 'In still other examples, the maximum DLS may be any value in a range between 1° per 100 ft. (30 m) and 25° per 100 ft. (30 m), or any value in a range between 1° per 100 ft. (30 m) and 60° per 100 ft. (30 m).', 'Similar to the directional drilling assembly \n312\n of \nFIG.', '3\n, the directional drilling assembly \n412\n can include a directional pad \n416\n that extends a distance to have an overhang \n434\n relative to, and beyond, a downhole end \n432\n of a portion of the directional pad housing \n430\n.', 'The downhole end \n432\n is illustrated as downhole end of a portion of the directional pad housing \n430\n aligned with, supporting, or part of a second pad \n417\n.', 'The second pad \n417\n may be opposite the directional pad \n416\n (i.e., angularly offset by 180° in the illustrated embodiment); however, in other embodiments the second pad \n417\n may be offset from the directional pad \n416\n by less than 180° (e.g., 90° or 120°).', 'In some embodiments, an overhang distance \n448\n between the downhole end of the directional pad \n416\n and the downhole end \n432\n of the other portion of the directional pad housing \n430\n may be the same as, or less than, the distance \n442\n between the downhole end \n432\n and an uphole end of the drill bit \n410\n.', 'For instance, the overhang \n434\n may extend across an entirety of a shank portion of the bit connection \n428\n.', 'The shank portion of the bit connection \n428\n may remain outside the bit \n410\n when made-up to the drill bit \n410\n as described herein.', 'In these or other embodiments, the contact length \n440\n may be zero or close to zero (e.g., less than the diameter of the final active cutting element \n437\n-\n1\n).', 'In some embodiments, the contact length \n440\n may be a percentage of a connection distance \n442\n.', 'The connection distance \n442\n may be the distance between the downhole end \n432\n of the other portion of the directional pad housing \n430\n and the uphole end of the drill bit \n410\n.', 'In some embodiments, the connection length \n442\n corresponds to the length of the shank portion of the bit connection \n428\n.', 'The overhang distance \n448\n may be related to the connection length \n442\n by an overhang percentage.', 'In some embodiments, the overhang percentage (i.e., percentage of the overhang distance \n448\n to the connection length \n442\n) may be in a range having a lower value, an upper value, or lower and upper values including any of 10%, 25%, 40%, 50%, 60%, 70%, 80%, 90%, 95%, 100%, or any value therebetween.', 'For example, the overhang percentage may be greater than 10%.', 'In other examples, the overhang percentage may be less than 100%.', 'In still other examples, the overhang percentage may be any value in a range between 10% and 100%.', 'The bit \n410\n has a bit diameter, which may also be referred to as the gauge diameter.', 'The bit diameter is twice the bit radius \n450\n shown in \nFIG.', '4\n.', 'In some embodiments, the bit diameter may be any diameter used in drilling wellbores, including bit diameters between 4 in.', '(10.2 cm).', 'and 24 in.', '(61.0 cm).', 'In some embodiments, the bit diameter is between 6 in.', '(15.2 cm) and 13 in.', '(33.0 cm) or between 8 in.', '(20.3 cm) and 9 in.', '(22.9 cm).', 'A contact ratio can be defined as a ratio of the bit diameter to the contact length \n440\n.', 'For example, the contact ratio may be greater than 3:1.', 'In other examples, the contact ratio may be 4:1.', 'In still other examples, the contact ratio may be between 20:1 and 2:1.', 'For instance, the contact ratio may be 33:2, 10:1, 9:1, 17:2, 8:1, 35:6, 5:1, 9:2; 8:3, or any other combination of bit diameter to contact length \n440\n.', 'A higher contact ratio may, in some cases, increase the maximum DLS of the directional drilling assembly \n412\n.', 'The directional pad \n416\n of \nFIG.', '4\n has a pad radius \n452\n measured from the longitudinal axis \n446\n of the directional drilling assembly \n412\n.', 'In some embodiments, the pad radius \n452\n is equal to or greater than the bit radius \n450\n.', 'For instance, the pad radius \n452\n may be equal to the bit radius \n450\n.', 'In other embodiments, the pad radius \n452\n may be greater than the bit radius \n450\n.', 'For instance, the bit radius \n450\n may be a final active cutting element radius, and the pad radius \n452\n may be greater than the final active cutting element radius.', 'In some embodiments, the pad radius \n452\n is between 100% and 150%, between 100% and 120%, between 101% and 115%, or between 101% and 110% of the bit radius \n450\n.', 'Increasing the pad radius may increase the force applied to the wall \n418\n of the wellbore \n402\n during use, and a greater force applied to the wall \n418\n may increase the DLS of the directional drilling assembly \n412\n.', 'In some embodiments, the directional pad \n416\n may be radially fixed relative to the longitudinal axis \n446\n.', 'For instance, the directional pad \n416\n may be a fixed pad that does not extend, expand, or otherwise actuate, such that the pad radius \n452\n remains constant.', 'In the same or other embodiments, the second pad(s) \n417\n may also be fixed pads rather than extendable or actuatable pads.', 'In some embodiments, the bit \n410\n is rotated relative to the directional pad housing \n430\n by the downhole tool \n444\n.', 'For example, the downhole tool \n444\n may include a drive shaft such as a drive shaft from a downhole motor, such as a turbine or a positive displacement motor (e.g., a Moineau pump).', 'The directional pad housing \n430\n may maintain a desired a rotational orientation during drilling, including an orientation relative to the force of gravity, and/or an orientation relative to magnetic or true north.', 'For instance, the directional pad housing \n430\n may be used for slide drilling.', 'In some embodiments, the directional pad housing \n430\n and the directional pad \n416\n may be rotationally fixed relative to the longitudinal axis \n446\n.', 'In other embodiments, the directional pad housing \n430\n may be rotated, thereby changing the direction of the dog leg of the directional drilling assembly \n412\n.', 'In some embodiments, the directional pad \n416\n may be a singular directional pad \n416\n.', 'In other words, the directional pad housing \n430\n may have a single (e.g., only one) directional pad \n416\n.', 'Where the directional pad housing \n430\n has one or more directional pads \n416\n, the directional pad housing \n430\n may include one or more other or second pads \n417\n having a different configuration.', 'The second pads \n417\n may not materially contribute to the directional tendencies of the directional pad housing \n430\n.', 'For instance, the second pads \n417\n may have radial reach (and optionally reduced axial reach) relative to the directional pads \n416\n, such that the second pads \n417\n can act more like a stabilizer while the directional pad(s) \n416\n steer the directional drilling assembly \n412\n.', 'In some embodiments, the bit \n410\n may include a box connection \n454\n.', 'The box connection \n454\n may be a hollow portion inside of the bit \n410\n configured to connect to the downhole tool \n444\n at a pin connection coupled to the bit connection \n428\n.', 'In some examples, the box connection \n454\n and the bit connection \n428\n may connect via threads \n456\n, where the box connection \n454\n has the female end of the threaded connection \n456\n, and the bit connection \n428\n has the male end of the threaded connection \n456\n.', 'The threaded connection may be single shoulder connection, such as an API connection.', 'In some embodiments, the threaded connection is a double shoulder connection or premium connection, such as a proprietary connection or licensed connection.', 'When the drill bit \n410\n is made-up to the downhole tool \n444\n, fluid flowing through a central bore \n458\n of the downhole tool \n444\n (e.g., in the drive shaft) may flow into the drill bit \n410\n and through one or more ports or nozzles in the body of the drill bit \n410\n.', 'The threaded connection \n456\n may allow sufficient room in the drill bit body to allow the ports or nozzles that will provide total flow sufficient to clean and cool the cutting structure of the drill bit \n410\n while drilling formation.\n \nFIG.', '5\n is another cross-sectional view of an embodiment of a directional drilling assembly \n512\n.', 'In some embodiments, a directional pad \n516\n may contact or engage a wall \n518\n of a wellbore \n502\n at a pad contact location \n536\n.', 'A bit \n510\n has a plurality of cutting elements \n537\n, some of which are active cutting elements \n537\n which engage and remove formation \n501\n.', 'A final active cutting element \n537\n-\n1\n may be an uphole-most active cutting element \n537\n.', 'In other words, the final active cutting element \n537\n-\n1\n may be the furthest uphole active cutting element \n537\n of all active cutting elements \n537\n.', 'As shown in \nFIG. \n5\n, in at least some embodiments, the final active cutting element \n537\n-\n1\n may not be the furthest uphole cutting element \n537\n.', 'One or more inactive cutting elements \n537\n-\n2\n may be located uphole of the final active cutting element \n537\n-\n1\n.', 'In some embodiments, the one or more inactive cutting elements \n537\n-\n2\n may be located on the same blade as the final active cutting element \n537\n-\n1\n.', 'In other embodiments, the one or more inactive cutting elements \n537\n-\n2\n may be located on a different blade from the final active cutting element \n537\n-\n1\n.', 'Thus, as described above, a contact length \n540\n may be measured from the pad contact location \n536\n to a final active cutting element contact location \n538\n.\n \nFIG.', '6\n is a representation of a section of a directional drilling assembly \n612\n, according to at least one embodiment of the present disclosure.', 'A directional pad \n616\n may be located uphole of a bit \n610\n that includes a plurality of cutting elements.', 'In some embodiments, the plurality of cutting elements include an active gauge cutting element \n638\n and an active adjacent-to-gauge cutting element \n637\n.', 'The directional pad \n616\n optionally has an outermost surface at a pad radius \n652\n greater than that the gauge radius \n660\n at an outermost cutting tip of the active gauge cutting element \n638\n, as measured relative to a longitudinal axis \n646\n of the bit \n610\n.', 'Thus, a directional pad angle \n662\n may exist between the pad contact location \n636\n and the final cutting element contact location of the active gauge cutting element \n638\n, relative to the longitudinal axis \n646\n.', 'In some embodiments, the directional pad angle \n662\n may be in a range having a lower value, an upper value, or lower and upper values including any of 0.0°, 0.1°, 0.5°, 1.0°, 1.5°, 2.0°, 2.5°, 3.0°, 3.5°, 4.0°, 4.5°, 5.0°, or any value therebetween.', 'For example, the directional pad angle \n662\n taper radially inwardly from the directional pad \n616\n to the active gauge cutting element \n638\n at an angle greater than 0.0° and/or less than 5.0°.', 'In still other examples, the directional pad angle \n662\n may be any value in a range between and/or between and including 0.0° and 5.0°.', 'In other embodiments, the angle may be greater than 5.0°.', 'In some embodiments, relatively higher directional pad angles \n662\n may increase the DLS as compared to relatively smaller directional pad angles \n662\n that can decrease the DLS.', 'In some embodiments, the contact length \n640\n may be less than 3 in.', '(7.6 cm), and the directional pad angle \n662\n may be between 0.0° and 5.0° or between 0.5° and 3.5°.', 'The combination of contact length \n640\n and directional pad angle \n662\n may further increase the DLS and/or improve control over the accuracy or precision of the DLS.\n \nFIG.', '7\n is a representation of a section of a bit \n710\n, according to at least one embodiment of the present disclosure.', 'The bit \n710\n may include a plurality of cutting elements, including an active gauge cutting element(s) \n737\n-\n1\n and an active adjacent-to-gauge cutting element(s) \n737\n-\n2\n.', 'In \nFIG.', '7\n, the cutting elements \n737\n-\n1\n, \n737\n-\n2\n illustrate cutting element positions in a composite cutting profile in which all cutting elements are aligned in the same blade.', 'Thus, multiple discrete cutting elements can be located at a same cutting element position and would show as a single cutting element.', 'Where multiple cutting elements show as a single cutting element in the cutting profile view, the cutting element position is considered to have redundancy.', 'In some embodiments, the active gauge cutting element(s) \n737\n-\n1\n is located farther uphole than every other cutting element of the plurality of cutting elements (or farther uphole than every other active cutting element of the plurality of cutting elements), including the active adjacent-to-gauge cutting element(s) \n737\n-\n2\n.', 'The active adjacent-to-gauge cutting element(s) \n737\n-\n2\n are located farther uphole than every other cutting element of the plurality of cutting elements except the active gauge cutting element(s) \n737\n-\n1\n.', 'In some embodiments, an active gauge cutting element \n737\n-\n1\n and an active adjacent-to-gauge cutting element \n737\n-\n2\n are located on the same blade of the bit \n710\n.', 'In other embodiments, a blade may include one, but not both, of an active gauge cutting element \n737\n-\n1\n and an active adjacent-to-gauge cutting element \n737\n-\n2\n.', 'The active gauge cutting element \n737\n-\n1\n has a first cutting element radius \n764\n-\n1\n relative to a longitudinal axis \n746\n of the bit \n710\n.', 'The active adjacent-to-gauge cutting element \n737\n-\n2\n has a second cutting element radius \n764\n-\n2\n relative to the longitudinal axis \n746\n.', 'In some embodiments, the second cutting element radius \n764\n-\n2\n may be different than the first cutting element radius \n764\n-\n1\n.', 'In this manner, a cutting element angle \n766\n is formed between the first cutting element \n737\n-\n1\n and the second cutting element \n737\n-\n2\n.', 'In some embodiments, the cutting element angle \n766\n may be in a range having a lower value, an upper value, or lower and upper values including any of 0.05°, 0.1°, 0.5°, 1.0°, 1.5°, 2.0°, 2.5°, 3.0°, 3.5°, 4.0°, 4.5°, 5.0°, or any value therebetween.', 'For example, the cutting element angle \n766\n may be greater than 0.05°.', 'In other examples, the cutting element angle \n766\n may be less than 5.0°.', 'In still other examples, the cutting element angle \n766\n may be any value in a range between 0.0° and 5.0°, between 0.1° and 4°, or between 1° and 3°.', 'In some embodiments, the second cutting element radius \n764\n-\n2\n may be smaller than the first cutting element radius \n764\n-\n1\n.', 'Thus, a negative cutting element angle \n766\n is formed.', 'In other words, the gauge of the bit may have a negative, or inward, taper in a downhole direction.', 'A negative cutting element angle \n766\n may enable the upper cutting elements, on the gauge of a drill bit, to more fully engage the formation (e.g., formation \n301\n of \nFIG.', '3\n) when the directional pad (e.g., directional pad \n316\n of \nFIG.', '3\n) causes an increased force against one side of the bit \n710\n.', 'In some embodiments, the cutting element angle \n766\n may be the same as the directional pad angle (e.g., directional pad angle \n662\n of \nFIG.', '6\n).', 'This may further enable an even force distribution or cutting volume across multiple active cutting elements \n737\n-\n1\n, \n737\n-\n2\n as the bit \n710\n is pushed by the directional pad.', 'In other embodiments, the cutting element angle \n766\n may be greater than or less than the directional pad angle.\n \nFIG.', '8\n is a representation of an embodiment of a bit \n810\n.', 'The bit \n810\n may include a box connection \n854\n having a box length \n868\n.', 'In some embodiments, the box length \n868\n may be in a range having a lower value, an upper value, or lower and upper values including any of 0.5 in.', '(1.3 cm), 0.75 in.', '(1.9 cm), 1.0 in.', '(2.5 cm), 1.25 in.', '(3.2 cm), 1.5 in.', '(3.8 cm), 1.75 in.', '(4.5 cm), 2.0 in.', '(5.1 cm), 2.25 in.', '(5.7 cm), 2.5 in.', '(6.4 cm), 2.75 in.', '(7.0 cm), 3.0 in.', '(7.6 cm), 5.0 in.', '(12.7 cm), or any value therebetween.', 'For example, the box length \n868\n may be greater than 0.5 in.', '(1.3 cm).', 'In other examples, the box length \n868\n may be less than 3.0 in.', '(7.6 cm).', 'In still other examples, the box length \n868\n may be any value in a range between 0.5 in.', '(1.3 cm) and 5.0 in.', '(12.6 cm), or between 1.0 in.', '(2.5 cm) and 3.0 in.', '(7.6 cm).', 'The bit \n810\n has a bit diameter \n850\n.', 'In some embodiments, a bit ratio may be the ratio of the bit diameter \n850\n to the box length \n868\n.', 'In some embodiments, the bit ratio may be between 2.5 and 5.', 'For instance, the bit ratio may be 8.5:2 (17:4), 8:2.5 (16:5), 8.75:2.75 (35:11), 8.5:2.75 (34:11), 3:1, or any other ratio of bit diameter \n850\n to box length \n868\n.', 'In some embodiments, the bit ratio may be greater than 3:1 or less than 4.5:1.', 'In some embodiments, the box length \n868\n may be at least partially dependent on the bit diameter \n850\n.', 'A longer box length \n868\n may be stronger, and a larger bit diameter \n850\n may incur greater forces on the box connection \n854\n, thereby impacting the bit ratio.', 'In some embodiments, however, the type of formation (e.g., formation \n301\n of \nFIG.', '3\n) to be drilled through may affect the bit ratio.', 'In some embodiments, at least one cutting element \n837\n (e.g., an active cutting element) of the bit \n810\n may axially overlap the box connection \n854\n.', 'In other words, at an axial position along a longitudinal axis of the bit \n810\n, both a portion of the bod connection \n854\n and at least one cutting element \n837\n may be located.', 'Thus, a radius extending through at least one cutting element \n837\n may extend through a portion of the box connection \n854\n.', 'Although the bit diameter \n850\n is shown relative to the bit body, in other embodiments, the bit diameter \n850\n is measured in relation to the gauge diameter of the bit (i.e., based on the cutting tip of the cutting elements \n837\n).', 'FIG.', '9\n is a representation of a composite cutting profile \n970\n, according to at least one embodiment of the present disclosure.', 'The composite cutting profile \n970\n may be utilized in any of the bits described herein, specifically regarding the bits described in reference to \nFIG.', '3\n through \nFIG.', '8\n.', 'The composite cutting profile \n970\n is a representation of the radial and axial cutting position of each cutting element \n937\n on a bit (e.g., bit \n310\n of \nFIG.', '3\n).', 'The composite cutting profile \n970\n may include a final active cutting element \n937\n-\n1\n located in a gauge region of the bit.', 'In some embodiments, the final active cutting element \n937\n-\n1\n may engage and remove a volume of material on a path through the formation (e.g., the formation \n301\n of \nFIG.', '3\n) while the wellbore (e.g., wellbore \n302\n of \nFIG.', '3\n) is being advanced in a downhole direction.', 'The final active cutting element \n937\n-\n1\n (or cutting elements at the final active cutting element position \n937\n-\n1\n) may be further uphole than cutting elements \n937\n at any other cutting element position on the cutting profile \n970\n.', 'Thus, the final active cutting element(s) \n937\n-\n1\n may be located the farthest uphole of any cutting elements \n937\n.', 'The final active cutting element(s) \n937\n-\n1\n may not be a backreaming cutting element, or configured to cut primarily while the bit is being pulled out of the wellbore, or to merely maintain the gauge diameter cut by a cutting element that is in a farther downhole position.', 'Rather, the final active cutting element \n937\n-\n1\n may be configured to engage and cut a volume of the formation while the wellbore is advancing.', 'In some embodiments, the bit may include redundant or backup final active cutting elements \n937\n-\n1\n.', 'In some embodiments, a bit having multiple blades may have multiple, redundant cutting elements \n937\n located in the same radial and longitudinal position on each of two or more different blades.', 'Cutting elements \n937\n located in the same longitudinal position on different blades are redundant because they cut the same rotational path.', 'In this manner, placing multiple final active cutting elements \n937\n-\n1\n in the same radial and longitudinal position on multiple blades provides redundancy that can help improve the life of the final active cutting elements \n937\n-\n1\n, which may experience greater wear than other cutting elements, as they can each actively remove a reduced total volume.', 'As may be seen in the composite cutting profile \n970\n, if redundant or backup final active cutting elements \n937\n-\n1\n are placed on every blade of the bit (and if the blades do not include trailing cutters at other positions), none of the other cutting elements \n937\n may be at a position in the cutting profile \n970\n that overlaps the position of the final active cutting element \n937\n-\n1\n.', 'Placing redundant or backup final active cutting elements \n937\n-\n1\n on some but fewer than each of the blades (e.g., half, one-third, one-quarter, every other blade, and so forth), may allow some overlap of the positions of active cutting elements with the final active cutting element(s) \n937\n-\n1\n on the cutting profile \n970\n.\n \nFIG.', '10\n is a representation of a composite cutting profile \n1070\n, according to at least one embodiment of the present disclosure.', 'The composite cutting profile \n1070\n may be utilized in any of the bits described herein, specifically regarding the bits described in reference to \nFIG.', '3\n through \nFIG.', '8\n.', 'The composite cutting profile \n1070\n is a representation of the cutting path of each cutting element \n1037\n on a bit (e.g., bit \n310\n of \nFIG.', '3\n).', 'The composite cutting profile \n1070\n may include a first final active cutting element \n1037\n-\n1\n located in a gauge region of the bit.', 'The first final active cutting element \n1037\n-\n1\n may be the uphole-most active cutting element \n1037\n (or multiple first final active cutting elements \n1037\n-\n1\n).', 'A second final active cutting element \n1037\n-\n2\n actively engages and removes formation farther uphole than any other cutting element \n1037\n except the first final active cutting element(s) \n1037\n-\n1\n.', 'The first final active cutting element \n1037\n-\n1\n and the second final active cutting element \n1037\n-\n2\n may overlap in the cutting profile \n1070\n and may thus be located on different blades of the bit, or at leading and trailing positions on a single blade.', 'Thus, in at least some embodiments, the first final active cutting element \n1037\n-\n1\n and the second final active cutting element \n1037\n-\n2\n may have overlapping cutting paths.', 'In this manner, the cutting element angle (e.g., cutting element angle \n766\n) may be fine-tuned along a length of the bit.\n \nFIG.', '11\n illustrates an example assembly tool \n1171\n according to at least one embodiment of the present disclosure.', 'A motor, drive shaft, or bias unit connection \n1128\n may include a connection shoulder \n1172\n and a plurality of keyed features \n1174\n.', 'In some embodiments, the connection \n1128\n may include eight flats spaced around the outer surface of the connection \n1128\n, which flats cooperatively define a surface or connection feature allowing the assembly tool \n1171\n to hold the connection \n1128\n in place while a bit (e.g., bit \n310\n, \n410\n, \n510\n, \n610\n, \n710\n, \n810\n) can be rotated and secured thereto.', 'In other embodiments, the assembly tool \n1171\n can be used to rotate the connection \n1128\n while another suitable device holds the bit in place.', 'While the connection \n1128\n is shown as having eight flats that define the keyed features \n1174\n, the connection \n1128\n of the motor, drive shaft, or bias unit may have any suitable feature.', 'In other embodiments, for instance, the bit connection \n1128\n may include 1, 2, 3, 4, 5, 6, 7, or more than 8 flats or other keyed features \n1174\n.', 'In some embodiments, the keyed features may include protrusions, recesses, slots, or holes that can be engaged by the assembly tool.', 'Any suitable keyed features \n1174\n may be evenly spaced around a circumference of the connection \n1128\n.', 'In other embodiments, the keyed features \n1174\n may be unevenly spaced around the circumference of the connection \n1128\n.', 'For example, a larger slot or flat may correspond to a specific location on the assembly tool \n1171\n, thereby aligning the connection \n1128\n with the assembly tool \n1171\n.', 'The connection \n1128\n may be a pin connection that is coupled to a box connection (e.g., box connection \n454\n of \nFIG.', '4\n) of a bit (e.g., bit \n410\n of \nFIG.', '4\n).', 'The connection \n1128\n may be attached to, or part of, a downhole tool, such as a drive shaft from a downhole motor, such as a turbine or a positive displacement motor (e.g., a Moineau pump).', 'The downhole tool is optionally internal to, and rotatable relative to, a directional pad housing \n1130\n.', 'A directional pad \n1116\n (and optionally the portion of the directional pad housing \n1130\n supporting the directional pad \n1116\n) may extend past, or overhang, the downhole end (e.g., downhole end \n432\n of \nFIG.', '4\n) of the directional pad housing \n1130\n.', 'In some embodiments, the directional pad \n1116\n (and optionally the portion of the directional pad housing \n1130\n supporting the directional pad \n1116\n) may extend over one or more of the plurality of keyed features \n1174\n and/or the connection shoulder \n1172\n.', 'The connection \n1128\n may include a threaded connection \n1156\n, which may connect to corresponding threads on a bit.', 'To securely fasten the bit to the connection \n1128\n via the threaded connection \n1156\n, the bit is rotated relative to the bit connection \n1128\n (or vice versa).', 'The assembly tool \n1171\n may clamp onto the connection \n1128\n to restrict or even prevent the drive shaft or other downhole tool from rotating while the bit is fastened to the connection \n1128\n.', 'In the illustrated embodiment, the assembly tool has an upper portion \n1176\n and a lower portion \n1178\n.', 'The upper portion \n1176\n and the lower portion \n1178\n may have generally U-shaped radial cross-sectional areas to clamp around the connection \n1128\n.', 'The upper portion \n1176\n may have an upper cut-out \n1180\n that mates with a portion of one or more of the directional pad \n1116\n, the directional pad housing \n1130\n, or the keyed features \n1174\n.', 'For instance, the upper cut-out \n1180\n may be sized to pass over the connection \n1128\n and the directional pad \n1116\n.', 'One or more portions of the upper cut-out \n1180\n may then be sized and position to restrict rotation of the directional pad \n1116\n or directional pad housing \n1130\n when positioned as shown in \nFIG.', '11\n.', 'The lower portion \n1178\n may have a lower cut-out \n1182\n sized to connect to the connection \n1128\n at the plurality of keyed features \n1174\n.', 'The lower cut-out \n1182\n may include one or more protrusions or engaging surfaces sized to mate, engage, or interlock with one or more of the plurality of keyed features \n1174\n.', 'In some embodiments, the lower cut-out \n1182\n may include an indentation for a second pad (e.g., second pad \n417\n of \nFIG.', '4\n) that may be supported by the directional pad housing \n1130\n.', 'The upper portion \n1176\n and the lower portion \n1178\n may connect at an interface \n1184\n.', 'The interface \n1184\n may be used to clamp or otherwise secure the upper portion \n1176\n and the lower portion \n1178\n together (e.g., with a compressive force).', 'The interface \n1184\n may be a bolted connection, a threaded connection, or any other connection or interface that aligns or secures the upper portion \n1176\n to the lower portion \n1178\n in the closed configuration shown in \nFIG.', '11\n.', 'In other words, when the interface \n1184\n is used to secure the upper portion \n1176\n to the lower portion \n1178\n, the assembly tool \n1171\n clamps to the connection \n1128\n over the directional pad \n1116\n.', 'In this manner, with the one or more engaging surfaces of the lower portion \n1178\n mating or interlocking with one or more of the keyed features \n1174\n, and potentially the surfaces of the upper cut-out \n1180\n restricting rotation of the directional pad \n1116\n, the connection \n1128\n is rotationally fixed relative to the assembly tool \n1171\n.', 'Thus, a bit may be attached and tightened to the connection \n1128\n using the assembly tool \n1171\n to provide a counter-rotation force.', 'FIGS.', '12\n-\n1\n and \n12\n-\n2\n illustrate another example assembly tool \n1271\n according to at least one embodiment of the present disclosure.', 'A motor, drive shaft, or bias unit connection \n1228\n may include a plurality of keyed features \n1274\n.', 'A shoulder may also be included as shown in \nFIG.', '11\n, but is optional and may not be included in some embodiments.', 'In some embodiments, the connection \n1228\n includes two slots spaced around the outer surface of the connection \n1228\n, which slots cooperatively define a surface or connection feature allowing the assembly tool \n1271\n to hold the connection \n1228\n in place while a bit \n1210\n can be rotated and secured thereto, or rotated around the bit \n1210\n while the bit \n1210\n is held in place.', 'In contrast to the flats \n1174\n shown in \nFIG. \n11\n, the slots \n1274\n may be deeper, and allow the application of higher torque.', 'Further, in some embodiments, one or more flats or other surfaces may also be provided on the connection \n1228\n along with the slots \n1274\n.', 'In \nFIG. \n12\n-\n2\n, for instance, two slots and four flats may be seen, although any suitable number of slots, flats, or the like can be used.', 'Accordingly, as described herein, any suitable keyed features \n1274\n may be used, and may include one keyed feature, or multiple keyed features evenly or unevenly spaced around a circumference of the connection \n1228\n.', 'The connection \n1228\n may be a pin connection that is coupled to a box connection (e.g., box connection \n454\n of \nFIG.', '4\n) of the bit \n1210\n.', 'The connection \n1228\n may be attached to, or part of, a downhole tool, such as a drive shaft from a downhole motor, such as a turbine or a positive displacement motor.', 'The downhole tool is optionally internal to, and rotatable relative to, a directional pad housing \n1230\n.', 'A directional pad \n1216\n (and optionally the portion of the directional pad housing \n1230\n supporting the directional pad \n1216\n) may extend past, or overhang, the downhole end (e.g., downhole end \n432\n of \nFIG.', '4\n) of the directional pad housing \n1230\n, as described herein.', 'In some embodiments, the directional pad \n1216\n (and optionally the portion of the directional pad housing \n1230\n supporting the directional pad \n1216\n) extends at least partially over, and is axially aligned with, one or more of the plurality of keyed features \n1274\n, flats, and/or the connection shoulder or pin connection of the connection \n1228\n.', 'The connection \n1228\n may include a threaded connection, which may connect to corresponding threads on the bit \n1210\n.', 'To securely fasten the bit \n1210\n to the connection \n1228\n via the threaded connection, the bit \n1210\n is rotated relative to the bit connection \n1228\n (or vice versa).', 'The assembly tool \n1271\n may fit around the connection \n1228\n, and optionally into the keyed features \n1274\n, to restrict or even prevent the drive shaft or other downhole tool from rotating while the bit \n1210\n is fastened to the connection \n1228\n.', 'In the illustrated embodiment, the assembly tool has an outer portion \n1276\n and an inner portion \n1278\n.', 'The inner portion \n1278\n may fit within the outer portion \n1276\n, and is optionally rotationally secured therein using one or more pins \n1279\n or other fasteners.', 'In some embodiments, there may be a single portion, rather than separate inner and outer portions \n1276\n, \n1278\n.', 'As further shown, one or more openings \n1280\n may be formed in the outer portion \n1276\n and optionally the inner portion \n1278\n.', 'These openings may be used as a grip so that the assembly tool \n1271\n can be held in place.', 'Of course, other mechanisms such as grips, keyed features, or the like may be used to otherwise hold the assembly tool \n1271\n in place.', 'The inner portion \n1278\n may have a cut-out \n1280\n that mates with a portion of one or more of the directional pad \n1216\n, the directional pad housing \n1230\n, or even keyed features (e.g., flats) of the connection \n1228\n.', 'For instance, the cut-out \n1280\n may be sized to pass over the connection \n1228\n and the directional pad \n1216\n.', 'One or more portions of the cut-out \n1280\n may then be sized and position to restrict rotation of the directional pad \n1216\n or directional pad housing \n1230\n when positioned as shown in \nFIG.', '12\n-\n2\n.', 'The inner portion \n1278\n may also have an engagement portion \n1282\n sized to connect to the connection \n1228\n at the plurality of slots \n1274\n.', 'The engagement portion \n1282\n may include one or more protrusions or engaging surfaces sized to mate, engage, fit within, or interlock with one or more of the plurality of keyed features \n1274\n.', 'In some embodiments, the inner portion \n1278\n may be symmetrical, or otherwise include a second cut-out \n1280\n.', 'The second cut-out \n1280\n may provide an opening for a second pad that may be supported by the directional pad housing \n1230\n.', 'In this manner, with the one or more engaging features \n1282\n (e.g., tabs) of the inner portion \n1278\n mating or interlocking with one or more of the keyed features \n1274\n, and potentially the surfaces of the cut-out \n1280\n restricting rotation of the directional pad \n1216\n, the connection \n1228\n is rotationally fixed relative to the assembly tool \n1271\n.', 'Thus, the bit \n1210\n may be attached and tightened to the connection \n1228\n using the assembly tool \n1271\n to provide a counter-rotation force.', 'The embodiments of the downhole directional drilling tool have been primarily described with reference to wellbore drilling operations; the downhole directional drilling tool described herein may be used in applications other than the drilling of a wellbore.', 'In other embodiments, downhole directional drilling tool according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources.', 'For instance, downhole directional drilling tool of the present disclosure may be used in a borehole used for placement of utility lines.', 'Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.', 'One or more specific embodiments of the present disclosure are described herein.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'The articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements in the preceding descriptions.', 'It should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, to simplify the discussion herein, some features are described with respect to particular embodiments.', 'However, any features that are not mutually exclusive can be combined or interchanged.', 'For instance, features of \nFIGS.', '3\n-\n5\n are interchangeable.', 'Additionally, any other elements described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'For instance, the cutting profiles of any of \nFIGS.', '6\n, \n7\n, \n9\n, and \n10\n may be defined by any of the bits of \nFIG.', '3\n-\n5\n or \n8\n.', 'Similarly, the bit of \nFIG.', '8\n may be used in any of the downhole tools of \nFIGS.', '3\n-\n5\n.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'The scope of the disclosure is, therefore, indicated by the appended claims rather than by the foregoing description.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.']

['1.', 'A downhole tool, comprising:\na directional pad configured to contact a wellbore wall at a pad contact location; and\na drill bit comprising a longitudinal axis and having at least one active cutting element, the at least one active cutting element contacting the wellbore wall at a cutting element contact location, a contact length between the cutting element contact location and the pad contact location being up to 3 in.', '(7.6 cm), wherein the at least one active cutting element comprises one or more active cutting elements at a first position that is further uphole than every other active cutting element of the at least one active cutting element; and\na directional pad angle between the pad contact location and the at least one active cutting element relative to the longitudinal axis, the directional pad angle being greater than 0° and less than or equal to 5°.', '2.', 'The downhole tool of claim 1, the drill bit having a bit diameter between 8 in.', '(20.3 cm) and 9 in (22.9 cm).', '3.', 'The downhole tool of claim 2, a contact ratio of the bit diameter to the contact length being greater than 3:1.\n\n\n\n\n\n\n4.', 'The downhole tool of claim 1, the drill bit being rotatable relative to the directional pad.\n\n\n\n\n\n\n5.', 'The downhole tool of claim 1, the directional pad being over-gauge relative to the bit, and the downhole tool having only one directional over-gauge pad.\n\n\n\n\n\n\n6.', 'The downhole tool of claim 1, the directional pad being coupled to a first portion of a directional pad housing, the directional pad extending longitudinally past a downhole end of a second portion of the directional pad housing.', '7.', 'The downhole tool of claim 1, the directional pad being coupled to a directional tool, and the drill bit including a box connection coupled to a pin connection of the directional tool, wherein the at least one active cutting element axially overlaps the box connection.', '8.', 'A downhole tool, comprising:\na housing;\na directional pad coupled to the housing and configured to contact a wellbore wall at a pad contact location; and\na drill bit comprising a longitudinal axis and having at least one active cutting element and a bit diameter, a contact ratio of a diameter of the bit to a contact length between the at least one active cutting element and the contact location being greater than 3:1, wherein the at least one active cutting element is positioned at a first position located further uphole than every other active cutting element of the at least one cutting element that is not at the first position; and\na directional pad angle between the pad contact location and the at least one cutting element relative to the longitudinal axis, the directional pad angel being greater than 0° and less than or equal to 5°.\n\n\n\n\n\n\n9.', 'The downhole tool of claim 8, the contact ratio being between 3:1 and 8.5:1.\n\n\n\n\n\n\n10.', 'The downhole tool of claim 8, further comprising a downhole motor including a drive shaft;\nwherein the drill bit comprises a box connection coupled to a pin connection of the downhole motor, and the at least one active cutting element axially overlaps the box connection;\nwherein the downhole tool comprises a directional pad housing coupled to the directional pad, and the drive shaft is internal to the directional pad housing.', '11.', 'The downhole tool of claim 10, the box connection having a box length, a bit ratio between a drill bit diameter and the box length being between 8.75:3 and 8.5:2.\n\n\n\n\n\n\n12.', 'The downhole tool of claim 8, the at least one active cutting element including at least one gauge cutting element, the directional pad having a pad radius greater than a cutting element radius of the at least one gauge cutting element.', '13.', 'The downhole tool of claim 8, comprising one or more second pads coupled to or integral with the housing, the one or more second pads each being angularly offset from the directional pad, wherein the directional pad has a greater radius and extends farther in a downhole direction than each of the one or more second pads.', '14.', 'The downhole tool of claim 8, the directional pad being radially fixed relative to a longitudinal axis of the downhole tool.', '15.', 'The downhole tool of claim 8, the directional pad being coupled to a first portion of the housing having a first downhole end, and extending longitudinally past a second downhole end of the housing that is between 120° and 180° offset from the first portion of the housing.', '16.', 'A downhole tool, comprising:\na directional pad configured to contact a wellbore wall at a contact location; and\na drill bit having a longitudinal axis, the drill bit including: a plurality of active cutting elements, including: at least one first active cutting element located at a first position farther uphole than a position of every other active cutting element of the plurality of active cutting element elements not at the first position, a directional pad angle between the contact location and the first active cutting element relative to the longitudinal axis being greater than 0° and less than or equal to 5°; and a second active cutting element located at a second position farther uphole than every other active cutting element of the plurality of active cutting elements except those at the first position, an active cutting element angle between the first active cutting element and the second active cutting element relative to the longitudinal axis being greater than 0° and less than or equal to 5°.\n\n\n\n\n\n\n17.', 'The downhole tool of claim 16, a contact length between the contact location and the first active cutting element being up to 3 in.', '(7.6 cm).', '18.', 'The downhole tool of claim 16, the drill bit having a bit diameter and a ratio between the bit diameter and a contact length between the first active cutting element and the contact location being greater than 3:1.\n\n\n\n\n\n\n19.', 'The downhole tool of claim 16, the directional pad being coupled to a directional pad housing, the directional pad having an overhang relative to the directional pad housing.']

['FIG.', '1 is a representation of a drilling system, according to at least one embodiment of the present disclosure;; FIG.', '2', 'is a representation of a prior art directional drilling system;; FIG.', '3 is a representation of a directional drilling system, according to at least one embodiment of the present disclosure;; FIG. 4 is a cross-sectional view of a directional drilling system, according to at least one embodiment of the present disclosure;; FIG.', '5 is another cross-sectional view of a directional drilling system, according to at least one embodiment of the present disclosure;; FIG.', '6 is a partial side view of a bit, according to at least one embodiment of the present disclosure;; FIG. 7 is another partial side view of a bit, according to at least one embodiment of the present disclosure;; FIG. 8 is side view of a bit, according to at least one embodiment of the present disclosure;; FIG.', '9 is a representation of a composite cutting profile, according to at least one embodiment of the present disclosure;; FIG.', '10 is another representation of a composite cutting profile, according to at least one embodiment of the present disclosure;; FIG.', '11 is a side view of an assembly tool usable to connect a drive shaft to a drill bit, according to at least one embodiment of the present disclosure;; FIG.', '12-1 is a perspective view of another assembly tool usable to connect a drive shaft to a drill bit, according to at least one embodiment of the present disclosure; and; FIG.', '12-2 is a perspective view of the assembly tool of FIG.', '12-1, with the drill bit removed.', '; FIG.', '1 shows one example of a drilling system 100 for drilling an earth formation 101 to form a wellbore 102.', 'The drilling system 100 includes a drill rig 103 used to turn a drilling tool assembly 104 which extends downward into the wellbore 102.', 'The drilling tool assembly 104 may include a drill string 105, a bottomhole assembly (“BHA”) 106, and a bit 110, attached to the downhole end of drill string 105.; FIG.', '2 is a representation of a prior art directional drilling assembly 212 including a bit 210.', 'The bit 210 may be connected to a directional drilling sub 214 having one or more selectively directional pads 216 configured to contact a wall 218 of the wellbore 202.', 'The directional pads may be expandable, such as where the directional drilling sub 214 is a rotary steerable system.', 'As the directional pads 216 selectively expand and contact the wall 218, the bit 210 experiences a greater force at a bit contact location 224 on an opposite side of the wall 218, thereby forcing a radial deflection, or dog leg, of the wellbore 202.', 'The bit 210 is stabilized by a contact of the stabilizer 220 with the wall 218 at a stabilizer contact location, thereby encouraging a consistent radial deflection, or dog leg severity (DLS).', 'The DLS is increased the closer the directional pads 216 are located to the bit contact location 224.', 'In the shown directional drilling assembly 212 (e.g., including a rotary steerable system), the internal structural mechanics of selectively extending the directional pads 216 limits how close to the bit 210 the directional pads 216 may be placed.', 'As shown, the distance between the directional pads 216 and the bit contact location 224 is large.', 'For example, as shown the distance between the directional pads 216 and the bit contact location 224 is greater than 12 in.', '(30.5 cm).', '; FIG.', '3 is a representation of an embodiment of a directional drilling assembly 312.', 'A bit 310 may be connected to a directional drilling sub 314 with a bit connection 328.', 'A directional pad 316 may be connected to a downhole end of the directional drilling sub 314.', 'The directional pad 316 may be located or housed in directional pad housing 330 located on the directional drilling sub 314.', 'In some embodiments, the directional pad 316 (and optionally the portion of the directional pad housing 330 supporting the directional pad 316) may be located on or toward the lower end of the directional drilling sub 314, and may extend past a downhole end 332 of the directional pad housing 330 and/or the directional drilling sub 314.', 'In particular, a distance referred to as an overhang 334 is shown as the distance the directional pad 316 (and/or associated portion of the directional pad housing 330) extends past, or overhangs, the downhole end 332 of another portion of the directional pad housing 330.; FIG.', '4 is a cross-sectional view of an embodiment of a portion of a directional drilling assembly 412.', 'In some embodiments, the directional drilling assembly 412 may be an enlarged view of a portion of the directional drilling assembly 312 of FIG.', '3.; FIG.', '5 is another cross-sectional view of an embodiment of a directional drilling assembly 512.', 'In some embodiments, a directional pad 516 may contact or engage a wall 518 of a wellbore 502 at a pad contact location 536.', 'A bit 510 has a plurality of cutting elements 537, some of which are active cutting elements 537 which engage and remove formation 501.', 'A final active cutting element 537-1 may be an uphole-most active cutting element 537.', 'In other words, the final active cutting element 537-1 may be the furthest uphole active cutting element 537 of all active cutting elements 537.', 'As shown in FIG.', '5, in at least some embodiments, the final active cutting element 537-1 may not be the furthest uphole cutting element 537.', 'One or more inactive cutting elements 537-2 may be located uphole of the final active cutting element 537-1.', 'In some embodiments, the one or more inactive cutting elements 537-2 may be located on the same blade as the final active cutting element 537-1.', 'In other embodiments, the one or more inactive cutting elements 537-2 may be located on a different blade from the final active cutting element 537-1.', 'Thus, as described above, a contact length 540 may be measured from the pad contact location 536 to a final active cutting element contact location 538.; FIG.', '6 is a representation of a section of a directional drilling assembly 612, according to at least one embodiment of the present disclosure.', 'A directional pad 616 may be located uphole of a bit 610 that includes a plurality of cutting elements.', 'In some embodiments, the plurality of cutting elements include an active gauge cutting element 638 and an active adjacent-to-gauge cutting element 637.', 'The directional pad 616 optionally has an outermost surface at a pad radius 652 greater than that the gauge radius 660 at an outermost cutting tip of the active gauge cutting element 638, as measured relative to a longitudinal axis 646 of the bit 610.', 'Thus, a directional pad angle 662 may exist between the pad contact location 636 and the final cutting element contact location of the active gauge cutting element 638, relative to the longitudinal axis 646.', 'In some embodiments, the directional pad angle 662 may be in a range having a lower value, an upper value, or lower and upper values including any of 0.0°, 0.1°, 0.5°, 1.0°, 1.5°, 2.0°, 2.5°, 3.0°, 3.5°, 4.0°, 4.5°, 5.0°, or any value therebetween.', 'For example, the directional pad angle 662 taper radially inwardly from the directional pad 616 to the active gauge cutting element 638 at an angle greater than 0.0° and/or less than 5.0°.', 'In still other examples, the directional pad angle 662 may be any value in a range between and/or between and including 0.0° and 5.0°.', 'In other embodiments, the angle may be greater than 5.0°.', 'In some embodiments, relatively higher directional pad angles 662 may increase the DLS as compared to relatively smaller directional pad angles 662 that can decrease the DLS.; FIG.', '7 is a representation of a section of a bit 710, according to at least one embodiment of the present disclosure.', 'The bit 710 may include a plurality of cutting elements, including an active gauge cutting element(s) 737-1 and an active adjacent-to-gauge cutting element(s) 737-2.', 'In FIG.', '7, the cutting elements 737-1, 737-2 illustrate cutting element positions in a composite cutting profile in which all cutting elements are aligned in the same blade.', 'Thus, multiple discrete cutting elements can be located at a same cutting element position and would show as a single cutting element.', 'Where multiple cutting elements show as a single cutting element in the cutting profile view, the cutting element position is considered to have redundancy.; FIG. 8 is a representation of an embodiment of a bit 810.', 'The bit 810 may include a box connection 854 having a box length 868.', 'In some embodiments, the box length 868 may be in a range having a lower value, an upper value, or lower and upper values including any of 0.5 in.', '(1.3 cm), 0.75 in.', '(1.9 cm), 1.0 in.', '(2.5 cm), 1.25 in.', '(3.2 cm), 1.5 in.', '(3.8 cm), 1.75 in.', '(4.5 cm), 2.0 in.', '(5.1 cm), 2.25 in.', '(5.7 cm), 2.5 in.', '(6.4 cm), 2.75 in.', '(7.0 cm), 3.0 in.', '(7.6 cm), 5.0 in.', '(12.7 cm), or any value therebetween.', 'For example, the box length 868 may be greater than 0.5 in.', '(1.3 cm).', 'In other examples, the box length 868 may be less than 3.0 in.', '(7.6 cm).', 'In still other examples, the box length 868 may be any value in a range between 0.5 in.', '(1.3 cm) and 5.0 in.', '(12.6 cm), or between 1.0 in.', '(2.5 cm) and 3.0 in.', '(7.6 cm).', '; FIG.', '9 is a representation of a composite cutting profile 970, according to at least one embodiment of the present disclosure.', 'The composite cutting profile 970 may be utilized in any of the bits described herein, specifically regarding the bits described in reference to FIG.', '3 through FIG.', '8.', 'The composite cutting profile 970 is a representation of the radial and axial cutting position of each cutting element 937 on a bit (e.g., bit 310 of FIG. 3).', 'The composite cutting profile 970 may include a final active cutting element 937-1 located in a gauge region of the bit.', 'In some embodiments, the final active cutting element 937-1 may engage and remove a volume of material on a path through the formation (e.g., the formation 301 of FIG.', '3) while the wellbore (e.g., wellbore 302 of FIG.', '3) is being advanced in a downhole direction.', 'The final active cutting element 937-1 (or cutting elements at the final active cutting element position 937-1) may be further uphole than cutting elements 937 at any other cutting element position on the cutting profile 970.', 'Thus, the final active cutting element(s) 937-1 may be located the farthest uphole of any cutting elements 937.', 'The final active cutting element(s) 937-1 may not be a backreaming cutting element, or configured to cut primarily while the bit is being pulled out of the wellbore, or to merely maintain the gauge diameter cut by a cutting element that is in a farther downhole position.', 'Rather, the final active cutting element 937-1 may be configured to engage and cut a volume of the formation while the wellbore is advancing.; FIG.', '10 is a representation of a composite cutting profile 1070, according to at least one embodiment of the present disclosure.', 'The composite cutting profile 1070 may be utilized in any of the bits described herein, specifically regarding the bits described in reference to FIG.', '3 through FIG.', '8.', 'The composite cutting profile 1070 is a representation of the cutting path of each cutting element 1037 on a bit (e.g., bit 310 of FIG. 3).', 'The composite cutting profile 1070 may include a first final active cutting element 1037-1 located in a gauge region of the bit.', 'The first final active cutting element 1037-1 may be the uphole-most active cutting element 1037 (or multiple first final active cutting elements 1037-1).', 'A second final active cutting element 1037-2 actively engages and removes formation farther uphole than any other cutting element 1037 except the first final active cutting element(s) 1037-1.; FIG.', '11 illustrates an example assembly tool 1171 according to at least one embodiment of the present disclosure.', 'A motor, drive shaft, or bias unit connection 1128 may include a connection shoulder 1172 and a plurality of keyed features 1174.', 'In some embodiments, the connection 1128 may include eight flats spaced around the outer surface of the connection 1128, which flats cooperatively define a surface or connection feature allowing the assembly tool 1171 to hold the connection 1128 in place while a bit (e.g., bit 310, 410, 510, 610, 710, 810) can be rotated and secured thereto.', 'In other embodiments, the assembly tool 1171 can be used to rotate the connection 1128 while another suitable device holds the bit in place.; FIGS.', '12-1 and 12-2 illustrate another example assembly tool 1271 according to at least one embodiment of the present disclosure.', 'A motor, drive shaft, or bias unit connection 1228 may include a plurality of keyed features 1274.', 'A shoulder may also be included as shown in FIG.', '11, but is optional and may not be included in some embodiments.']

US11662334

Tracking and estimating tubing fatigue in cycles to failure considering non-destructive evaluation of tubing defects

Jan 31, 2022

Zhanke Liu, Linyuan Yang, Gregory Campbell, Rujuta Marathe

SCHLUMBERGER TECHNOLOGY CORPORATION

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['A technique facilitates tracking and assessing a fatigue life of a tubing string utilizing, for example, estimation of cycles to failure when used in a wellbore operation.', 'The technique may comprise initially determining a fatigue life of a tubing string.', 'Additionally, the technique comprises utilizing a sensing device, e.g. a magnetic flux leakage (MFL) device, to monitor the tubing string.', 'When an anomaly, e.g. a new defect, is detected by the sensing device, a new fatigue life of the tubing string is determined based on the change.', 'The new fatigue life may be used to estimate a fatigue life in terms of cycles to failure.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'The present document is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/310,427, filed Mar. 18, 2016, which is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nCoiled tubing technology has been used in an expanding range of applications since its introduction to the oil industry in the 1960s.', 'The wide array of tools and technologies that can be used in cooperation with coiled tubing and the ability of coiled tubing to pass through completion tubulars makes the technology very versatile.', 'A coiled tubing system may include surface pumping facilities, a coiled tubing string mounted on a reel, an injector head or other mechanism to convey the coiled tubing into and out of the wellbore, and a surface control apparatus at the wellhead.', 'The coiled tubing may be deployed in wellbores to facilitate performance of well treatment and/or well intervention operations, e.g. operations comprising hydraulic fracturing, matrix acidizing, milling, perforating, coiled tubing drilling, or other downhole operations.', 'SUMMARY', 'In general, the present disclosure provides a methodology and system for tracking and assessing a fatigue life of a tubing string utilizing, for example, estimation of cycles to failure when used in a wellbore operation.', 'According to an embodiment, the technique comprises determining a fatigue life of a tubing string, e.g. a coiled tubing string, and utilizing a sensing device, e.g. a magnetic flux leakage (MFL) device, to monitor the tubing string.', 'When an anomaly, e.g. a new defect, is detected by the sensing device, a new fatigue life of the tubing string is determined based on the anomaly.', 'The new fatigue life may be used to estimate a fatigue life in terms of cycles to failure.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is a schematic illustration of an example of a pipe defect assessment system for evaluating pipe, e.g. coiled tubing, according to an embodiment of the disclosure;\n \nFIG.', '2\n is a schematic illustration of a processor-based system for evaluating sensor data in combination with stored historical data, thus enabling accurate estimation of cycles to failure, according to an embodiment of the disclosure;\n \nFIG.', '3\n is a graphical representation illustrating data regarding fatigue life of a pipe versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '4\n is a graphical representation illustrating data regarding nominal wall thickness of a pipe versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '5\n is a graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '6\n is another graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '7\n is another graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '8\n is another graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '9\n is a graphical representation illustrating data regarding consumed fatigue life versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '10\n is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '11\n is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '12\n is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure;\n \nFIG.', '13\n is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure; and\n \nFIG.', '14\n is a graphical representation illustrating data regarding estimated trips to failure versus depth of the pipe, according to an embodiment of the disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some illustrative embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'The disclosure herein generally relates to a methodology and system for tracking and assessing a fatigue life of a pipe string, e.g. a coiled tubing string.', 'According to an embodiment, the technique may be used to provide accurate estimation of cycles to failure, e.g. trips downhole until failure, when the pipe string is used in, for example, a wellbore operation.', 'The technique comprises determining a fatigue life of a coiled tubing string based on historical data which may be stored on a processing device, e.g. a computer, or other suitable device.', 'A sensing device, e.g. a magnetic flux leakage (MFL) device, also is used to monitor the coiled tubing string.', 'When an anomaly, e.g. a new defect, is detected by the sensing device, a new fatigue life of the coiled string is determined based on stored data regarding the anomaly.', 'Data on fatigue life, anomaly type, and updated fatigue life may be processed to determine an accurate estimate of fatigue life in cycles and/or trips to failure.', 'The estimate information may then be output to enable evaluation regarding future use of the pipe string.', 'Accordingly, embodiments described herein may be used as a method of tracking coiled tubing fatigue with incorporation of the concept of cycles to failure.', 'This new approach to fatigue tracking provides more direct assessment to end users regarding the fitness of the coiled tubing string for service as compared to traditional methods of percentage fatigue life tracking.', 'Embodiments utilize sensor data, e.g. MFL inspection data, to estimate a reduction in cycles to failure due to anomalies, such as changes which occur to the tubing string.', 'Examples of anomalies which can affect the number of cycles to failure include localized defects, wall thinning, ballooning, and a variety of other anomalies.', 'Referring generally to \nFIG.', '1\n, an example of a pipe tracking system \n20\n for evaluating pipe \n22\n, e.g. jointed pipe or coiled tubing, is illustrated.', 'It should be noted that the embodiments described herein may be employed in well or non-well related applications.', 'Additionally, the pipe tracking system \n20\n may comprise a variety of pipe support systems, pipe delivery systems, sensor arrangements, local and/or remote processing systems, data evaluation algorithms, models, and/or other software programs, as well as other components arranged in various configurations depending on the parameters of a pipe damage assessment application.', 'In \nFIG.', '1\n, an embodiment of the pipe tracking system \n20\n is in the form of a coiled tubing tracking system.', 'Additionally, the pipe \n22\n is illustrated in the form of coiled tubing \n22\n which moves relative to an appropriate sensor device having a sensor or sensors \n24\n.', 'In embodiments described herein, the sensor or sensors \n24\n may comprise magnetic flux leakage (MFL) sensors which monitor magnetic flux leakage.', 'The relative movement of coiled tubing \n22\n is indicated by arrow \n26\n, however some embodiments may be constructed to move the sensor or sensors \n24\n along a stationary pipe \n22\n.', 'Additionally, both the pipe \n22\n and the sensor(s) \n24\n may be moved to cause the relative movement with respect to each other.', 'Each sensor \n24\n may be positioned to monitor for the presence of a magnetic flux leakage signal associated with an anomaly \n28\n, e.g. a defect, and to output sensor data to a data processing system \n30\n.', 'The signals provided by sensor \n24\n change upon detection of the differing magnetic flux leakage signal associated with the defect \n28\n or other anomaly.', 'The changes in that sensor data can be processed via data processing system \n30\n to, for example, quantify defect shape, size, and/or severity which can then be used in combination with other data to estimate a fatigue life, e.g. a cycles to failure, with respect to the coiled tubing or other pipe \n22\n.', 'The presence of an anomaly on coiled tubing \n22\n affects its mechanical integrity by, for example, reducing its tensile load capacity or reducing its pressure containment capacity, thus reducing the number of cycles until failure of the coiled tubing occurs.', 'The cycles to failure may be diminished because the presence of a defect often acts as a stress riser which can lead to development of fatigue cracking in coiled tubing or other pipe.', 'However, changes in wall thickness, ballooning, or other anomalies also can reduce the cycles to failure relative to the determined fatigue life of the coiled tubing without the presence of the anomaly or anomalies.', 'By utilizing the sensor or sensors \n24\n, magnetic flux leakage changes may be monitored to determine whether the magnetic flux leakage signal, e.g. MFL signature, begins to indicate characteristics associated with an anomaly able to reduce the cycles to failure.', 'The magnetic flux leakage signal data is relayed from the sensor \n24\n to the data processing system \n30\n for evaluation, as described in greater detail below.', 'The sensor(s) \n24\n may be used at a wellsite or at an off-site facility for testing pipe \n22\n.', 'For example, the sensor(s) \n24\n may be used in a wellbore operation as coiled tubing \n22\n is deployed into or retrieved from a wellbore penetrating a subterranean formation.', 'In the example illustrated, the sensor or sensors \n24\n detect magnetic flux leakage but the sensors \n24\n may be combined with other types of sensors positioned to help detect and analyze an anomaly or anomalies along pipe \n22\n.', 'In some embodiments sensor \n24\n may comprise a single sensor but sensor \n24\n also may comprise a plurality of sensors or sensor elements arranged longitudinally and/or circumferentially.', 'In a specific embodiment, sensor \n24\n comprises a plurality of magnetic flux leakage sensing elements positioned to detect along the circumference of pipe \n22\n as pipe \n22\n and sensor(s) \n24\n are moved relative to each other.', 'Although pipe \n22\n has been described in the form of coiled tubing which moves relative to the sensor, the pipe \n22\n may comprise individual pipe joints or other types of pipes which are moved relative to the sensor \n24\n.', 'Data obtained by the sensor or sensors \n24\n is transmitted to processing system \n30\n.', 'The processing system \n30\n may be located in whole or in part at a well site, at a well testing facility, and/or at a remote location.', 'After processing data from each sensor \n24\n, the processing system \n30\n may be used to display or otherwise output results related to the detection and evaluation of magnetic flux leakage signal data corresponding with the one or more anomalies \n28\n.', 'The raw and/or processed data may be sent to other systems and other locations for continued processing, analysis, and/or control operations.', 'Referring generally to \nFIG.', '2\n, an example of processing system \n30\n is illustrated.', 'In this example, processing system \n30\n is in the form of a computer-based system having a processor \n32\n, such as a central processing unit (CPU).', 'The processor \n32\n is coupled with sensor or sensors \n24\n and is operatively employed to intake magnetic flux leakage signal data related to anomalies, e.g. defects, \n28\n and then to process the data, e.g. run appropriate models and/or algorithms.', 'For example, the data may be processed to find similar stored signal data correlated with specific types of defects \n28\n, e.g. defects of a certain size, type, and/or shape.', 'This data may then be processed to update stored data on fatigue life of the pipe/coiled tubing \n22\n so as to enable an accurate estimation of cycles to failure.', 'Fatigue life data, anomaly data, and other types of data may be stored in a suitable memory \n34\n which may comprise a single or plural memory devices.', 'In the example illustrated, the processor \n32\n is operatively coupled with memory \n34\n as well as with an input device \n36\n and an output device \n38\n.', 'In some embodiments, the connection between sensors \n24\n and processing system \n30\n may be indirect.', 'For example, data from the sensor or sensors \n24\n may be collected and subsequently downloaded to processing system \n30\n.', 'Desired data may be stored in memory \n34\n and the processor \n32\n may be used to run selected algorithms/models, e.g. comparisons with stored correlations, via a software module/system \n40\n, e.g. an answer product software module.', 'For example, the software module \n40\n may be used to process the data collected by sensor(s) \n24\n in combination with other data stored in memory \n34\n.', 'The memory \n34\n may comprise a library \n42\n used to store a variety of data.', 'The library \n42\n also may be used to store sensor data obtained via the one or more sensors \n24\n.', 'By way of example, the library \n42\n may comprise a fatigue life library \n44\n which comprises, for example, historical data on fatigue life for various types of coiled tubing \n22\n (or other types of pipe), and fatigue life models and associated parameters calibrated against historical fatigue data, without including detrimental effects due to defect \n28\n.', 'The library \n42\n also may comprise an anomaly library \n46\n which contains historical data on many types of anomalies which can affect the fatigue life of the pipe/coiled tubing \n22\n.', 'According to an embodiment, the anomaly library \n46\n may include a pre-established benchmark or defect library for use by processor \n32\n.', 'For example, data on the defects \n28\n may be stored in anomaly library \n46\n as well as selected attributes of given defects, e.g. a defect photo and a corresponding magnetic flux leakage signal or “defect signature” representing a specific type of defect \n28\n.', 'The library \n42\n also may comprise a correlation library \n48\n containing, for example, historical data regarding correlations related to fatigue life with and without a given anomaly/defect \n28\n.', 'The software module \n40\n is able to use such correlations to determine a new fatigue life upon the occurrence of a given defect or other anomaly \n28\n which matches stored data in library \n42\n regarding that type of defect/anomaly.', 'Additionally, the library \n42\n may comprise a cycles to failure library \n50\n which contains data based on historical testing.', 'As described in greater detail below, testing is employed to obtain data on remaining pipe/coiled tubing cycles based on, for example, the new fatigue life combined with the type of operation in which the pipe/coiled tubing \n22\n is utilized.', 'Referring generally to \nFIG.', '3\n, a graphical illustration is provided in which a plot of data representing consumed fatigue life of coiled tubing \n22\n is illustrated versus depth of the coiled tubing \n22\n as measured from a downhole end of the coiled tubing.', 'This type of data may be stored in, for example, fatigue life library \n44\n.', 'Based on the profile of percentage consumed fatigue life in this example, the coiled tubing \n22\n appears to be most heavily used (the highest percentage of consumed fatigue life) at a depth interval of around 10,000 feet.', 'However, the percentage fatigue life plot, alone, may not provide end users with sufficient information regarding the expected number of cycles to failure under anticipated operating conditions.', 'Additionally, due to model nonlinearity of, for example, the fatigue life library \n44\n, the fatigue life value may not indicate the percentage of remaining cycles to failure.', 'For example, a fatigue life of 50% may not mean the remaining number of cycles is the same number as the consumed number of cycles.', 'Due to model nonlinearity, the remaining number of cycles to reach 100% fatigue life may be a fraction of the consumed number of cycles to reach the fatigue life of 50%.', 'If the coiled tubing \n22\n is a tapered coiled tubing string, the same level of percentage fatigue life on sections of different wall thicknesses may not be equivalent.', 'For example, 40% consumed fatigue life on a thin wall, e.g. a wall of 0.125 inch thickness, may be more serious than 60% consumed fatigue life on a thicker wall, e.g. a wall of 0.204 inch thickness.', 'Moreover, a fatigue life tracking model relying solely on historical data regarding consumed fatigue life for a given coiled tubing \n22\n may not be sufficiently accurate in the presence of anomalies, e.g. localized defects \n28\n.', 'It should be noted the examples and specific values provided herein are given for purposes of explanation and should not be construed as limiting.', 'Embodiments described herein combine fatigue life data with additional data to provide end users with improved information regarding the number of cycles to failure.', 'The methodology is useful for a variety of tubing, including tapered coiled tubing.', 'Tapered coiled tubing strings are widely used in coiled tubing operations and feature changes in nominal wall thickness values from a downhole end of the coiled tubing \n22\n to an uphole end of the coiled tubing \n22\n.', 'An example of a coiled tubing wall thickness profile is illustrated in \nFIG.', '4\n as plotted against depth from a downhole end of the coiled tubing.', 'In this example, the coiled tubing \n22\n has a plurality of different wall thicknesses, e.g. seven different wall thickness values, and a 20,000 foot span.', 'As illustrated, the wall thickness may transition from 0.156 inches at a downhole end to 0.204 inches at an uphole end within the depth range of approximately 5500 feet to 6500 feet.', 'For tapered coiled tubing such as the example illustrated in \nFIG.', '4\n, the baseline consumed fatigue life often is traditionally considered 0% for the entire string when in a new, unused state from the manufacturer.', 'This traditional baseline consumed fatigue life of 0% is determined despite the differences in tubing wall thickness at different depths along the borehole during a coiled tubing operation.', 'Despite the change in wall thickness values in this scenario, the expected remaining fatigue life to be consumed is considered the same, namely 100%, for the entire coiled tubing \n22\n.', 'However, the actual expected number of cycles to failure may vary substantially between the sections of different wall thicknesses.', 'For example, the thicker walled end of the coiled tubing \n22\n would tend to last many more cycles than the thin walled end under typical operating conditions.', 'This also illustrates the desirability of cycles to failure modeling which provides more direct information to end users compared to the conventional percentage fatigue life modeling.', 'By combining fatigue life data with anomaly data, e.g. data regarding changes in fatigue life due to different wall thicknesses, a more accurate estimation of the actual fatigue cycle limits may be provided.', 'For example, test data on correlations between wall thickness and reduction in fatigue life as well as the cycles to failure may be stored in libraries \n48\n, \n50\n.', 'An example of such data is illustrated graphically in \nFIG.', '5\n.', 'In the example represented in \nFIG.', '5\n, historical test data for the same type of tapered coiled tubing \n22\n is plotted to provide cycles to failure versus depth in a common operating scenario, e.g. operating the tapered coiled tubing \n22\n with 3000 pounds per square inch differential pressure and subjecting the coiled tubing to a 72 inch bending radius.', 'As indicated by this data, the cycles to failure for the thick walled end is greater than the cycles to failure for the thin walled end under the same common bending radius and differential pressure.', 'This indicates the thick walled end may be able to sustain many more fatigue cycles than the thin walled end.', 'This type of historical test data may be collected in library \n42\n and used by software module \n40\n to provide an accurate estimate of the cycles to failure.', 'The estimate may be output to the computer display or other output device \n38\n.', 'In \nFIG.', '6\n, results of employing the methodology for estimating cycles to failure are illustrated.', 'The results showing cycles to failure in \nFIG.', '6\n are calculated by initially determining an existing level of consumed fatigue life for a given tubing \n22\n, as represented in \nFIG.', '3\n.', 'Referring again to \nFIG.', '6\n, it should be noted that the first approximately 5000 feet of coiled tubing \n22\n on the downhole end may be more susceptible to failure as indicated by the much lower number of remaining cycles to failure.', 'Such improved information is not available from methods of coiled tubing fatigue tracking relying solely on the consumed fatigue life data of coiled tubing without anomalies (see data represented in \nFIG.', '3\n).', 'The anomalies \n28\n which effectively change the fatigue life of the tubing \n22\n may be in many different forms.', 'By way of example, the coiled tubing \n22\n or other pipe may be exposed to anomalies in the form of damaging factors, such as mechanical defects, corrosion, and/or bending-straightening cycles.', 'These damaging factors may lead to localized metal loss which can reduce the life expectancy of the coiled tubing \n22\n.', 'The sensor devices \n24\n, e.g. magnetic flux leakage inspection devices, can be used to reliably detect such localized defects.', 'The correlation library \n48\n may comprise various correlations, e.g. scaling correlations, between the MFL signals and percentage fatigue life reduction.', 'By using such correlations in the methodology described herein, e.g. by combining such correlations with data from the cycles to failure library \n50\n, the reduction in cycles to failure due to the localized effects may be accurately evaluated and output to the desired output device \n38\n.', 'By using software module \n40\n to process the combined data from libraries \n44\n, \n46\n, \n48\n, \n50\n, a more precise estimation of cycles to failure may be provided as compared to using solely the data related to fatigue life of pipe without anomalies \n28\n.', 'In \nFIG.', '7\n, data is provided graphically via plots \n52\n, \n54\n in the form of plot \n54\n of depth versus cycles to failure for coiled tubing \n22\n in which defects/anomalies \n28\n are not considered.', 'The figure also contains plot \n52\n illustrating an improved prediction of cycles to failure versus depth for coiled tubing \n22\n in which the defect/anomalies \n28\n are considered.', 'For this example, it should be noted the coiled tubing \n22\n at around 10,000 feet may be more susceptible to failure.', 'In this case, the increased susceptibility to failure is due to a group of mechanical defects \n28\n which reduces the expected number of cycles to failure.', 'In addition to localized defects, other anomalies \n28\n may lead to a reduction in coiled tubing fatigue resistance.', 'Such anomalies \n28\n may include wall thinning due to acid exposure, abrasion, or other factors.', 'The anomalies \n28\n also may include ballooning of the coiled tubing \n22\n due to cyclic operations under high pressure.', 'By using the MFL devices \n24\n or other suitable sensors, the occurrence of such anomalies or changes in such anomalies may be monitored in real time.', 'For example, the MFL sensors \n24\n may be used to provide real-time, accurate monitoring of wall thicknesses and diameter measurements so that the impact of wall thinning and diameter ballooning may be added to the anomaly library \n46\n so as to facilitate predictions of cycles to failure.', 'FIG.', '8\n provides an example in which the results are graphically illustrated.', 'In this example, a first plot \n56\n illustrates the results when the nominal values of wall thickness and coiled tubing diameter are used, and a second plot \n58\n corresponds with results when the actual measured values of wall thicknesses and diameter are used.', 'By using the MFL sensors \n24\n to track the anomalies \n28\n, e.g. wall thinning and/or ballooning, improved prediction of cycles to failure may be achieved as illustrated graphically.', 'The software module \n40\n may comprise various models or algorithms for utilizing the data collected and stored in library \n42\n.', 'For example, the software module \n40\n may comprise a data matching algorithm which matches the appropriate historical data from sub libraries \n44\n, \n46\n, \n48\n and \n50\n.', 'In some embodiments, the software module \n40\n may incorporate fatigue life thresholds and trips-to-failure modeling.', 'These various techniques may be used to provide cycles to failure assessments for direct evaluation of fitness for service with respect to a given coiled tubing or other type of pipe \n22\n.', 'Initial fatigue life assessment may be determined and stored in library \n42\n according to established models for fatigue life tracking which consider loading history, e.g. pressure and bending radius, and tubing properties, e.g. diameter, wall thickness, and material grade.', 'As described above, the consumed fatigue life theoretically reaches 100% before failure occurs but in real world operations the failure often occurs prior to reaching the 100% fatigue life due to anomalies \n28\n.', 'The methodologies described herein may be used to provide a rigorous and accurate way of setting fatigue life threshold values which account for the effects of anomalies \n28\n, e.g. localized defects.', 'According to an embodiment, a methodology for setting accurate threshold values for fatigue life is based on non-destructive evaluation of the pipe/coiled tubing \n22\n.', 'As described above, magnetic flux leakage sensors \n24\n may be used to obtain measurements for use in a non-destructive evaluation method based on established quantitative relationships between MFL measurements and a fatigue life ratio of specific defects \n28\n.', 'This fatigue life ratio may be defined as the fraction of total cycles to failure when a defect exists compared to when the defect does not exist.', 'By using this quantitative correlation (which may be stored in correlation library \n48\n), the threshold value of fatigue life may be determined at the place of localized defects.', 'An example of the effects of the localized defect \n28\n is illustrated graphically in \nFIG.', '9\n.', 'In the illustrated graph, the graph line \n60\n indicates the consumed fatigue life versus depth during deployment of coiled tubing \n22\n without defects \n28\n.', 'By way of example, the fatigue life for a given defect-free pipe/coiled tubing \n22\n may be stored in fatigue life library \n44\n.', 'A dot \n62\n represents a threshold value that the fatigue life should not exceed at a depth of around 5000 feet where a localized defect \n28\n exists.', 'It should be noted this threshold value is much lower than 100% due to the detrimental effects of localized defect \n28\n as determined by the stored correlation relationships between MFL measurements and fatigue life ratio in module \n40\n.', 'In addition, it should be noted the value for dot \n62\n is determined based on the known information regarding the time when the localized defect \n28\n occurred.', 'If the timing of the occurrence of defect \n28\n is unknown, then a range of values may be similarly determined for the fatigue life thresholds, as described immediately below, including worst-case and best-case scenarios.', 'In this graphical example, a worst-case scenario has been indicated by a triangle \n64\n which corresponds to the case where the defect \n28\n exists from the very beginning.', 'A best-case scenario is indicated by a triangle \n66\n which corresponds to the case in which the defect \n28\n occurred very recently.', 'The interval of threshold values between triangles \n64\n and \n66\n is based on the fact that the timing of the defect occurrence plays a role in the severity of the effects that result from the defect \n28\n with respect to coiled tubing fatigue.', 'The earlier the defect \n28\n occurs, the more impact it has on the life of the coiled tubing \n22\n.', 'Accordingly, the limits of coiled tubing fatigue life may be determined via quantitative evaluation of defect severity based on magnetic flux leakage measurements.', 'In reality, the time when a defect \n28\n occurs is in general between the very beginning and the very recent job.', 'Thus, the threshold value is in general between the worst-case and the best-case scenarios, as indicated by dot \n62\n, which is between triangle \n64\n and triangle \n66\n.', 'In some embodiments, the methodology may be implemented via an answer product software package embodied in software module \n40\n as described in the examples set forth below.', 'The data collected from such testing also may be used in libraries \n44\n, \n46\n, \n48\n, \n50\n to improve the quality of the historical data and thus the predictive results.', 'According to a first example, a coiled tubing string was evaluated with the following details:\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOD\n \n2.375 in\n \n \n \n \nMaterial grade\n \n90-ksi\n \n \n \n \nWall Thickness\n \nTapered:\n \n \n \n \n \n0.175 in\n \n \n \n \n \n0.190 in\n \n \n \n \n \n0.204 in\n \n \n \n \n \n0.224 in\n \n \n \n \nMilling Date\n \nMay, 2015\n \n \n \n \nIn-Service Date\n \nFebruary, 2016\n \n \n \n \nEnd of Service Date\n \nSeptember, 2016\n \n \n \n \nTotal Running Feet\n \n783,748 ft with 49 BHAs\n \n \n \n \nWorking Drum\n \nCore Diameter: 96 in\n \n \n \n \n \nWidth: 87 in\n \n \n \n \nGooseneck Radius\n \n\u2002\u2009120 in\n \n \n \n \nOperation Type\n \nCoiled Tubing Drilling (CTD)', 'During the first run-in-hole, the non-destructive evaluation tracking system \n20\n did not detect an anomaly/defect \n28\n.', 'However, when the coiled tubing string was pulled out of the borehole, three defects \n28\n were detected respectively near 14,000 feet, 12,000 feet, and 10,000 feet.', 'The defect \n28\n at 12,000 feet was the defect having the greatest impact.', 'In this particular example, the defect at 12,000 feet was a gouge type defect caused by injector head chain slippage during the first run in hole operation.', 'To evaluate the severity of this particular defect \n28\n, the software module \n40\n was used to employ an answer product software.', 'Based on the processing of data, evaluation results were output via, for example, output device \n38\n as indicated graphically in \nFIG.', '10\n.', 'In this example, the accumulated baseline fatigue life at the time defect \n28\n occurred is illustrated by graph line \n68\n.', 'Because the defects \n28\n occurred while running in hole during the very first run, the baseline fatigue life is near zero except at bias weld locations where fatigue reduction has been applied as illustrated.', 'The impact of the defect \n28\n on fatigue life was considered by the answer product software of software module \n40\n and the calculated impact of defect \n28\n resulted in a dropping of the fatigue life threshold.', 'For this case, the fatigue life threshold is dropped to 40% from the 100% theoretical limit, as represented by the dot \n70\n indicated at a depth near 12,000 feet.', 'The gap between the graph line \n68\n and the dot \n70\n represents the amount of remaining fatigue that can be safely consumed without failure of the coiled tubing \n22\n at this particular defect \n28\n.', 'The answer product software of software module \n40\n also may be used to track the evolution of specific defects \n28\n, e.g. the defect \n28\n at a depth near 12,000 feet.', 'In this example, the condition of this particular defect \n28\n has deteriorated after six months of service in the field.', 'Due to defect deterioration, the quantitative fatigue life threshold is dropped further to about 30% of the previous 40% threshold, as represented by the dot \n72\n in the graphical illustration of \nFIG.', '11\n.', 'It should be noted the defect \n28\n is now located at the depth near 10,800 feet and this is mainly due to coil trimming during deployment.', 'Additionally, the baseline fatigue as represented by graph line \n74\n has grown due to field use compared to line \n68\n in \nFIG.', '10\n.', 'As illustrated, there is still a gap between the graph line \n74\n and the dot \n72\n in \nFIG. \n11\n, but the gap has reduced substantially as compared to the gap in \nFIG. \n10\n.', 'This means the coiled tubing \n22\n is still suitable for a few additional jobs without failing at this particular defect \n28\n although the coiled tubing \n22\n should be continually monitored by the non-destructive evaluation tracking system \n20\n.', 'This case study demonstrates it is feasible to safely extend the useful life of coiled tubing strings even with the presence of a defect, e.g. damage, by using the continued monitoring, inspection, and evaluation of the coiled tubing string enabled by tracking system \n20\n.', 'According to a second example, a coiled tubing string was evaluated with the following details:\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOD\n \n2.375 in\n \n \n \n \nMaterial grade\n \n90-ksi\n \n \n \n \nWall Thickness\n \nTapered:\n \n \n \n \n \n0.156 in\n \n \n \n \n \n0.175 in\n \n \n \n \n \n0.190 in\n \n \n \n \n \n0.204 in\n \n \n \n \nWorking Drum\n \nCore Diameter: 115 in\n \n \n \n \n \nWidth: 96 in\n \n \n \n \nGooseneck Radius\n \n\u2002\u2009100 in\n \n \n \n \nOperation Type\n \nCoiled Tubing Drilling (CTD)', 'In this example, the answer product software of software module \n40\n was again used to evaluate the impact of a physical defect \n28\n on the coiled tubing string \n22\n.', 'Results are shown in \nFIG. \n12\n.', 'It should be noted the test results were achieved at a pressure level of 3000 psi and a gooseneck radius of 100 inches for deployment of the coiled tubing \n22\n.', 'Because of this particular defect \n28\n, the fatigue life threshold was reduced to within 15% for the depth where the defect \n28\n was located (see dot \n76\n).', 'Because the baseline fatigue life at that particular depth has already exceeded 13% (see graph line \n78\n), the coiled tubing string \n22\n was predicted to fail within two typical jobs.', 'According to a third example, a coiled tubing string was evaluated with the following details:\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nOD\n \n2.375 in\n \n \n \n \nMaterial grade\n \n90-ksi\n \n \n \n \nWall Thickness\n \nTapered:\n \n \n \n \n \n0.175 in\n \n \n \n \n \n0.190 in\n \n \n \n \n \n0.204 in\n \n \n \n \n \n0.224 in\n \n \n \n \nMilling Date\n \nMay, 2015\n \n \n \n \nIn-Service Date\n \nJanuary, 2016\n \n \n \n \nEnd of Service Date\n \nJuly, 2016\n \n \n \n \nTotal Running Feet\n \n855,691 ft with 58 BHAs\n \n \n \n \nWorking Drum\n \nCore Diameter: 96 in\n \n \n \n \n \nWidth: 87 in\n \n \n \n \nGooseneck Radius\n \n\u2002\u2009120 in\n \n \n \n \n \n \n \n \n \n \n In this example, a group of groove/necking type defects \n28\n were identified at a later stage and tracked via MFL sensors \n24\n of tracking system \n20\n.', 'The software module \n40\n, e.g. answer product software, of processing system \n30\n was used by the non-destructive evaluation tracking system \n20\n to quantify the impact of such defect \n20\n on the integrity of the coiled tubing \n22\n.', 'The system \n20\n output results to output device \n38\n and those results are illustrated graphically in \nFIG.', '13\n.', 'It should be noted the test results were obtained while subjecting the coiled tubing \n22\n to a pressure level of 3000 psi and a gooseneck radius of 120 inches.', 'The results indicate a reduced fatigue life threshold, as represented by dots \n80\n, which is fairly close to the existing baseline fatigue life indicated by graph line \n82\n.', 'These results indicate the coiled tubing \n22\n is near the end of its useful life.', 'Consequently, appropriate decisions may be made such as withdrawal of the coiled tubing from service based on the system evaluation results.', 'The noninvasive tracking system \n20\n enables monitoring, inspection, and evaluation so as to enable withdrawal of the coiled tubing \n22\n before a costly failure occurs.', 'In some embodiments, the software module \n40\n may be used to estimate cycles to failure based on modeling which assumes the coiled tubing \n22\n is fatigued against a constant bending radius.', 'However, the coiled tubing \n22\n may go through varying bending radii depending on the depth of each section of the coiled tubing.', 'For example, the closer the coiled tubing \n22\n is to the center of the drum/reel on which it is coiled, the smaller the bending radius.', 'Additionally, for each complete trip downhole (as the coiled tubing is moved into and out of the service well), the coiled tubing goes through two complete bending cycles on the gooseneck and one complete cycle on the coiled tubing drum.', 'Based on such facts, the model carried out by processing system \n30\n may be extended to provide cycles to failure estimates in the form of a quantitative estimation of trips to failure, as indicated graphically in \nFIG.', '14\n.', 'Referring again to \nFIG.', '14\n, different estimates of trips to failure are provided graphically for different scenarios and such results may be output to, for example, output device \n38\n.', 'In this example, a graph line \n84\n represents the model estimation of trips to failure based on new coiled tubing with 0% consumed fatigue life and without localized defects.', 'Such estimation utilizes the fatigue life model built in system/module \n40\n and is based on the provided operating condition parameters, including the coiled tubing information (e.g. depth, diameter, wall thickness, grade), the corresponding reel geometries (e.g. inside reel diameters, reel width), coiled tubing gooseneck radius, and the typical circulating pressure level.', 'A graph line \n86\n represents the model estimation of used coiled tubing considering accumulated fatigue life without the existence of localized anomalies, e.g. without localized defects.', 'Such estimation is based on the information used to estimate graph line \n84\n plus the additional information of the existing/consumed fatigue value at each depth of the coiled tubing.', 'In this example, graph lines \n88\n, \n90\n are utilized and graph line \n90\n represents the model estimation of used coiled tubing considering accumulated fatigue life and also considering the existence of localized damages, as detected and processed by system \n30\n for example.', 'Such estimation utilizes the comprehensive information used to estimate graph line \n86\n plus the additional information of the MFL measurements by system \n30\n and the corresponding correlation libraries built into system/module \n40\n combined with the added assumption that the localized damages were in existence since approximately the time the coiled tubing string was first put into operation.', 'Additionally, graph line \n88\n represents the model estimation of used coiled tubing considering accumulated fatigue life and also considering the existence of localized damages as detected and processed by system \n30\n for example.', 'Such estimation utilizes the comprehensive information used to estimate graph line \n86\n, plus additional information of the MFL measurements by system \n30\n and the corresponding correlation libraries built into system/module \n40\n combined with the added assumption that the localized damages have occurred on the most recent job.', 'Thus, the tracking and evaluation system \n20\n may be used to output useful results to an operator so that decisions may be made with respect to continued use of the coiled tubing \n22\n (or other type of pipe) given various scenarios including the timing of defect occurrence.', 'By using processing system \n30\n to process data regarding anomaly type, the fatigue life accumulation data for the pipe \n22\n, and the number of cycles experienced by the pipe \n22\n at the time the defect, accurate estimates of the cycles to failure and/or trips to failure can be provided.', 'In some applications, additional data (e.g. depth of defect \n28\n during usage, pressure and/or bending radius experienced by pipe \n22\n at the defect \n28\n, wall thickness) can be useful in further enhancing the estimates.', 'The estimates of remaining cycles/trips can be output to, for example, output device \n38\n for use in determining an appropriate remedial action, such as withdrawal of the pipe, repair of the pipe, or the number of additional operations before such action.', 'As described above, the processing system \n30\n may further be used in processing data for estimating a threshold value to set a limit for the fatigue life value that should not be exceeded so as to safeguard operations based on defect severity estimation and timing information with respect to defect occurrence.', 'The process of estimating may comprise estimating a worst-case threshold value assuming the existence of defects since the very beginning of tubing utilization.', 'Additionally, the process may comprise estimating a best-case threshold value assuming defects occurred very recently.', 'The process also may comprise estimating a worst-case number of trips to failure assuming the presence of defects from the very beginning.', 'Also, the process may comprise estimating the best-case number of trips to failure assuming defects occurred very recently.', 'The system and methodologies described herein may be employed in non-well related applications which utilize evaluation of coiled tubing, jointed pipe, and/or other tubing strings.', 'Additionally, processes may employ a variety of sensors, data processing systems, and/or software modules for evaluating sensor data and/or making recommendations.', 'The system may be automated to implement automatic changes to a tubing string operation based on defect data detected and evaluated.', 'In some applications, the operational changes can be made in real time.', 'Additionally, various types of storage databases/libraries may be constructed to accumulate many types of correlations and defect data.', 'By way of example, the library \n42\n may comprise a defect library which may be automatically updated with defect entries based on defects \n28\n detected during evaluation of pipes, e.g. coiled tubing.', 'Also, elements of the overall processes described herein may be performed at a variety of times and in various orders during implementation of the processes.', 'Although a few embodiments of the system and methodology have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A method for tracking and assessing a coiled tubing string, comprising:\ndetermining a fatigue life of the coiled tubing string;\nutilizing a magnetic flux leakage (MFL) device to monitor the coiled tubing string;\nupon detecting a defect in the coiled tubing string via the MFL device, processing defect data in combination with data on the fatigue life to determine a new fatigue life of the coiled tubing string with the detected defect; and\nusing the new fatigue life to output an estimate of cycles to failure of the coiled tubing string.', '2.', 'The method as recited in claim 1, wherein processing defect data comprises utilizing the type of defect detected as a factor in determining the new fatigue life.', '3.', 'The method as recited in claim 1, wherein utilizing comprises utilizing the MFL device to monitor a tapered coiled tubing string.', '4.', 'The method as recited in claim 3, wherein using comprises outputting the estimate of cycles to failure for sections of the tapered coiled tubing string along the entire length of the tapered coiled tubing string.', '5.', 'The method as recited in claim 1, wherein processing comprises using a software module to select historical data used in determining the new fatigue life.', '6.', 'The method as recited in claim 1, wherein using comprises outputting an estimate of remaining trips downhole until failure.', '7.', 'The method as recited in claim 1, wherein processing comprises employing a correlation library.', '8.', 'The method as recited in claim 1, wherein using comprises estimating a threshold value to set a limit for the fatigue life value that should not be exceeded so as to safeguard operations based on defect severity estimation and timing information with respect to defect occurrence.', '9.', 'The method as recited in claim 8, wherein estimating the threshold value comprises estimating a worst-case threshold value assuming the defect existed since the beginning of the use of the coiled tubing string.', '10.', 'The method as recited in claim 8, wherein estimating the threshold value comprises estimating a best-case threshold value assuming a recent occurrence of the defect.', '11.', 'The method as recited in claim 1, wherein using comprises estimating a worst-case number of trips to failure assuming the defect existed since the beginning of use of the coiled tubing.', '12.', 'The method as recited in claim 1, wherein using comprises estimating a best-case number of trips to failure assuming a recent occurrence of the defect.', '13.', 'A method, comprising:\nmonitoring coiled tubing to detect the presence of an anomaly in the coiled tubing;\nproviding data regarding the anomaly to a data processing system for comparison to stored historical data;\nestablishing a fatigue life of the coiled tubing without the anomaly;\ndetermining the number of cycles experienced by the coiled tubing at the time the anomaly occurred;\nusing combined data on the fatigue life, the type of anomaly, and the number of cycles experienced by the coiled tubing at the time the anomaly occurred to estimate a new fatigue life; and\nbased on the new fatigue life, determining and outputting an estimate of the remaining number of cycles to failure to determine future use of the coiled tubing.', '14.', 'The method as recited in claim 13, further comprising continuing to use the coiled tubing a predetermined number of cycles based on the estimate.', '15.', 'The method as recited in claim 13, wherein using comprises using at least one MFL sensor to track magnetic flux leakage signals and to detect changes in the magnetic flux leakage signals indicative of the anomaly.', '16.', 'The method as recited in claim 13, wherein providing data to the data processing system comprises using magnetic flux leakage signatures to provide data on a type of defect.', '17.', 'The method as recited in claim 13, wherein using the combined data comprises using data on borehole depth of the anomaly during use of the coiled tubing and using data on the pressure experienced by a section of the coiled tubing having the anomaly during use of the coiled tubing.', '18.', 'A system for estimating tubing life, comprising:\na sensor positioned along a pipe to monitor for a magnetic flux leakage signal associated with an anomaly in the pipe; and\na data processing system which obtains data from the sensor, the data processing system comprising: a display; a memory in which historical anomaly data is stored regarding the type of anomaly, the memory also storing fatigue life data regarding fatigue life of the pipe without the anomaly; and a processor which uses a computer model for combining data from the sensor, historical anomaly data, and fatigue life data to estimate a remaining number of cycles to failure of the pipe.\n\n\n\n\n\n\n19.', 'The system as recited in claim 18, wherein the processor also utilizes data on borehole depth of the anomaly during use of the pipe to estimate the remaining number of cycles to failure.', '20.', 'The system as recited in claim 19, wherein the computer model is used to output an estimate of trips downhole until failure.']

['FIG.', '1 is a schematic illustration of an example of a pipe defect assessment system for evaluating pipe, e.g. coiled tubing, according to an embodiment of the disclosure;; FIG.', '2 is a schematic illustration of a processor-based system for evaluating sensor data in combination with stored historical data, thus enabling accurate estimation of cycles to failure, according to an embodiment of the disclosure;; FIG.', '3 is a graphical representation illustrating data regarding fatigue life of a pipe versus depth of the pipe, according to an embodiment of the disclosure;; FIG. 4 is a graphical representation illustrating data regarding nominal wall thickness of a pipe versus depth of the pipe, according to an embodiment of the disclosure;; FIG.', '5 is a graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;; FIG.', '6 is another graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;; FIG. 7 is another graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;; FIG. 8 is another graphical representation illustrating data regarding cycles to failure versus depth of the pipe, according to an embodiment of the disclosure;; FIG.', '9 is a graphical representation illustrating data regarding consumed fatigue life versus depth of the pipe, according to an embodiment of the disclosure;; FIG.', '10 is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure;; FIG.', '11 is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure;; FIG.', '12 is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure;; FIG.', '13 is another graphical representation illustrating data regarding fatigue life versus depth of the pipe, according to an embodiment of the disclosure; and; FIG.', '14 is a graphical representation illustrating data regarding estimated trips to failure versus depth of the pipe, according to an embodiment of the disclosure.']

US11905801

Bi-directional spring cone in liner hanger system

Jun 29, 2020

Ming Zhao, Asif Javed, James Hall

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written opinion issued in PCT application PCT/US2020/040103, dated Oct. 15, 2020 (14 pages).; Wilhelm A. Schneider, “Design and application of slotted cylinder springs”, United States Army, USAELRDL Technical Report 2327, 1963. (29 pages).

2442544; June 1948; Johnson; 3976133; August 24, 1976; Allen; 4127168; November 28, 1978; Hanson; 5749585; May 12, 1998; Lembcke; 6467540; October 22, 2002; Weinig; 7048055; May 23, 2006; Hirth; 7114573; October 3, 2006; Hirth et al.; 8997882; April 7, 2015; Turley et al.; 20040177967; September 16, 2004; Hirth

106522868; March 2017; CN; 2009137536; November 2009; WO; 2017105562; June 2017; WO

['A system for hanging tubing in a wellbore includes a tubular body, a plurality of lower slips mounted along the tubular body, a spring cone disposed around the tubular body and fixed to the plurality of lower slips, the spring cone comprising a lock ring having a ratchet profile, and a packer element disposed around the tubular body, below and adjacent the spring cone.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'The present document is based on and claims priority to U.S. Provisional Patent Application Ser.', 'No. 62/869,225, filed Jul. 1, 2019, which is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nA liner hanger system is used to hang a liner in a previously installed casing or liner.', 'The system usually includes a liner hanger to provide anchoring and a packer to provide sealing.', 'The slips on the hanger after set are engaged with the casing to provide the hanging load (in the downward direction).', 'Hold-down slips on the liner top packer are meant to hold the load from the opposite direction (upward direction).', 'The liner top packer also has an elastomeric element, which will be energized to seal the annulus between the liner and the casing after being set.', 'Normally, the liner hanger system is conveyed downhole with the liners using a running/setting tool.', 'Hydraulically or mechanically, the slips are set by pushing a part having a cone profile to ramp the slips up to contact the casing.', 'The upward load is usually due to the well accidental discharge, downhole frac/stimulation pumping operations.', 'In a worst case scenario, this upward load could be larger than the hanging load (downward), which is the effective liner weight downhole.', 'As a result, the packer slips could be relaxed due to this load reversal.', 'The elastomeric element on the liner top packer may not be optimally energized due to the back off caused by the load reversal.', 'As a result, the entire liner hanger system may fail to hang the liners or to seal the annulus, causing a catastrophic incident.', 'Accordingly, there is a need to mitigate the risk of liner hanger system failure due to load reversal.', 'SUMMARY\n \nA system for hanging tubing in a wellbore according to one or more embodiments of the present disclosure includes a tubular body, a plurality of lower slips mounted along the tubular body, a spring cone disposed around the tubular body and fixed to the plurality of lower slips, the spring cone comprising a lock ring having a ratchet profile, and a packer element disposed around the tubular body, below and adjacent the spring cone.', 'A method according to one or more embodiments of the present disclosure includes conveying a liner hanger system downhole into a cased wellbore, the liner hanger system including a tubular body, a plurality of lower slips mounted along the tubular body, a spring cone disposed around the tubular body and fixed to the plurality of lower slips, the spring cone including: a lock ring having a ratchet profile, and a cone profile, and a packer element disposed around the tubular body, below and adjacent the spring cone, the packer element including an elastomeric element, actuating the plurality of lower slips against the cone profile of the spring cone to create a setting load that forces the plurality of lower slips radially outward into engagement with the casing, and compresses the spring cone, and transferring the setting load through the spring cone to energize the packer element to seal an annulus between a liner and the casing, wherein the lock ring having the ratchet profile prevents the spring cone from moving in an upward direction after compression.', 'A method of manufacture according to one or more embodiments of the present disclosure includes dividing a cylinder into a plurality of sections arranged in sequence, cutting a plurality of slots into each section of the plurality of sections in a slot pattern, and disposing a lock ring having a ratchet profile near a middle of the cylinder.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is an illustration of a liner hanger system with a spring cone according to one or more embodiments of the present disclosure;\n \nFIG.', '2\n is a slotted cylinder spring with associated geometric parameters according to one or more embodiments of the present disclosure;\n \nFIGS.', '3\nA and \n3\nB\n are examples of different types of slots according to one or more embodiments of the present disclosure;\n \nFIG.', '4\n is a bi-directional spring cone before setting according to one or more embodiments of the present disclosure;\n \nFIG.', '5\n is a bi-directional spring cone after setting according to one or more embodiments of the present disclosure; and\n \nFIG.', '6\n is an example of spring cone load-deflection performance according to one or more embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the apparatus and/or method may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'In the specification and appended claims: the terms “up” and “down,” “upper” and “lower,” “upwardly” and “downwardly,” “upstream” and “downstream,” “uphole” and “downhole,” “above” and “below,” and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure.', 'The present disclosure generally relates to an apparatus and method to mitigate the risk of liner hanger system failure due to load reversal.', 'More specifically, one or more embodiments of the present disclosure relate to an apparatus and method for spring loading components of the liner hanger system in case of the load reversal.', 'According to one or more embodiments of the present disclosure, a bi-directional spring cone may provide the required retentive load to mitigate the risk of liner hanger system failure due to load reversal.', 'Referring generally to \nFIG.', '1\n, an illustration of a liner hanger system with a spring cone according to one or more embodiments of the present disclosure is shown.', 'The liner hanger system \n10\n may be used to suspend a liner in a wellbore \n11\n that has been cased with a casing \n13\n.', 'In one or more embodiments of the present disclosure, the liner hanger system \n10\n may be conveyed downhole into the cased wellbore \n11\n using a running or setting tool, for example.', 'As shown in \nFIG. \n1\n, the liner hanger system \n10\n includes a tubular body \n12\n and a lower slip \n14\n mounted along the tubular body \n12\n.', 'In one or more embodiments of the present disclosure, the lower slip \n14\n may include teeth, ratcheting, or gripping elements to allow the lower slip \n14\n to bite into and grip the casing \n13\n.', 'Although only one lower slip \n14\n is shown in \nFIG.', '1\n, a plurality of lower slips \n14\n may be mounted along the tubular body \n12\n according to one or more embodiments of the present disclosure.', 'As further shown in \nFIG.', '1\n, the liner hanger system \n10\n may also include a spring cone \n16\n disposed around the tubular body \n12\n and fixed to the lower slip \n14\n.', 'In one or more embodiments of the present disclosure, the spring cone \n16\n may be fixed to the lower slip \n14\n with at least one shear screw \n18\n.', 'Moreover, the spring cone \n16\n may include a cone profile \n20\n that is configured to engage a corresponding profile \n21\n of the lower slip \n14\n.', 'While \nFIG. \n1\n shows that the cone profile \n20\n of the spring cone \n16\n may be located near an end of the spring cone \n16\n, as long as the cone profile \n20\n is configured to engage a corresponding profile \n21\n of the lower slip \n14\n, the cone profile \n20\n may be located at another location along the spring cone \n16\n without departing from the scope of the present disclosure.', 'In one or more embodiments of the present disclosure, the spring cone \n16\n may also include a lock ring \n22\n having a ratchet profile \n24\n located near a middle of the spring cone \n16\n.', 'The lock ring \n22\n with the ratchet profile \n24\n is further described below.', 'As further shown in \nFIG.', '1\n, the liner hanger system \n10\n may also include a packer element \n26\n disposed around the tubular body \n12\n.', 'In one or more embodiments of the present disclosure, the packer element \n26\n may include an elastomeric element \n28\n.', 'The elastomeric element \n28\n of the packer element \n26\n may be located near a top of a lower liner section \n30\n for sealing a liner to the casing \n13\n according to one or more embodiments of the present disclosure.', 'Still referring to \nFIG.', '1\n, the liner hanger system \n10\n according to one or more embodiments of the present disclosure may also include an upper cone \n32\n disposed around the tubular body \n12\n.', 'As shown in \nFIG.', '1\n, the upper cone \n32\n may include an engagement profile \n33\n in accordance with one or more embodiments of the present disclosure.', 'As further shown in \nFIG.', '1\n, the liner hanger system \n10\n may also include an upper slip \n34\n fixed to the upper cone \n32\n.', 'The upper slip \n34\n may be fixed to the upper cone \n32\n via a shear screw \n18\n, for example.', 'In one or more embodiments of the present disclosure, the upper slip \n34\n may include a corresponding profile \n35\n to the engagement profile \n33\n of the upper cone \n32\n.', 'Although only one upper slip \n34\n is shown in \nFIG.', '1\n, a plurality of upper slips \n34\n may be fixed to the upper cone \n32\n according to one or more embodiments of the present disclosure.', 'Referring now to \nFIG.', '2\n, a slotted cylinder spring with associated geometric parameters according to one or more embodiments of the present disclosure is shown.', 'Indeed, the spring cone \n16\n, as previously described, may be a slotted cylinder spring according to one or more embodiments of the present disclosure.', 'Advantageously, the slotted cylinder spring is able to provide high load capacity and low deflection in a limited size.', 'As shown in \nFIG. \n2\n, in accordance with one or more embodiments of the present disclosure, the slotted cylinder spring \n36\n may be made by dividing a cylindrical pipe body \n38\n into a plurality of sections \n40\n arranged in sequence, cutting a plurality of slots \n42\n into each section \n40\n of the plurality of sections \n40\n in a slot pattern, and disposing a lock ring \n22\n having a ratchet profile \n24\n near a middle of the cylindrical pipe body \n38\n.', 'In one level on the circumference of the cylindrical pipe body \n38\n (i.e., one section \n40\n), the slotted cylinder spring \n36\n has a number of slots \n42\n per section \n40\n (N\ns\n).', 'In one or more embodiments of the present disclosure, N\ns \ncan be 2, 3, 4, or more, for example.', 'To achieve a slot pattern according to one or more embodiments of the present disclosure, a next section \n40\n of the cylindrical pipe body \n38\n may have the same N\ns \nbut with 180/N\ns \ndegrees of rotation, so that a vertical path \n43\n is located at the center of the previous slot \n42\n.', 'With a number of sections \n40\n (N\nss\n) arranged in sequence, one spring cone \n16\n according to one or more embodiments of the present disclosure may be obtained.', 'According to one or more embodiments of the present disclosure, N\nss \nmay be 4, 5, 6, 7, 8, or more, for example.', 'Still referring to \nFIG.', '2\n, the slotted cylinder spring \n36\n of the spring cone \n16\n may include various material properties and geometric parameters to govern the spring performance of the spring cone \n16\n.', 'For example, \nFIG.', '2\n shows geometric parameters of the slotted cylinder spring \n36\n such as the inner diameter ID, the outer diameter OD, beam height h, width of cut WOC, depth of cut DOC, length of slot L, and wall thickness b.', "Based on the geometric parameters of the slotted cylinder spring \n36\n, the spring stiffness (K) may be derived using Equation 1, where F is the force on the cylindrical pipe body \n38\n, δ\ntot \nis the total displacement produced by the force, i.e., the change in length of the cylindrical pipe body \n38\n, E is the Young's Modulus, which is measured as stress σ (or uniaxial force per unit surface) over strain ϵ (or change in length divided by original length), i.e.,\n \n \n \n \n \n \nσ\n \nε\n \n \n,\n \n \n \n \n and the other geometric parameters are as previously defined.", 'K\n \n=\n \n \n \nF\n \n \nδ\n \n \nt\n \n\u2062\n \no\n \n\u2062\n \nt\n \n \n \n \n=\n \n \n \n16\n \n·\n \n \nN\n \nS\n \n \n·\n \nb\n \n·\n \n \nh\n \n3\n \n \n·\n \nE\n \n \n \n \nN\n \nSS\n \n \n·\n \n \nL\n \n3\n \n \n \n \n \n \n \n \n \nEq\n \n.\n \n \n \n1\n \n \n \n \n \n \n \n \nAlso based on the geometric parameters of the slotted cylinder spring \n36\n, the spring total length L\ns \nmay be derived using Equation 2, where the geometric parameters are as previously defined.', 'L\ns\n=(\nN\nss\n+1)·(\nh+WOC\n)+\nh\n\u2003\u2003Eq. 2 \n \nBased on the required load on the lower slips \n14\n (and/or the upper slips \n34\n) and the elastomeric element \n28\n of the packer element \n26\n, the geometric parameters as previously described may be designed to yield superior spring performance.', 'Regarding materials, the slotted cylinder spring \n36\n may be made of 150 KSI 17-4 PH Stainless Steel (Smith Material Spec.', 'ES4.39251) to achieve an ultra-high load for liner hanger applications in accordance with one or more embodiments of the present disclosure.', 'However, depending on the application, the slotted cylinder spring \n36\n may be made out of other materials, such as 4130/4140 Steel, for example, without departing from the scope of the present disclosure.', 'Referring now to \nFIGS.', '3\nA and \n3\nB\n, examples of different types of slots \n42\n according to one or more embodiments of the present disclosure are shown.', 'There may be various ways to cut the slots \n42\n into the cylindrical pipe body \n38\n in accordance with one or more embodiments of the present disclosure, including the straight cut \n44\n shown in \nFIG.', '3\nA\n, and the radial cut \n46\n shown in \nFIG.', '3\nB\n, for example.', 'Other types of cuts having different shapes or geometric configurations are contemplated and may be within the scope of the present disclosure.', 'In one or more embodiments of the present disclosure, the straight cut \n44\n, such as that shown in \nFIG.', '3\nA\n, is relatively easy, cost saving, and more suitable for smaller slot \n42\n widths.', 'In one or more embodiments of the present disclosure, the radial cut \n46\n, such as that shown in \nFIG.', '3\nB\n, can minimize the difference of the arc length on the OD and ID of the cylindrical pipe body \n38\n, making the slot \n42\n deflection more uniform, especially when the slot \n42\n width is relatively large.', 'As further shown in \nFIG. \n3\nB\n, a slot \n42\n may include at least one nub \n48\n.', 'Although \nFIG.', '3\nB\n shows that the slot \n42\n having radial cuts \n46\n includes the at least one nub \n48\n, slots \n42\n having straight cuts \n44\n or other types of cuts having different shapes or geometric configurations may also include at least one nub \n48\n in accordance with one or more embodiments of the present disclosure.', 'The functionality of the at least one nub \n48\n is further described below with respect to \nFIG.', '4\n.', 'Referring now to \nFIG.', '4\n, a bi-direction spring cone \n16\n before setting according to one or more embodiments of the present disclosure is shown.', 'As shown in \nFIG.', '4\n, the spring cone \n16\n includes a plurality of slots \n42\n, at least one nub \n48\n, a lock ring \n22\n having a ratchet profile \n24\n near a middle of the spring cone \n16\n, and a cone profile \n20\n as previously described.', 'As further shown in \nFIG. \n4\n, the at least one nub \n48\n may be added on each of the end slots \n42\n(\na\n) according to one or more embodiments of the present disclosure.', 'The end slots \n42\n(\na\n) are there to transfer the load to the “effective” slots \n42\n(\nb\n) during setting in accordance with one or more embodiments of the present disclosure.', 'As shown, the at least one nub \n48\n reduced the end slot \n42\n(\na\n) width by half, which forces all the slots \n42\n to close once the spring cone \n16\n is fully compressed (\nFIG. \n5\n).', 'Full radius on the end slot \n42\n(\na\n) helps reduce the stress concentration and therefore reduces local plastic deformation.', 'As further shown in \nFIG.', '4\n, the spring cone \n16\n before setting is in an uncompressed state.', 'As previously described with respect to \nFIG.', '1\n, shear screws \n18\n may fix the lower slip \n14\n to the spring cone \n16\n and the upper slip \n34\n to the upper cone \n32\n, according to one or more embodiments of the present disclosure.', 'When sufficient pressure of hydraulic fluid or other sufficient mechanical pressure is applied to an actuator (not shown) of the liner hanger system \n10\n, the shear screws \n18\n may shear to enable shifting or actuation of the lower slip \n14\n and the upper slip \n34\n.', 'That is, when the shear screws \n18\n shear, the lower slip \n14\n shifts against the cone profile \n20\n of the spring cone \n16\n to create a setting load that forces the lower slip \n14\n radially outward into engagement with the casing \n13\n and compresses the spring cone \n16\n.', 'When engaged with the casing \n13\n, the lower slip \n14\n provides a hanging load in a downward direction.', 'In one or more embodiments, the shearing of the shear screws \n18\n also causes the upper slip \n34\n to shift against the engagement profile \n33\n of the upper cone \n32\n to force the upper slip \n34\n radially outward into engagement with the casing \n13\n.', 'In one or more embodiments of the present disclosure, the generated setting load may be transferred through the spring cone \n16\n to energize the adjacent elastomeric element \n28\n of the packer element \n26\n to seal an annulus between a liner and the casing \n13\n.', 'That is, after setting, the lower slip \n14\n and/or the upper slip \n34\n may engage the casing \n13\n, the spring cone \n16\n may be compressed, and the elastomeric element \n28\n of the packer element \n26\n may seal an annulus between the liner and the casing \n13\n.', 'As shown in \nFIG. \n5\n, for example, the spring cone \n16\n gets solid and is in a compressed state after setting in accordance with one or more embodiments of the present disclosure.', 'Advantageously, according to one or more embodiments of the present disclosure, the lock ring \n22\n having the ratchet profile \n24\n of the spring cone \n16\n prevents the spring cone \n16\n from moving in an upward direction after compression.', 'Moreover, if an upward load in the liner hanger system \n10\n exceeds the hanging load provided by the lower slip \n14\n when engaged with the casing \n13\n, i.e., if load reversal occurs, the spring cone \n16\n relaxes in the upward direction and the downward direction.', 'That is, in case of any load reversal, the relaxation in the axial direction by the spring cone \n16\n will be compensated by the spring load.', 'As such, the lower slips \n14\n and elastomeric element \n28\n of the packer element \n26\n may be effectively spring loaded if load reversal occurs in accordance with one or more embodiments of the present disclosure.', 'Advantageously, the lock ring \n22\n having the ratchet profile \n24\n allows the spring cone \n16\n to relax independently in both directions.', 'Still referring to \nFIGS.', '4\n and \n5', ', it is not necessary to design the same slot pattern on both sides of the spring cone \n16\n.', 'Indeed, the load and possible deflection requirement for loading the lower slips \n14\n and elastomeric element \n28\n of the packer element \n26\n may be different.', 'Therefore, different spring performance may be designed on both sides to meet different requirements, according to one or more embodiments of the present disclosure.', 'Referring now to \nFIG.', '6\n, an example of spring cone \n16\n load-deflection performance according to one or more embodiments of the present disclosure is shown.', 'Specifically, \nFIG.', '6\n shows an example of the load deflection curve of the spring cone \n16\n.', 'As shown, at a setting load of about 60,000 lbs, for example, the spring cone \n16\n gets fully solid (i.e., fully closed as shown in \nFIG.', '5\n).', 'In case of any relaxation, due to the lock ring \n22\n having the ratchet profile \n24\n, the spring cone \n16\n is still able to provide sufficient load to maintain the setting position of the lower slips \n14\n and the elastomeric element \n28\n of the packer element \n26\n.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A system for hanging tubing in a wellbore, comprising:\na tubular body;\na plurality of lower slips mounted along the tubular body;\na spring cone disposed around the tubular body and fixed to the plurality of lower slips, the spring cone comprising a cone profile, a spring including a plurality of slots, and a lock ring including a ratchet profile, wherein the lock ring is disposed between a first slot and a second slot of the plurality of slots; and\na packer element disposed around the tubular body, below and adjacent the spring cone.', '2.', 'The system of claim 1, wherein the spring cone further comprises a cylinder having a plurality of sections arranged in sequence.', '3.', 'The system of claim 2, wherein each section of the plurality of sections comprises two or more slots of the plurality of slots.', '4.', 'The system of claim 3, wherein the plurality of slots comprises at least one straight cut slot.', '5.', 'The system of claim 3, wherein the plurality of slots comprises at least one radial cut slot.', '6.', 'The system of claim 3, wherein at least one slot of the plurality of slots comprises at least one nub.', '7.', 'The system of claim 1, wherein the spring cone is fixed to the plurality of lower slips with at least one shear screw.', '8.', 'The system of claim 1, further comprising:\nan upper cone disposed around the tubular body, the upper cone comprising an engagement profile; and\na plurality of upper slips comprising a corresponding profile to the engagement profile,\nwherein the plurality of upper slips is fixed to the upper cone.\n\n\n\n\n\n\n9.', 'A method, comprising:\nconveying a liner hanger system downhole into a cased wellbore, the liner hanger system comprising: a tubular body; a plurality of lower slips mounted along the tubular body; a spring cone disposed around the tubular body and fixed to the plurality of lower slips, the spring cone comprising: a spring including a plurality of slots; a lock ring including a ratchet profile, wherein the lock ring is disposed between a first slot and a second slot of the plurality of slots; and a cone profile; and a packer element disposed around the tubular body, below and adjacent the spring cone, the packer element comprising an elastomeric element;\nactuating the plurality of lower slips against the cone profile of the spring cone to create a setting load that forces the plurality of lower slips radially outward into engagement with a casing, and compresses the spring cone; and\ntransferring the setting load through the spring cone to energize the packer element to seal an annulus between a liner and the casing,\nwherein the lock ring having the ratchet profile prevents the spring cone from moving in an upward direction after compression.', '10.', 'The method of claim 9,\nwherein the plurality of lower slips provides a hanging load in a downward direction when engaged with the casing, and\nwherein, if an upward load in the liner hanger system exceeds the hanging load, a first portion the spring cone including the first slot relaxes in the upward direction and a second portion of the spring cone including the second slot relaxes in the downward direction.', '11.', 'The method of claim 10, wherein relaxation of the first portion of the spring cone in the upward direction and relaxation of the second portion of the spring cone in the downward direction maintains the plurality of lower slips in engagement with the casing, and keeps the packer element energized to seal the annulus between the liner and the casing.\n\n\n\n\n\n\n12.', 'The method of claim 9, wherein the liner hanger system is conveyed downhole into the cased wellbore using a running tool.', '13.', 'The method of claim 9, wherein the spring cone further comprises a cylinder having a plurality of sections arranged in sequence.', '14.', 'The method of claim 9, wherein the liner hanger system further comprises:\nan upper cone disposed around the tubular body, the upper cone comprising an engagement profile; and\na plurality of upper slips comprising a corresponding profile to the engagement profile,\nwherein the plurality of upper slips is fixed to the upper cone,\nthe method further comprising: actuating the plurality of upper slips against the engagement profile of the upper cone to force the plurality of upper slips radially outward into engagement with the casing.\n\n\n\n\n\n\n15.', 'A method of manufacture of a slotted cylindrical spring, comprising:\ndividing a cylinder into a plurality of sections arranged in sequence, a first section of the plurality of sections is disposed between a second section and a third section of the plurality of sections;\ncutting a plurality of slots into each section of the plurality of sections of the cylinder in a slot pattern to form the slotted cylindrical spring; and\ndisposing a lock ring including a ratchet profile on the first section after cutting the plurality of slots.', '16.', 'The method of claim 15, wherein cutting the plurality of slots comprises cutting at least one straight slot.', '17.', 'The method of claim 15, wherein cutting the plurality of slots comprises cutting at least one radial slot.', '18.', 'The method of claim 15, wherein at least one slot of the plurality of slots comprises at least one nub.', '19.', 'The method of claim 15, further comprising creating a cone profile near an end of the cylinder.']

['FIG.', '1 is an illustration of a liner hanger system with a spring cone according to one or more embodiments of the present disclosure;; FIG.', '2 is a slotted cylinder spring with associated geometric parameters according to one or more embodiments of the present disclosure;; FIGS.', '3A and 3B are examples of different types of slots according to one or more embodiments of the present disclosure;; FIG. 4 is a bi-directional spring cone before setting according to one or more embodiments of the present disclosure;; FIG.', '5 is a bi-directional spring cone after setting according to one or more embodiments of the present disclosure; and; FIG.', '6 is an example of spring cone load-deflection performance according to one or more embodiments of the present disclosure.']

US11774610

Methods and systems for concurrent land vibroseis acquisition with simultaneous activation

Sep 21, 2018

Nicolae Moldoveanu, Maurice Nessim, John Quigley, Wadii El Karkouri

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion for Application No. PCT/US2018/52191 dated Dec. 4, 2018.; Bouska, Jack, Distance Separated Simultaneous Sweeping, for Fast, Clean, Vibroseis Acquisition, Geophysical Prospecting, revision accepted Sep. 2009, pp. 123-153.; Howe, David et al., Independent Simultaneous Sweeping—A Method to Increase the Productivity of Land Seismic Crews, 2008, pp. 1-5.; Moldoveanu, Nick et al., High Fidelity Vibratory Seismic in a Difficult Geologic Area, 1999, pp. 1-4.; Translation of the official Notification dated Nov. 18, 2021 by the Patent Office of the Russian Federation, 9 pages.

6028818; February 22, 2000; Jeffryes; 6942059; September 13, 2005; Smith; 20090116337; May 7, 2009; Chiu; 20120075955; March 29, 2012; Dean; 20120147699; June 14, 2012; Dellinger; 20120314536; December 13, 2012; Bagaini; 20160077226; March 17, 2016; Bianchi

2015143189; September 2015; WO

['Land seismic survey including providing at least two vibrators in a first group, wherein each vibrator in the first group is assigned to a respective source line, where the source lines of the first group run substantially parallel to one another; providing at least two vibrators in a second group, wherein each vibrator in the second group is assigned to a respective source line that is different than the source lines assigned to vibrators from the first group; actuating the vibrators in the first group simultaneously using different frequency bandwidth sweeps and different phase encodings; actuating the vibrators in the second group at the same time as those in the first group, and simultaneously using different frequency bandwidth sweeps and different phase encodings; and detecting the resulting seismic signals with a plurality of seismic sensors that are placed in contact with the earth and as part of a seismic spread.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE TO RELATED APPLICATIONS', 'The present application claims priority to U.S. Provisional Application No. 62/561,836 that was filed on Sep. 22, 2017, that application being incorporated by reference herein in its entirety.', 'TECHNICAL FIELD', 'The present application and embodiments herein relate hydrocarbon exploration and associated land seismic vibroseis surveys for formation modeling, and more particularly to methods for performing such surveys with groups of multiple vibrators that are actuated simultaneously, and where individual vibrators in each group produce different frequency bandwidth sweeps.\n \nBACKGROUND\n \nDescription in the background section is meant to help one skilled in the art understand some of the embodiments described herein, and is not meant to in any way to unduly limit or otherwise unduly influence any subsequent interpretation of present or future claims related to the present application.', 'A first stage in hydrocarbon exploration generally is seismic exploration.', 'Seismic exploration is used to derive information about subsurface features of the proposed exploration area, that can indicate a presence, or lack thereof, of various minerals and natural items, such as hydrocarbons.', 'Once a likely presence of hydrocarbons is determined, and features of that deposit are determined, extraction may be planned for and eventually take place.', 'Hydrocarbon extraction involves drilling into an earth formation to establish a well hole, completing that well hole, and several other similarly expensive steps before hydrocarbons can be extracted.', 'It is a very expensive and time-consuming process that creates a premium value for information that can help improve a likelihood of drilling a well such as to successfully access and produce hydrocarbons.', 'One way of performing seismic exploration is with vibroseis land surveys.', 'In a vibroseis land survey, moveable vibrators (vibroseis units) are used to impute vibration signals into the earth surface, that then reverberate and reflect when encountering formation features, and return to surface.', 'Those signals are detected by seismic sensors that then store/rout the data to a central storage computer memory.', 'The seismic sensors may detect magnitude, particle motion, particle direction and/or pressure.', 'Commercial land seismic surveys use large numbers of seismic sensors that provide large amounts of data that when analyzed can provide information indicating various attributes of the earth formation.', 'The information can indicate the presence, or lack thereof, of hydrocarbons and other minerals and formation attributes.', 'It is valuable for one skilled in the art to understand the magnitude of normal successful land surveys.', 'Often a successful land survey will involve tens, if not hundreds, of thousands of individual land sensors.', 'At a cost of $10-100 per sensor it is normal that the hardware for a survey can be in the range of $100,000 to more than $100,000,000.', 'With that high cost of equipment, one way to reduce overall cost is to survey one portion of a survey area with a defined receiver patch, and then move the receiver patch and recording equipment to another portion of the survey area.', 'With that, one can use less equipment and yet end up surveying the entire desired area.', 'It should also be appreciated that the time it takes to perform a survey is important, especially in view of using the above noted technique of moving equipment from location to location.', 'SUMMARY\n \nThe following summary is meant to aid the understanding of one skilled in the art with regard to embodiments described herein and related claims and is not meant in any way to unduly limit any claims herein or related claims thereto.', 'A combination of various embodied features includes a method of performing a land seismic vibroseis survey, providing at least two vibrators in a first group, wherein each vibrator in the first group is assigned to a respective source line, where the source lines of the first group run substantially parallel to one another; providing at least two vibrators in a second group, wherein each vibrator in the second group is assigned to a respective source line that is different than the source lines assigned to vibrators from the first group; actuating the vibrators in the first group simultaneously using different frequency bandwidth sweeps and different phase encodings; actuating the vibrators in the second group at the same time as those in the first group, and simultaneously using different frequency bandwidth sweeps and different phase encodings; and detecting the resulting seismic signals with a plurality of seismic sensors that are placed in contact with the earth and as part of a seismic spread.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The following brief description of the drawings is meant to aid the understanding of one skilled in the art when reviewing this document and any associated claims, and is not meant in any way to unduly limit those or any future related claims.\n \nFIG.', '1\n: shows features relating to a simultaneous vibroseis surveys with two vibrators shooting.\n \nFIG.', '2\n: shows vibroseis concurrent acquisition with 2 groups of vibroseis units separated by a predefined distance; in each group the vibrators sweep simultaneously using split bandwidth sweeps; each vibrator group is independent of each other.\n \nFIG.', '3\n: is a Composite amplitude spectrum of 4 split bandwidth sweeps listed in Table 1.\n \nFIG.', '4\n: shows two ways to acquire encoded sweeps with 4 split_bandwidth and phase encoded: sweep1-listen_time, sweep2_listen_time, sweep3_listen_time, sweep4_lisyen time ((ex: for 5 sec sweep and 6 sec listen_time total time=44 sec); sweep1, sweep2, sweep3, sweep4, listen_time (ex: for 5 sec sweep and 6 sec listen_time total time=26 sec).', 'FIG.', '5\n: shows examples of shot records for conventional acquisition (20 sec sweep, 6 listening) (left) vs. embodiments of the method described herein with encoded sweeps (right).\n \nFIG.', '6\n: shows vibroseis concurrent acquisition with four groups of vibroseis units separated by a predefined distance; in each group the vibrators sweep simultaneously using encoded sweeps; each vibrator group is independent of each other.', 'DETAILED DESCRIPTION', 'The following detailed description is meant to aid the understanding of one skilled in the art regarding the various combinations of embodied features described herein and in the claims, as well as future related claims.', 'It is in no way meant to unduly limit those present or future claims.', 'A challenge to the noted issue of survey speed is the ability to activate vibrators at the same time (or very near thereto) at different locations around a seismic sensor spread (receiver patch).', 'If many shot points can be acquired at the same time or nearly the same time, the receiver patch can be moved quickly to the new location and the total duration of the survey can be reduced.', 'Unfortunately, when vibrators are actuated too close to one another and at the same time or nearly the same time, the signals can interfere with one another when detected by a sensor, thereby degrading the detected data.', 'The present application describes embodiments relating to new and novel method(s) of actuating land seismic vibrators and performing a seismic survey that provides improved efficiencies to dramatically improve commercial results in the areas of cost, time and efficiency in connection with a land seismic survey.', 'The present application relates to methods for conducting a land seismic survey using a plurality of land seismic sensors in connection with a plurality of land seismic vibroseis units.', 'In land seismic vibroseis surveying, and according to embodiments herein, a large number of seismic survey sensors are distributed in connection with the earth.', 'It is possible to use at any one time 10,000, 20,000, 50,000, 100,000 and even up to and more than 200,000 individual land sensors in a survey.', 'Further, it is possible to move a land survey spread involving those numbers of sensors from one area to an adjacent area to eventually complete survey of a total area.', 'As part of a seismic survey, a vibratory impulse is imputed into the earth.', 'In a simple manner, an impulse can be actuated at any one time.', 'However, using that simple method ensures that the survey will take a very long time and will be commercially less efficient and successful.', 'To improve efficiencies, it is desirable to operate multiple vibrators at the same time.', 'However, complications can arise in that scenario if the signals interfere with one another when detected by a sensor.', 'There are a number of ways to address that issue, such as encoding the signals, and or other separation techniques.', 'Processing of the data acquired with current land simultaneous shooting treat the seismic interference as noise and noise attenuation methods are applied for active source separation.', 'To achieve successful results, the vibrator units that are firing at the same time need to be separated by a large distance and thus creates a need to use a large receiver spread.', 'In the present application various embodiments are disclosed that allow closer intervals between vibrator units and also deployment of a smaller receiver spread\n \nAccording to various embodiments, efficiency of a vibroseis survey can be increased if one or more groups of vibrators shoot concurrently over a receiver (sensor) spread.', 'Each group of vibrators may include at least 2, 3 or 4 vibroseis units and each vibroseis unit in a group may sweep at a different frequency bandwidth sweep.', 'In each vibroseis unit could be 1, 2 or more vibrators.', 'There are various mechanical configurations for a vibroseis unit.', 'As shown in \nFIG.', '1\n, various features of a simultaneous shooting survey are shown as used for vibroseis land surveys, where the sources (vibroseis units identified as V1 and V2) actuate simultaneously and are separated by a distance in space or can be separated by a firing time interval.', 'If either time separation (slip sweep) or distance separation are employed properly a signal in the defined target area will not undesirably interfere with one another.\n \nFIG.', '2\n shows a group of four vibroseis units (V1, V2, V3, V4) operating as and in a group.', 'The four vibroseis units (V1, V2, V3, V4) are placed on four adjacent and substantially parallel source lines 1.', 'A source line is a track (imaginary line) that the vibroseis unit is to move along and occasionally activate at predetermined locations and in a predetermined way.', 'Receiver lines 2 are perpendicular to the source lines 1.', 'As shown in \nFIG.', '2\n, one of the vibroseis devices (V1, V2, V3, V4) is a single vibroseis unit (in some cases a truck).', 'In each group, a vibroseis unit is placed in a respective track as shown, and each vibroseis unit activates simultaneously producing a different frequency bandwidth sweep with a different phase encoding.', 'If for conventional vibroseis acquisition the sweep frequency is 2-90 Hz and the sweep length is 20 sec., with a single sweep per shot point, one implementation is to split 2-90 Hz sweep in four parts, each part having a different bandwidth and different phase.', 'The length of each sweep can then be 5 seconds.', 'Such an embodiment may be: V1: 2-27 Hz, phase=0°; V2=24-48 Hz, phase=90°; V3=45-69 Hz, phase=180°, V4=66-90 Hz, phase=270°.', 'In that case, each vibroseis device stays on the same shot point and sweeps four times, each time with a different bandwidth.', 'This scenario is outlined and described in Table 1.', 'In Table 1, split bandwidth sweeps for a group of four vibroseis devices are placed on four different source lines 1, where each vibroseis device sweeps four times at a same location.', 'TABLE 1\n \n \n \n \n \n \n \n \n \n \nShot\n \nSweep\n \nListening\n \n \n \nSP-11 (line-1)\n \nSP-21 (line-2)\n \nSP-31 (line-3)\n \nSP-41 (line-4)\n \nnumber\n \nlength\n \ntime\n \n \n \n \n \n \n \n \nV\n1\n: 2-27 Hz\n \nV\n2 \n= 24-48 Hz\n \nV\n3 \n= 45-69 Hz\n \nV\n4 \n= 66-90 Hz\n \nShot-1\n \n5 sec.', '6 sec.', 'Phase = 0°\n \nPhase = 90°\n \nPhase = 180°\n \nPhase = 270°\n \n \n \n \n \n \nV\n1 \n= 24-48 Hz\n \nV\n2 \n= 45-69 Hz\n \nV\n3 \n= 66-90 Hz\n \nV\n4 \n= 2-27 Hz\n \nShot-2\n \n5 sec.\n \n6 sec.', 'Phase = 90°\n \nPhase = 180°\n \nPhase = 270°\n \nPhase = 0°\n \n \n \n \n \n \nV\n1 \n= 45-69 Hz\n \nV\n2 \n= 66-90 Hz\n \nV\n3 \n= 2-27 Hz\n \nV\n4 \n= 24-48 Hz\n \nShot-3\n \n5 sec.', '6 sec.', 'Phase = 180°\n \nPhase = 270°\n \nPhase = 0°\n \nPhase = 90°\n \n \n \n \n \n \nV\n1 \n= 66-90 Hz\n \nV\n2 \n= 2-27 Hz\n \nV\n3 \n= 24-48 Hz\n \nV\n4 \n= 45-69 Hz\n \nShot-4\n \n5 sec.', '6 sec.', 'Phase = 270°\n \nPhase = 0°\n \nPhase = 90°\n \nPhase = 180°\n \n \n \n \n \n \n \n \n \n \nAccording to embodiments shown in \nFIG.', '1\n and described in Table 1, to recover a full bandwidth of 2-90 Hz, each shot can be correlated with a proper sweep for each vibroseis device and a vertical sum of the four shots on the same location are performed after correlation.', 'The resulting small overlap between the consecutive frequency bandwidth and the taper applied for each sweep are designed to provide a continuous composite spectrum as shown in \nFIG.', '3\n.', 'According to a combination of various embodied features, vibroseis units can be placed at certain distances from one another and can generate sweeps as those described in Table 1.', 'In that scenario, the phase for each sweep in group-2 can be encoded, such as: 45°, 135°, 225° and 315°.', 'In that scenario, the distance between the groups can be based on a survey design and modeling study to assure that the effect of seismic interference in the target zone is minimized to an acceptable level.', 'The second group of vibroseis units may shoot independently of the first group of vibroseis units.', 'In the scenarios described herein, the number of vibroseis unit groups can be more than two, depending on the survey size.', 'Each vibrator group can have a different number of vibroseis units, and can be 2, 3, 4 or more.', 'A comparison between the sweeping time with an embodied method versus a conventional shooting (no simultaneous shooting) is presented in Table 2 below.', 'Table 2 is a comparison between sweeping time for conventional acquisition (no simultaneous shooting) and split bandwidth simultaneous shooting with one group and two groups of four vibroseis units.', 'TABLE 2\n \n \n \n \n \n \n \n \n \n \nSplit bandwidth simultaneous \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nConventional\n \nshooting with 4 vibroseis \n \nSplit bandwidth simultaneous\n \n \n \n \nshooting with a\n \nunits on 4 source lines\n \nshooting with 8 vibroseis \n \n \n \n \n \n \n \n \n \n \n \n \n \nsingle sweep and a\n \ns + l + s + l + s + l + s + l\n \n \nunits on 8 source lines\n \n \n \n \n \n \n \n \n \n \n \n \n \nAcquisition\n \nvibroseis unit on 1\n \ns = sweep time\n \ns', '+ s + \n \ns + l', '+ s + l', '+\n \ns + s + \n \n \n \nparameters\n \nsource line\n \nl = listening time\n \ns', '+ s + l\n \ns + l', '+ s + l\n \ns + s + l', 'Sweep length\n \n20 sec.', '5 sec.', '5 sec.', '5 sec.', '5 sec.', 'Listening time\n \n\u20026 sec.', '6 sec.', '6 sec.\n \n\u20026 sec.', '6 sec.', 'Number of active\n \n1\n \n4\n \n4\n \n8\n \n8\n \n \n \nshot lines\n \n \n \n \n \n \n \n \nNumber of\n \n1\n \n4\n \n4\n \n4\n \n4\n \n \n \nsweeps per\n \n \n \n \n \n \n \n \nvibroseis point\n \n \n \n \n \n \n \n \nTotal time per\n \n26 sec.', '11 sec.\n \n6.5 sec.', '11 sec.\n \n6.5 sec.', 'vibroseis point\n \n \n \n \n \n \n \n \nfor a source line\n \n \n \n \n \n \n \n \nTotal time per\n \n26*4 = 104 sec.', '44 sec.\n \n\u200926 sec.', '44 sec.\n \n\u200926 sec.', 'vibroseis point\n \n \n \n \n \n \n \n \nfor 4 source lines\n \n \n \n \n \n \n \n \nTotal time per\n \n26*8 = 208 sec.', '44 sec.\n \n\u200926 sec.', '44 sec.\n \n\u200926 sec.', 'vibroseis point\n \n \n \n \n \n \n \n \nfor 8 source\n \n \n \n \n \n \n \n \nlines\n \n \n \n \n \n \n \n \n \n \nAccording to embodiments herein, in order to reduce the total line time per vibroseis source points the four sweeps, V1, V2, V3, V4 can be concatenated to eliminate the listening time for V1, V2, and V3.', 'In that scenario, the total time for sweeping at four source locations is 26 seconds instead of 44 seconds.', 'This is illustrated in \nFIG.', '4\n.', 'It should be appreciated that a savings of 16 second per shot location, in the context of a large land seismic survey is multiplied many thousands of times and produces a significant improvement in time efficiency, commercial viability, and success of a land seismic vibroseis survey.', 'Another group of 4 vibroseis units can be placed at a certain distance and will generate the same sweeps as is described in Table 1.', 'The phase for each sweep in group-2 will be also encoded, for example: 45°, 135°, 225° and 315°.', 'The distance between groups can be based on survey design and modeling study to assure that the effect of seismic interference in the target zone is minimized.', 'The second group of vibroseis units is shot independently of the first group of vibroseis units.', 'The number of the vibroseis unit groups may be more than two, depending on the survey size.', 'FIG.', '6\n shows four vibrator groups, each group with four vibrator (units and each vibrator group working independently.\n \nFIG.', '6\n shows vibroseis concurrent acquisition with four groups of vibroseis units separated by a predefined distance where in each group the vibrators sweep simultaneously using encoded sweeps, and each vibrator group is independent of each other.', 'Each vibrator group could have a different number of vibroseis units, typically, 2, 3, or 4.', 'During operations the number of units per group could be changed to accommodate the operational conditions.', 'Changes can be included in the shooting plan prepared during survey planning.', 'As shown in \nFIG.', '6\n, two groups of vibrator units (V1, V2, V3, V4) may share source lines wherein the source lines of each group are collinear, or the same, as those of another group.', 'If one or more vibrator units are not at the required locations due to different field conditions (ex. obstructions)', 'the vibrators could sweep the same sequence of sweeps at the current locations, provided the x,y,z coordinates are recorded based on Global Positioning System (GPS) and altimetry measurements.', 'That actuation method gives flexibility in operations and could minimize the non-productive time.', 'According to present embodiments, new methods and systems for performing land seismic vibroseis surveys are disclosed.', 'However, no matter how efficient such a method is and what commercial improvements are realized, it is all for not if the actual seismic data results are inadequate.', 'According to the present disclosure and according to experimentation it has been shown that survey results using the present embodiments are similar to, if not better than, conventional more inefficient methods.', 'This is shown in \nFIG.', '5\n.', 'A comparison of data acquired with conventional acquisition (20 second length and 6 second listening time, one shot point at each time) vs shooting with four vibrators placed on four different lines, simultaneously, each vibrator shooting a different split bandwidth sweep (5 second length and 6 second listening time) is shown in \nFIG.', '5\n.', 'While the present disclosure relates to a limited number of embodiments, those skilled in the art, having the benefit of this disclosure, will appreciate that numerous modifications and variations therefrom are possible while staying within the scope of the disclosure herein.', 'It is intended that the appended claims cover such modifications and variations as fall within the true spirit and scope of the disclosure recited herein.']

['1.', 'A method for performing a land seismic vibroseis survey, comprising:\nproviding a first plurality of vibrators in a first group, wherein each vibrator in the first group is assigned to a respective source line of a first plurality of source lines, where the source lines of the first plurality of source lines run substantially parallel to one another;\nproviding a second plurality of vibrators in a second group, wherein each vibrator in the second group is assigned to a respective source line of a second plurality of source lines that is different than the first plurality of source lines;\nactuating each vibrator of the first plurality of vibrators simultaneously, wherein each vibrator of the first plurality of vibrators uses a first set of frequency bandwidth sweeps and a first set of phase encodings, wherein the first set of frequency bandwidth sweeps comprises a different frequency bandwidth sweep for each vibrator of the first plurality of vibrators, wherein a first plurality of pairs of frequency bandwidth sweeps of the first set of frequency bandwidth sweeps comprises one or more overlapping frequencies, and wherein the first set of phase encodings comprises a different phase encoding for each vibrator of the first plurality of vibrators;\nactuating each vibrator of the second plurality of vibrators at the same time as each vibrator of the first plurality of vibrators, wherein each vibrator of the second plurality of vibrators uses a second set of frequency bandwidth sweeps and a second set of phase encodings, wherein the second set of frequency bandwidth sweeps comprises a different frequency bandwidth sweep for each vibrator of the second plurality of vibrators, and wherein the second set of phase encodings comprises a different phase encoding for each vibrator of the second plurality of vibrators, wherein each frequency bandwidth sweep of the first set of frequency bandwidth sweeps covers an exact same frequency range as each respective frequency bandwidth sweep of the second set of frequency bandwidth sweeps; and\ndetecting one or more resulting seismic signals with a plurality of seismic sensors that are placed in contact with the earth and as part of a seismic spread.', '2.', 'The method of claim 1, comprising a third plurality of vibrators in a third group, wherein each vibrator of the third plurality of vibrators is assigned to a respective source line of a third plurality of source lines, where the source lines of the third plurality of source lines run substantially parallel to one another.\n\n\n\n\n\n\n3.', 'The method of claim 2, comprising a fourth plurality of vibrators in a fourth group, wherein each vibrator of the fourth plurality of vibrators is assigned to a respective source line of a fourth plurality of source lines, where the source lines of the fourth plurality of source lines run substantially parallel to one another.', '4.', 'The method of claim 1, wherein the source lines of the first group are not shared with the source lines of the second group.', '5.', 'The method of claim 2, wherein the source lines of the first group and the source lines of the third group are shared.', '6.', 'A method of seismic vibroseis surveying, comprising:\na first vibrator group comprising four vibrators, V1, V2, V3 and V4, wherein each of the four vibrators is located on a different source line, wherein each different source line running parallel to one another,\nthe V1 being actuated for a shot 1 between 2-27 Hz and at a phase of 0 degrees, V2 being simultaneously actuated for the shot 1 between 24-48 Hz and at a phase of 90 degrees, V3 being simultaneously actuated for the shot 1 between 45-69 Hz and at a phase of 180 degrees, and V4 being simultaneously actuated for the shot 1 between 66-90 Hz and at a phase of 270 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 is simultaneously actuated with each other.', '7.', 'The method of claim 6, wherein:\nthe V1 being actuated for a shot 2 between 24-48 Hz and at a phase of 90 degrees, V2 being simultaneously actuated for the shot 2 between 45-69 Hz and at a phase of 180 degrees, V3 being simultaneously actuated for the shot 2 between 66-90 Hz and at a phase of 270 degrees, and V4 being simultaneously actuated for the shot 2 between 2-27 Hz and at a phase of 0 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 is simultaneously actuated with each other.', '8.', 'The method of claim 7, wherein:\nthe V1 being actuated for a shot 3 between 45-69 Hz and at a phase of 180 degrees, V2 being simultaneously actuated for the shot 3 between 66-90 Hz and at a phase of 270 degrees, V3 being simultaneously actuated for the shot 3 between 2-27 Hz and at a phase of 0 degrees, and V4 being simultaneously actuated for the shot 3 between 24-48 Hz and at a phase of 90 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 is simultaneously actuated with each other.', '9.', 'The method of claim 8, wherein:\nthe V1 being actuated for a shot 4 between 66-90 Hz and at a phase of 270 degrees, V2 being simultaneously actuated for the shot 4 between 2-27 Hz and at a phase of 0 degrees, V3 being simultaneously actuated for the shot 4 between 24-48 Hz and at a phase of 90 degrees, and V4 being simultaneously actuated for the shot 4 between 45-69 Hz and at a phase of 180 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 is simultaneously actuated with each other.', '10.', 'A system for performing a land seismic vibroseis survey, comprising:\na first plurality of vibrators in a first group, wherein each vibrator in the first group is assigned to a respective source line of a first plurality of source lines, wherein each source line of the first plurality of source lines run substantially parallel to one another and each vibrator of the first plurality of vibrators is actuated simultaneously using a first set of frequency bandwidth sweeps and a first set of phase encodings, wherein the first set of frequency bandwidth sweeps comprises a different frequency bandwidth sweep for each vibrator of the first plurality of vibrators, wherein a first plurality of pairs of frequency bandwidth sweeps of the first set of frequency bandwidth sweeps comprises one or more overlapping frequency ranges, and wherein the first set of phase encodings comprises a different phase encoding for each vibrator of the first plurality of vibrators;\na second plurality of vibrators in a second group, wherein each vibrator in the second group is assigned to a respective source line of a second plurality of source lines, where each source line of the second plurality of source lines run substantially parallel to one another and each vibrator of the second plurality of vibrators is actuated simultaneously as each vibrator of the first plurality of vibrators, wherein each vibrator of the second plurality of vibrators uses a second set of frequency bandwidth sweeps and a second set of phase encodings, wherein the second set of frequency bandwidth sweeps comprises a different frequency bandwidth sweep for each vibrator of the second plurality of vibrators, and wherein the second set of phase encodings comprises a different phase encoding for each vibrator of the second plurality of vibrators, wherein each frequency bandwidth sweep of the first set of frequency bandwidth sweeps covers an exact same frequency range as each respective frequency bandwidth sweep of the second set of frequency bandwidth sweeps; and\na plurality of seismic sensors configured to be placed in contact with the earth and as part of a seismic spread for detecting one or more resulting seismic signals.', '11.', 'The system of claim 10, wherein the first plurality of source lines is not shared with the second plurality of source lines.', '12.', 'The system of claim 10, comprising a third plurality of vibrators in a third group, wherein each vibrator in the third group is assigned to a respective source line of a third plurality of source lines, where each source line of the third plurality of source lines runs substantially parallel to one another.\n\n\n\n\n\n\n13.', 'The system of claim 12, comprising a fourth plurality of vibrators in a fourth group, wherein each vibrator in the fourth plurality of vibrators is assigned to a respective source line of a fourth plurality of source lines, wherein each source line of the fourth plurality of vibrators runs substantially parallel to one another.', '14.', 'The system of claim 12, wherein the first plurality of source lines and the third plurality of source lines are shared.', '15.', 'The system of claim 10, wherein the first plurality of vibrators comprises four vibrators, a vibrator V1, a vibrator V2, a vibrator V3, and a vibrator V4, wherein each of the four vibrators is located on a different source line running parallel to another source line, and wherein a first vibrator of the four vibrators is actuated for a shot 1 between 2-27 Hz and at a phase of 0 degrees, a second vibrator of the four vibrators is simultaneously actuated for the shot 1 between 24-48 Hz and at a phase of 90 degrees, a third vibrator of the four vibrators is simultaneously actuated for the shot 1 between 45-69 Hz and at a phase of 180 degrees, and a fourth vibrator of the four vibrators is simultaneously actuated for the shot 1 between 66-90 Hz and at a phase of 270 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 is simultaneously actuated with each other.', '16.', 'The system of claim 15, wherein the first vibrator is actuated for a shot 2 between 24-48 Hz and at a phase of 90 degrees, the second vibrator of the four vibrators is simultaneously actuated for the shot 2 between 45-69 Hz and at a phase of 180 degrees, the third vibrator of the four vibrators is simultaneously activated for the shot 2 between 66-90 Hz and at a phase of 270 degrees, and the fourth vibrator of the four vibrators is simultaneously actuated for a shot 2 between 2-27 Hz and at a phase of 0 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 is simultaneously actuated with each other.', '17.', 'The system of claim 16, wherein the first vibrator of the four vibrators is actuated for a shot 3 between 45-69 Hz and at a phase of 180 degrees, the second vibrator of the four vibrators is simultaneously actuated for the shot 3 between 66-90 Hz and at a phase of 270 degrees, the third vibrator of the four vibrators is simultaneously activated for the shot 3 between 2-27 Hz and at a phase of 0 degrees, and the fourth vibrator of the four vibrators is simultaneously actuated for the shot 3 between 24-48 Hz and at a phase of 90 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 are simultaneously actuated with each other.', '18.', 'The system of claim 17, wherein the first vibrator of the four vibrators is actuated for a shot 4 between 66-90 Hz and at a phase of 270 degrees, the second vibrator of the four vibrators is simultaneously actuated for the shot 4 between 2-27 Hz and at a phase of 0 degrees, the third vibrator of the four vibrators is simultaneously actuated for the shot 4 between 24-48 Hz and at a phase of 90 degrees, and the fourth vibrator of the four vibrators is simultaneously actuated for the shot 4 between 45-69 Hz and at a phase of 180 degrees, wherein a plurality of the vibrator V1, the vibrator V2, the vibrator V3, and the vibrator V4 is simultaneously actuated with each other.', '19.', 'The system of claim 10, wherein each vibrator of the second plurality of vibrators is placed at a set of a plurality of sets of distances from each vibrator of the first plurality of vibrators, wherein the plurality of sets of distances are based on a survey design and modeling study to assure that an effect of seismic interference in a target zone is less than a threshold level.', '20.', 'The system of claim 10, wherein the second group has a different number of vibrators from the first group.']

['FIG.', '1: shows features relating to a simultaneous vibroseis surveys with two vibrators shooting.; FIG.', '2: shows vibroseis concurrent acquisition with 2 groups of vibroseis units separated by a predefined distance; in each group the vibrators sweep simultaneously using split bandwidth sweeps; each vibrator group is independent of each other.; FIG.', '3: is a Composite amplitude spectrum of 4 split bandwidth sweeps listed in Table 1.; FIG.', '4: shows two ways to acquire encoded sweeps with 4 split_bandwidth and phase encoded: sweep1-listen_time, sweep2_listen_time, sweep3_listen_time, sweep4_lisyen time ((ex: for 5 sec sweep and 6 sec listen_time total time=44 sec); sweep1, sweep2, sweep3, sweep4, listen_time (ex: for 5 sec sweep and 6 sec listen_time total time=26 sec).', '; FIG.', '5: shows examples of shot records for conventional acquisition (20 sec sweep, 6 listening) (left) vs. embodiments of the method described herein with encoded sweeps (right).; FIG.', '6: shows vibroseis concurrent acquisition with four groups of vibroseis units separated by a predefined distance; in each group the vibrators sweep simultaneously using encoded sweeps; each vibrator group is independent of each other.; FIG.', '2 shows a group of four vibroseis units (V1, V2, V3, V4) operating as and in a group.', 'The four vibroseis units (V1, V2, V3, V4) are placed on four adjacent and substantially parallel source lines 1.', 'A source line is a track (imaginary line) that the vibroseis unit is to move along and occasionally activate at predetermined locations and in a predetermined way.', 'Receiver lines 2 are perpendicular to the source lines 1.', 'As shown in FIG.', '2, one of the vibroseis devices (V1, V2, V3, V4) is a single vibroseis unit (in some cases a truck).', 'In each group, a vibroseis unit is placed in a respective track as shown, and each vibroseis unit activates simultaneously producing a different frequency bandwidth sweep with a different phase encoding.', 'If for conventional vibroseis acquisition the sweep frequency is 2-90 Hz and the sweep length is 20 sec., with a single sweep per shot point, one implementation is to split 2-90 Hz sweep in four parts, each part having a different bandwidth and different phase.', 'The length of each sweep can then be 5 seconds.', 'Such an embodiment may be: V1: 2-27 Hz, phase=0°; V2=24-48 Hz, phase=90°; V3=45-69 Hz, phase=180°, V4=66-90 Hz, phase=270°.', 'In that case, each vibroseis device stays on the same shot point and sweeps four times, each time with a different bandwidth.', 'This scenario is outlined and described in Table 1.', 'In Table 1, split bandwidth sweeps for a group of four vibroseis devices are placed on four different source lines 1, where each vibroseis device sweeps four times at a same location.; FIG.', '6 shows vibroseis concurrent acquisition with four groups of vibroseis units separated by a predefined distance where in each group the vibrators sweep simultaneously using encoded sweeps, and each vibrator group is independent of each other.']

US11827838

Polymeric amidoamine emulsifiers

May 15, 2020

Dimitri M. Khramov, Stephen Cliffe, Reda Karoum

SCHLUMBERGER TECHNOLOGY CORPORATION

Exam Report issued in United Kingdom Patent Application No. GB2116452.0 dated Aug. 26, 2022, 6 pages.

20040259738; December 23, 2004; Patel; 20070093393; April 26, 2007; Navarrete et al.; 20110160099; June 30, 2011; Patel et al.; 20170283680; October 5, 2017; Chen; 20180244976; August 30, 2018; Cliffe

2017081325; May 2017; WO; 2017173010; October 2017; WO; 2019028198; February 2019; WO

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['Wellbore fluids may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; and a polymeric amidoamine emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the polymeric amidoamine emulsifier has at least 5 repeating units.', 'Wellbore fluids may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; and a polymeric amidoamine emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the polymeric amidoamine emulsifier includes at least 3 repeating units selected from allylamine, polyaminopolyamide, N-alkyl acrylamides, (meth)acrylic acid, alkyleneamine reacted with a dicarboxylic acid, alpha-olefin-alt-maleic anhydride, styrene maleic anhydride, alkylene oxide, wherein one or more amine or acid group on the repeating unit is amidized.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE PARAGRAPH\n \nThis application claims the benefit of U.S. Provisional Application No. 62/848,273 entitled “Polymeric Amidoamine Emulsifiers,” filed May 15, 2019, the disclosure of which is incorporated herein by reference.', 'BACKGROUND\n \nDuring wellbore operations, various fluids may be used in the well for a variety of functions.', 'The fluids may be circulated through a bore hole, which may subsequently flow upward through the wellbore to the surface.', 'During this circulation, the drilling fluid may remove drill cuttings from the bottom of the hole to the surface, to suspend cuttings and weighting material when circulation is interrupted, to control subsurface pressures, to maintain the integrity of the wellbore until the well section is cased and cemented, to isolate the fluids from the formation by providing sufficient hydrostatic pressure to prevent the ingress of formation fluids into the wellbore, to cool and lubricate the drill string and bit, and/or to maximize penetration rate.', 'Drilling fluids are typically classified according to their base material; in oil based fluids, solid particles are suspended in oil, and water or brine may be emulsified with the oil.', 'The oil is typically the continuous phase.', 'In water base fluids, solid particles are suspended in water or brine, and oil may be emulsified in the water.', 'The water is typically the continuous phase.', 'Pneumatic fluids are a third class of drilling fluids in which a high velocity stream of air or natural gas removes drill cuttings.', 'Oil-based wellbore fluids such as invert emulsion muds include an oleaginous liquid such as hydrocarbon oil which serves as a continuous phase, a non-oleaginous liquid such as water or brine solution which serves as a discontinuous phase, and an emulsifying agent.', 'Emulsifying agents may be used to lower the interfacial tension of the liquids so that the non-oleaginous liquid may form a stable dispersion of fine droplets in the oleaginous liquid.', 'Additionally, such invert emulsion fluids may contain one or more weighting agents, surfactants, viscosifiers, fluid loss control agents or bridging agents.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'In one aspect, embodiments of the present disclosure are directed to wellbore fluids that may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; and a polymeric amidoamine emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the polymeric amidoamine emulsifier has at least 5 repeating units.', 'In another aspect, embodiments of the present disclosure are directed to wellbore fluids that may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; and a polymeric amidoamine emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the polymeric amidoamine emulsifier includes at least 3 repeating units selected from allylamine, polyaminopolyamide, N-alkyl acrylamides, (meth)acrylic acid, alkyleneamine reacted with a dicarboxylic acid, alpha-olefin-alt-maleic anhydride, styrene maleic anhydride, alkylene oxide, wherein one or more amine or acid group on the repeating unit is amidized.', 'In yet another aspect, embodiments of the present disclosure may include methods of drilling a wellbore with an oil-based mud, wherein the oil-based mud is an invert emulsion including an emulsifier stabilizing the invert emulsion, wherein the emulsifier is the product of a reaction between an alkyl cyclic anhydride and a polar reactant.', 'wherein the polar reactant is one or more selected from poly(allylamine), poly(ethyleneimine), polyaminopolyamide, and polyacrylamide.', 'Other aspects and advantages of the claimed subject matter will be apparent from the following description and the appended claims.', 'DETAILED DESCRIPTION', 'This disclosure relates generally to emulsifier compositions used to stabilize invert emulsions.', 'In one or more embodiments, emulsifiers in accordance with the present disclosure may include polymeric amidoamine based emulsifiers.', 'In some embodiments, emulsifiers may promote invert emulsion stability at high-pressure high-temperature (HPHT) conditions such as those encountered within a wellbore.', 'Conventional emulsifiers used in wellbore applications to stabilize emulsions may undergo degradation in extreme conditions, leading to fluid instability, sagging, and phase separation.', 'For example, emulsifiers conventionally used in oil-based muds may be susceptible to hydrolytic degradation because the aqueous phases may contain substantial amounts of caustic materials such as lime and elevated pHs that can initiate hydrolysis of labile bonds in the emulsifier, particularly at elevated temperatures.', 'Polymeric amidoamine emulsifiers in accordance with the present, disclosure may be used to prepare emulsified wellbore fluids, including water-in-oil or invert emulsions in which an aqueous internal phase is stabilized by a surfactant in an oil continuous phase.', 'The presently described surfactants, such as polyamidoamine surfactants, are polymers comprised of units that often have a hydrophobic portion of the molecule that interacts with oleaginous fluids and a hydrophilic, often polar, portion of the molecule that interacts with aqueous fluids.', 'When combined with a mixture of aqueous and oleaginous fluids, the surfactant orients at the interface between the phases and forms a micelle.', 'Depending on the balance between the hydrophobic and hydrophilic portions of the molecules, surfactants may form stronger barriers between the phases and more stable emulsions.', 'In one or more embodiments, polymeric amidoamine emulsifiers may be used as emulsifiers for formulating oil-based muds.', 'Further, emulsifiers in accordance with the present disclosure may have favorable impacts on wellbore fluid rheology, including improving pumpability and preventing particulate sag and shale dispersion.', 'Polymeric amidoamine emulsifiers may also be prepared from synthetic polymers, which may be tuned to control molecular weight and degree of branching, allowing a greater degree of flexibility over conventional fatty acid-based surfactants derived from smaller and/or natural compounds.', 'The tunable ratio of the polymeric constituents of the emulsifier also makes it possible to control polymerization and select the hydrophilic/lipophilic balance (HLB) ratio of the emulsifiers.', 'Polymeric amidoamine emulsifiers in accordance with the present disclosure may include linear and/or branched structures that occupy larger footprints on the surface of emulsion micelles than emulsifiers prepared via conventional routes (and which may be smaller molecules), and further may have a decreased tendency to crystallize out of solution or develop unreasonably high or low temperature rheology in various base oils.', 'As mentioned, the polymeric nature of the polymeric amidoamine emulsifiers may result in a larger molecule than conventional amidoamine emulsifiers.', 'For example, in one or more embodiments, the polymeric amidoamine emulsifiers may have at least three or at least five repeating units.', 'However, it is also envisioned that there may be at least ten or more repeating units if larger molecules are used.', 'Thus, in one or more embodiments, the polymeric amidoamine emulsifier may have a weight average molecular weight that is at least 1000 Da, or in more particular embodiments, ranging from 1000 Da to 10,000 Da.', 'Thus, it is envisioned, for example, that the polymeric emulsifiers of the present disclosure may be based on poly(ethyleneminine), poly(allyl amine), alpha-olefin maleic copolymers, poly(acrylic) acids, poly(methacrylic) acids, poly(maleic anhydride), or polyaminopolyamide.', 'That is, it is envisioned that the repeating units may be selected from allylamine, polyaminopolyamide, N-alkyl acrylamides, (meth)acrylic acid, alkyleneamine reacted with a dicarboxylic acid, alpha-olefin-alt-maleic anhydride, styrene maleic anhydride, alkylene oxide, and/or alkylene amine in one or more embodiments (and particularly when the number of repeating units is at least 5).', 'In other embodiments, the repeating units may be selected (particularly when the number of repeating units is at least 3) from allylamine, polyaminopolyamide, N-alkyl acrylamides, (meth)acrylic acid, alkyleneamine reacted with a dicarboxylic acid, alpha-olefin-alt-maleic anhydride, styrene maleic anhydride, and/or alkylene oxide.', 'In one or more embodiments, polymeric amidoamine emulsifiers may be the product of a polar reactant comprising nitrogen moieties.', 'In some instances, this polar reactant is in fact polymeric, while in other instances, the polar reactant is not polymeric but may be reacted with a polymeric component to form the polymeric emulsifier.', 'Another reactant used to form the polymeric amidoamine emulsifiers is a fatty component, often a fatty acid, that is used to provide the hydrophobic portion of the emulsifier.', 'Finally, while the nitrogen components provide some hydrophilicity to the resulting reaction product, embodiments may also include a polycarboxylic acid or anhydride as a reactant, providing greater hydrophilicity to the resulting component.', 'In one or more embodiments, polymeric amidoamine emulsifiers may be the product of an amine derivatized polymeric acid.', 'In one or more embodiments, polymeric amidoamine based emulsifiers may be derived from the reaction of a polycarboxylic acid and a polar reactant such as a poly(allylamine), poly(ethyleneimine), polyaminopolyamide, polyetheramine and polyacrylamide to form a covalent linkage such as an amide or imide.', 'In one or more embodiments, polar reactants in accordance with the present disclosure may include C1 to C10 alkyl amines, such as methyl amine, ethyl amine, and the like.', 'Alkyl amines may be substituted or non-substituted, branched or unbranched, ethoxylated or propoxylated, saturated and unsaturated.', 'Polymeric Amines\n \nPoly(ethyleneimine)', 'In one or more embodiments, polymeric amidoamine based emulsifiers may be derived from the reaction of a poly(ethyleneimine), a fatty acid, and a polycarboxylic acid/anhydride to form an emulsifier of the present disclosure.', 'Thus, in such embodiments, linear poly(ethyleneimines), in one or more embodiments, and branched poly(ethyleneimines), in one or more other embodiments, may serve as a polar reactant.', 'Other embodiments may include tailorable poly(ethyleneimine) dendrimers of selectable generation for the preparation of polymeric amidoamine emulsifiers.', 'In one or more embodiments, the hydrophilic poly(ethyleneimine) may have at least five or more repeating unitsor ten or more repeating units in more particular embodiments.', 'As mentioned, to form the polymeric emulsifier, the hydrophilic poly(ethyleneimine) backbone may be reacted with hydrophobic fatty acids, such as those described below, to form an amidoamine.', 'Further, polymeric amindoamines prepared from poly(ethyleneimine) reacted with fatty acids may be further reacted with a polycarboxylic acid or anhydride (of a carboxylic acid) capping agent, such as those described below, which is capable of reacting with one or more of the remaining hydrophilic groups of the poly(ethyleneimine) to further increase the hydrophilicity of the resulting compound.', 'In one or more embodiments, polar reactants may be comprised of a poly(ethyleneimine) base of the general formula (I) or (II) where in one embodiment the number of repeating units may range from n=at least 3, in another n=at least 5 and in another n=up to 200:', 'Thus, as shown from the above, some embodiments relate to a linear poly(ethyleneimine) base while others relate to branched poly(ethyleneimine) base reactants, each of which may be reacted with a fatty acid and then a polycarboxylic acid or anhydride.', 'In some embodiments, the weight average molecular weight of the poly(ethyleneimine) nitrogen containing polar reactant including those exemplified above as formulae (I) and (II) may range from 200 Da to 8,000 Da.', 'In some embodiments, the weight average molecular weight of the poly(ethyleneimine) nitrogen containing polar reactant including those exemplified above as formulae (I) and (II) may range from 700 Da to 3,000 kDa.\n \nPoly(allylamine)', 'In one or more embodiments, polymeric amidoamine based emulsifiers may be derived from the reaction of a poly(allylamine), a fatty acid, and a polycarboxylic acid/anhydride capping agent.', 'Thus, in such embodiments, polar reactants in accordance with the present disclosure may include a poly(allylamine).', 'In one or more embodiments, the hydrophilic poly(allylamine) backbone may include at least three, or at least five or, or at least ten or more repeating units.', 'In some embodiments, the hydrophilic poly(allylamine) backbone may be reacted with hydrophobic fatty acids as described below.', 'Polymeric amindoamines prepared from poly(allylamine) reacted with fatty acids may be further reacted with a polycarboxylic acid or anhydride (of a carboxylic acid) capping agent, capable of reacting with one or more of the remaining hydrophilic groups of the poly(allylamine) as further described below.', 'Thus, in one or more embodiments, polar reactants may be comprised of a poly(allylamine) base of the general formula (III):\n \n \n \n Where n may be at least 3, at least 5, or at least 10, in various embodiments.', 'In some embodiments, the weight average molecular weight of the poly(allylamine) nitrogen containing polar reactant may range from 17,000 Da to 60,000 Da.', 'In one or more embodiments, polar reactants may be prepared from allylamine oligomers having a number of constituent monomers in the range of 1 to 10 monomers.', 'Polyaminopolyamide\n \nIn one or more embodiments, polymeric amidoamine based emulsifiers may be derived from the reaction of a polyaminopolyamide, and a polycarboxylic acid/anhydride.', 'Thus, in one or more embodiments, polar reactants in accordance with the present disclosure may include polyaminopolyamides comprised of linear polyakylene amines (such as polyethylene amines) of tunable size and a di-functional acid such as adipic acid, sebaccic acid, dimer acid, or dicarboxylic fatty acids, that can be further reacted with fatty acid capping agent, as described below, to generate a polymeric amidoamine emulsifier with a tailorable HLB.', 'In one or more embodiments, the polyaminopolyamides may consist of at least three, or at least five, or at least ten or more repeating units, which may be defined as the total number of repeating units.', 'In one or more embodiments, the polyaminopolyamide may include two or three linear polyalkylene amines (i.e., having at least two primary amines separated by at least two carbon atoms) and at least one di-acid per two to three linear polyalkylene amines.', 'The reacted polyethyelene amine and di-acid may further repeat.', 'Thus, the total number of repeating units may reflect the sum of both levels of repeating unit.', 'Thus, for example, in one or more embodiments, the polyaminopolyamide base may be of the general formula (IV)\n \n \n \n where in one embodiment n is at least 1, 2, 3, 4, or 5, z is at least 1, 2, 3 or 5, and m is C2 to C18.', 'Further, in one or more embodiments, n+z is at least 3 or 5.', 'In some embodiments, the weight average molecular weight of the polyaminopolyamide base (prior to reaction with the fatty acid capping agent) may range from 200 Da to 8000 Da. \n \nEthoxylated/Propoxylated Amidoamine\n \nIn one or more embodiments, the polymeric amidoamine emulsifier may be comprised of a polyamine backbone and at least one ethylene oxide and/or propylene oxide copolymer.', 'The resulting primary amine terminated ethoxylated/propoxylated molecules may possess additional functionality and may contain amines that are highly reactive with the fatty acids and di-acid capping reagents discussed above.', 'Examples of such ethoxylated/propoxylated amidoamines are shown below:\n \n \n \n \nIn one or more embodiments the polymeric amidoamine emulsifier may be a polyetheramine that comprises ethoxylated/propoxylated monoamines, diamines and triamines.', 'Such polyetheramine backbones may have a molecular weight ranging from 300 to 8000 Da.', 'In one or more embodiments, the ethoxyled/propoxylated moieties of the amine branches can be controllably tuned to select specific emulsifier functionalities and features, including the resultant HLB value.', 'The incorporation of ethoxylation moieties may also aid in controlling the rheology of the fluid, particularly at lower temperatures where the ratio of ethoxylation to propoxylation may be tuned to achieve the desired HLB value.', 'Fatty Acid\n \nAs described above, various polar reactants may be reacted with a fatty acid to provide the hydrophobic portion of the emulsifiers of the present disclosure.', 'In one or more embodiments, the fatty acid may be any saturated or unsaturated (and optionally branched) fatty acid having a primary alkyl chain length with about 8 to about 32 carbon atoms therein.', 'However, if branched, it is envisioned that the total carbon number may be greater than 24, with the C8-C24 primary alkyl chain optionally having one or more C1 to C24 branches where in one or more embodiments the fatty acid may be at least a C8 and branched.', 'In one or more embodiments, the fatty acid may be saturated and branched, and in another it may be unsaturated and branched, and yet in another embodiment it may be linear and unsaturated.', 'Polycarboxylic Acid\n \nAs mentioned above and referenced in the above formulae, the polymeric emulsifier may also be formed with reaction with a hydrophilic capping agent.', 'Thus, the hydrophilic capping agent referenced above may include a polycarboxylic acid, anhydride (of a carboxylic acid such as acetic acid or a polycarboxylic acid, including one of those described below such as, but not limited to, maleic anhydride and succinic anhydride), urea, isocyanates (such as methylisocyanate), alpha-halo-carboxylic acid (such as chloroacetic acid, chloropropionic acid, etc), oxirane, cyclic diesters (such as lactide or glycolide), or cyclic sulfonate ester (such as propanesultone or other sultones).', 'Polycarboxylic acids may include, for example, lactic acid, glycolic acid and ether derivatives thereof, succinic acid, malonic acid, (ethylenedioxy) diacetic acid, maleic acid, oxalic acid, adipic acid, diglycolic acid, tartaric acid, tartronic acid, fumaric acid, citric acid, aconitic acid, citraconic acid, carboxymethyloxysuccinie acid, lactoxysuccinic acid, 2-oxy-1,1,3-propane tricarboxylic acid, oxydisuccinie acid, 1,1,2,2-ethane tetracarboxylic acid, 1,1,3,3-propane tetracarboxylic acid, 1,1,2,3-propane tetracarboxylic acid, cyclopentane-cis, cis, cis-tetracarboxylic acid, cyclopentadienide pentacarboxyiic acid, 2,3,4,5-tetrahydrofuran-cis, cis, cis-tetracarboxyiic acid, 2,5-tetrahydrofuran-cis-dicarboxylie acid, 1,2,3,4,5,6-hexane-hexaearhoxylic acid, mellitic acid, pyromellitic acid, phthahc acid, isophthaiic acid, and terphthalic acid.', 'Base Fluid\n \nWellbore fluids in accordance with the present disclosure may be prepared as an emulsion having a discontinuous aqueous phase within a continuous oleaginous phase.', 'Base fluids useful for preparing emulsions in accordance with the present disclosure may include at least one of fresh water, sea water, brine, mixtures of water and water-soluble organic compounds, and mixtures thereof.', 'In various embodiments, the aqueous fluid may be a brine, which may include seawater, aqueous solutions wherein the salt concentration is less than that of sea water, or aqueous solutions wherein the salt concentration is greater than that of sea water.', 'Salts that may be found in seawater include, but are not limited to, sodium, calcium, aluminum, magnesium, potassium, strontium, and lithium salts of chlorides, bromides, carbonates, iodides, chlorates, bromates, formates, nitrates, oxides, sulfates, silicates, phosphates and fluorides.', 'Salts that may be incorporated in a brine include any one or more of those present in natural seawater or any other organic or inorganic dissolved salts.', 'Suitable oleaginous or oil-based fluids that may be used to formulate emulsions may include a natural or synthetic oil and in some embodiments, in some embodiments the oleaginous fluid may be selected from the group including diesel oil; mineral oil; a synthetic oil, such as hydrogenated and unhydrogenated olefins including polyalpha olefins, linear and branch olefins and the like, polydiorganosiloxanes, siloxanes, or organosiloxanes, esters of fatty acids, specifically straight chain, branched and cyclical alkyl ethers of fatty acids, mixtures thereof and similar compounds known to one of skill in the art; and mixtures thereof.', 'In one or more embodiments, the oil:water ratio of an invert emulsion formulation may fall within the range of 30:70 to 95:5 in some embodiments, from 40:60 to 95:5 in some embodiments, from 50:50 to 70:30, or from 60:40 to 80:20 in yet other embodiments, where any lower limit can be used with any upper limit.', 'In one or more embodiments the emulsifier may be present at concentration in the wellbore fluid in the range of 1.5 ppb to 8 ppb.', 'Wellbore Fluid Additives', 'The wellbore fluids of the present disclosure may also contain wellbore fluid additives such as emulsifiers, wetting agents, organophilic clays, viscosifiers, bridging agents, fluid loss control agents, alkalinity control agents, and corrosion inhibitors, which may be added to the compositions disclosed herein so as to impart additional functional properties.', 'Wetting agents that may be suitable for use include, but are not limited to, crude tall oil, oxidized crude tall oil, surfactants, organic phosphate esters, ether carboxylic acids, fatty amines, amidoamines, modified imidazolines and amidoamines, fatty acid amidoamines (including dry fatty acid amidoamines) and salts thereof, ethoxylates, branched or linear primary alcohol ethoxylates, secondary alcohol ethoxylates, branched decyltridecyl alcohol ethoxylates, branched or linear alkylphenol ethoxylates, branched or linear alkyl amine ethoxylates, alkyl ether amine ethoxylates, linear alcohol alkoxylates, alkyl aromatic sulfates and sulfonates such as alkyl benzene sulfonates, calcium dodecylbenzenesulphonate, and the like, and combinations or derivatives of these.', 'Wetting agents may include, but are not limited to VERSAWET™ and VERSACOAT™, NOVAMUL™, FAZEMUL™, FAZEWET™, MEGAMUL™, SUREMUL™, ONEMUL™, ACTIMUL RD™, MUL-XT™ are non-limiting examples of commercially available wetting agents manufactured and distributed by M-I, L.L.C. that may be used in the fluids and methods of this disclosure.', 'To mitigate sag of the weighting agent within the oleaginous fluid, without creating a rheological profile that is problematic at colder temperatures when the viscosity of the fluid will naturally increase (particularly as the base fluid interacts with the weighting agent particles present in the fluid), the present inventors have determined that addition of particular wetting agents to the fluid may result in a weighted fluid that avoids sag without having excessive viscosity, particularly at colder temperatures.', 'In some embodiments, the wetting agents may be carboxylic acid-based wetting agents such as, for example, dicarboxylic fatty acids, dimer acids, or dimers of fatty acids.', 'Dicarboxylic fatty acids have the general formula HOOC—R—COOH, wherein R is an alkyl or alkenyl group containing from 10 to 50 carbon atoms, and in particular embodiments from 20 to 40 carbon atoms.', 'In other embodiments, wetting agents may be selected from the dimerization products of unsaturated dicarboxylic fatty acids, for example, such as products prepared by dimerization of unsaturated fatty acids containing from 8 to about 18 carbon atoms, including 9-dodecenoic, 9-tetradecenoic, 9-octadecenoic, octadecatetranoic acids, and the like.', 'Organophilic clays, normally amine treated clays, may be useful as viscosifiers in the fluid compositions disclosed herein.', 'Other viscosifiers and gellants, such as oil soluble polymers, polyamide resins, polycarboxylic acids and soaps may also be used.', 'Clays such as attapulgite, sepiolite, bentonite, and the like may also be used as viscosifiers.', 'The amount of viscosifier used in the compositions may vary depending on downhole conditions, as understood by those skilled in the art.', 'However, normally about 0.1% to 6% by weight range may be sufficient for most applications.', 'VG-69™, VG-SUPREME™, VG-HT™, and VG-PLUS™ are organoclay available from M-I, L.L.C. (Houston, TX), and VERSA-HRP™ is a polyamide resin material available from M-I L.L.C. (Houston, TX) that may be used in the fluids and methods of this disclosure.', 'Fluid loss control agents may act by coating the walls of the well.', 'Suitable fluid loss control agents may include, but are not limited to, modified lignites, asphaltic compounds, gilsonite, organophilic humates or tannins prepared by reacting humic acid or tannic acid with amides or polyalkylene polyamines, amine-treated tannins such as ONE-TROL-HT™, and latex polymers.', 'In embodiments, the fluid loss control agent may be selected from one or more of VERSATROL™, VERSALIG™, ECOTROL™ family of products, ONETROL-HT™, EMI 789, and NOVATECH™ F, which are all commercially available from MI SWACO (Houston, TX).', 'Weighting agents or density materials suitable for use in wellbore fluid formulations in accordance with the present disclosure include, but are not limited to, hematite, magnetite, iron oxides, illmenite, barite, siderite, celestite, dolomite, calcite, manganese oxides, halites and the like.', 'Weighting agents in accordance with the present disclosure may include commercially available additives such as M-I WATE™ available from M-I L.L.C. (Houston, TX).', 'In other embodiments, the weighting agent may be a micronized weighting agent, optionally coated with a dispersant.', 'In embodiments, the weighting agent may be coated, for example, with dispersants such as oleic acid and polybasic fatty acids, alkylbenzene sulphonic acids, alkane sulphonic acids, linear alpha-olefin sulphonic acids, phospholipids such as lecithin, including salts thereof and including mixtures thereof.', 'Synthetic polymers may also be used including polyacrylate esters such as polymers of stearyl methacrylate and/or butylacrylate.', 'In another embodiment, the corresponding acids methacrylic acid and/or acrylic acid may be used.', 'One skilled in the art would recognize that other acrylate or other unsaturated carboxylic acid monomers (or esters thereof) may be used to achieve substantially the same results as disclosed herein.', 'The quantity of the coated or uncoated weighting agent added, if any, may depend upon the desired density of the final composition.', 'Weighting agents may be added to result in a density of up to about 22 pounds per gallon (ppg).', 'In other embodiments, the weighting agent may be added to achieve a density of up to 22 ppg or up to 19.5 ppg.(Please Verify)', 'In one or more embodiments, upon introducing a wellbore fluid of the present disclosure into a borehole, a filtercake may be formed which provides an effective sealing layer on the walls of the borehole preventing undesired invasion of fluid into the formation through which the borehole is drilled.', 'Filter cakes formed by wellbore fluids of the present disclosure may effectively seal earthen formations, and may be stable at elevated temperatures.', 'Further, it is also envisioned that in addition to use in drilling a well, the present emulsifiers may be used in any fluid containing an invert emulsion, including when drilling the reservoir section, use in completion operations, etc.', 'Further, it is also envisioned that the wellbore fluids of the present disclosure may be injected into a work string, flow to bottom of the wellbore, and then out of the work string and into the annulus between the work string and the casing or wellbore.', 'This batch of treatment is typically referred to as a “pill.”', 'The pill may be pushed by injection of other wellbore fluids such as completion fluids behind the pill to a position within the wellbore which is immediately above a portion of the formation where fluid loss is suspected.', 'Injection of fluids into the wellbore is then stopped, and fluid loss will then move the pill toward the fluid loss location.', 'Positioning the pill in a manner such as this is often referred to as “spotting” the pill.', 'Injection of such pills is often through coiled tubing or by a process known as “bullheading.”', 'The method used in preparing wellbore fluids described herein is not critical.', 'Conventional methods can be used to prepare the wellbore fluids in a manner analogous to those normally used, to prepare conventional oil-based drilling fluids.', 'In one representative procedure, a desired quantity of oleaginous fluid such as a base oil and a suitable amount of carbon black materials are mixed together and the remaining components (if necessary) are added sequentially with continuous mixing.', 'An invert emulsion of the present disclosure is formed by vigorously agitating, mixing or shearing the oleaginous fluid and the non-oleaginous fluid.', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.']

['1.', 'A wellbore fluid, comprising:\nan oleaginous continuous phase;\na non-oleaginous discontinuous phase; and\na polymeric amidoamine emulsifier stabilizing the non-oleaginous discontinuous phase in the oleaginous continuous phase, wherein the polymeric amidoamine emulsifier has at least 5 repeating units; wherein the emulsifier is the product of a reaction between:\na polycarboxylic acid/anhydride,\na long chain fatty acid,\na polar reactant, wherein the polar reactant comprises an acyclic polymer having nitrogen moieties that is one or more selected from poly(ethyleneimine).', '2.', 'The wellbore fluid of claim 1, wherein the repeating units are selected from group consisting of allylamine, polyaminopolyamide, N-alkyl acrylamides, (meth)acrylic acid, alkyleneamine reacted with a dicarboxylic acid, alpha-olefin-alt-maleic anhydride, styrene maleic anhydride, alkylene oxide, and alkylene amine.', '3.', 'The wellbore fluid of claim 1, wherein the emulsion is stable up to 375° F.\n\n\n\n\n\n\n4.', 'The wellbore fluid of claim 1, wherein the emulsion has an oil:water ratio within the range of 40:60 to 95:5.\n\n\n\n\n\n\n5.', 'The wellbore fluid of claim 1, wherein the polar reactant is derivatized with a polycarboxylic acid/anhydride that is one or more selected from a group consisting of alpha-olefin maleic anhydride, poly(acrylic) acid, poly(methacrylic) acid and poly(maleic anhydride).', '6.', 'The wellbore fluid of claim 1, wherein the polar reactant is ethoxylated and/or propoxylated.', '7.', 'The wellbore fluid of claim 1, wherein the emulsifier is present at a concentration in the range of 1.5 ppb to 8 ppb.', '8.', 'The wellbore fluid of claim 1, wherein the weight average molecular weight of the polar reactant is in the range of 200 Da to 8000 Da.\n\n\n\n\n\n\n9.', 'The wellbore fluid of claim 1, wherein the polar reactants have the general formula (I-II)\nwhere n=at least 5 and at most 200, z=at least 1, m=C1 to C18.', '10.', 'The wellbore fluid of claim 1, wherein the oleaginous continuous phase comprises an oil-based fluid.', '11.', 'The wellbore fluid of claim 1, wherein the non-oleaginous discontinuous phase comprises an aqueous fluid.']

['No Captions Available']

US11921247

Full automation of high-resolution interval velocity estimation for check-shot and other vertical seismic profile-type datasets

Feb 2, 2021

Takashi Mizuno, Joel Herve Le Calvez

SCHLUMBERGER TECHNOLOGY CORPORATION

Zhang et al., “Seismic wave simulation by velocity-stress wave equations in two-phase anisotropic media”, Journal of Geophysics and Engineering 2014, vol. 11. (Year: 2014).; Salgado et al., “Interpretation of Large-Strain Seismic Cross-Hole Tests”, Journal of Geotechnical and Geoenvironmental Engineering ⋅ Apr. 1997 (Year: 1997).; International Search Report and Written Opinion of International Patent Application No. PCT/US2022/014684 dated May 4, 2022, 10 pages.; Correa, J., A. Egorov, K. Tertyshnikov, A. Bona, R. Pevzner, T. Dean, B. Freifeld, and S. Marshall, 2017, Analysis of signal to noise and directivity characteristics of DAS VSP at near and far offsets—A CO2CRC Otway Project data example: The Leading Edge, 36, 994a1-994a7.; Daley, T.M., D.E. Miller, K. Dodds, P. Cook., and B.M. Vreifeld, 2016, Field testing of modular borehole monitoring with simultaneous distributed acoustic sensing and geophone vertical seismic profiles at Citronelle, Alabama: Geophysical Prospecting, 64, 1318-1334.; Mizuno, T., S. Leaney, J. L. Calvez, F. Naseer, M. L. Khaitan, 2019. The significance of gauge length in particle velocity estimation from DAS data: VSP and microseismic cases: SEG Annual Meeting Expanded Abstracts, 4869-4873.

4809239; February 28, 1989; Esmersoy; 5012453; April 30, 1991; Katz; 8750074; June 10, 2014; Blias; 20160091621; March 31, 2016; Buland; 20170285195; October 5, 2017; Pei; 20180203144; July 19, 2018; Karrenbach

Foreign Citations not found.

['Embodiments presented provide for a fully automated method of high-resolution interval velocity estimation for vertical seismic profile-type data.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nNone.\n \nFIELD OF THE DISCLOSURE\n \nAspects of the disclosure relate to analysis of seismic data.', 'More specifically, aspects of the disclosure relate to automation methods for obtaining velocity estimations, without a need for time picking of analysis intervals.', 'BACKGROUND\n \nBorehole seismic projects attempt to estimate the P and S wave velocities along a wellbore trajectory by measuring speed of seismic wave recorded at the borehole.', 'As the type of boreholes and geometries can vary, there are many different types of overall configurations that may be present.', 'FIG.', '1\nA-\n1\nM\n present different types of applications where borehole seismic may be used.', 'In \nFIG.', '1\nA\n, for example, check-shot vertical seismic profile (VSP) and zero-offset VSP (\nFIG.', '1\nE\n), are the most fundamental configurations to be considered since they give P and S wave velocity along the borehole.', 'As illustrated in \nFIG.', '1\nA\n, a derrick \n101\n is positioned to prepare a wellbore \n100\n.', 'A seismic source \n102\n is configured to send a sonic pulse \n104\n into the geological stratum.', 'FIGS.', '1\nB-\n1\nM\n provide different types of embodiments that provide seismic pulses in different configurations.', 'As provided in \nFIG.', '1\nB\n, a multiple pattern from multiple sources is illustrated.', 'In \nFIG.', '1\nC\n, multiple seismic sources \n112\n are provided in the wellbore.', 'In \nFIG.', '1\nH\n, a wave form pattern \n110\n is created from different sources.', 'In different embodiments, an artificial seismic source is deployed close to the borehole wellhead, and the arrival of the direct P wave (and sometimes both P- and S-waves) is recorded using downhole sensors.', 'Variations of P and S wave velocity may be inferred in terms of propagation direction (anisotropy) by using several different configurations including offset VSP (\nFIG.', '1\nG\n), vertical incidence VSP, walkabove VSP (\nFIG.', '1\nD\n), walkaround VSP (\nFIG.', '1\nI\n), 3D VSP (\nFIG.', '1\nM\n).', 'Those surveys provide critical information for seismic imaging and reservoir characterization.', 'In addition to those FIGS.', 'described above, other geometries and variations are shown as examples of different configurations and methods used.', 'Traditionally, the borehole seismic industry has used three-component (\n3\nC) sensors.', 'Recently, fiber-based system such as heterodyne Distributed Acoustic Sensing (hDVS) systems or Distributed Acoustic Sensing (DAS) systems, have seen popularity increasing due to the low-cost of deployment and associated low acquisition time.', 'However, those systems are one-component (\n1\nC) acquisition systems.', 'Traditional approaches to data obtained from the different systems and geometries described above, rely on an analyst “time-picking” different sets of data obtained.', 'Such choices involve many factors and is a very laborious task.', 'This task slows down analysis and, consequently, activities at the jobsite.', 'There is a need to provide a method that does not involve tedious analysis, such as picking of time intervals, that is currently performed in conventional analysis.', 'There is a further need to provide a method that does not have the drawbacks discussed above, namely exhaustive use of operator and analyst time.', 'There is a still further need to reduce economic costs associated with field and analyst time related to time picking intervals.', 'SUMMARY\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized below, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted that the drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments without specific recitation.', 'Accordingly, the following summary provides just a few aspects of the description and should not be used to limit the described embodiments to a single concept.', 'In one example embodiment, a method is disclosed.', 'The method may comprise testing and obtaining particle velocity data from at least one geological stratum in a field location.', 'The method may further comprise obtaining strain data from the at least one geological stratum in the field location.', 'The method may further comprise performing a peak-to-peak amplitude analysis for the particle velocity data for a target phase.', 'The method may further comprise performing a peak-to-peak amplitude analysis for the strain data for the target phase.', 'The method may further comprise estimating a velocity of waves in the at least one geological stratum based upon the peak-to-peak amplitude analysis for the particle velocity data for the target phase and the peak-to-peak amplitude analysis for the strain data for the target phase.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are therefore not be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.\n \nFIG.', '1\nA\n is a side profile of a check shot vertical seismic profile being performed at a wellbore site.\n \nFIG.', '1\nB\n is a side profile of a walkaway vertical seismic profile being performed at a wellbore site.\n \nFIG.', '1\nC\n is a side profile of a monoseismic test being performed at a wellbore site.\n \nFIG.', '1\nD\n is a side profile of a walkabove vertical seismic profile test being performed at a wellbore site.\n \nFIG.', '1\nE\n is a side profile of a zero-offset vertical seismic profile being performed at a wellbore site.\n \nFIG.', '1\nF\n is a side profile of a single well seismic profile being performed at a wellbore site.\n \nFIG.', '1\nG\n is a side profile of an offset vertical seismic profile being performed at a wellbore site.\n \nFIG.', '1\nH\n is a side profile of a vertical seismic profile versus offset test being performed at a wellbore site.\n \nFIG.', '1\nI\n is a side profile of a walkaround vertical seismic profile being performed at a wellbore site.\n \nFIG.', '1\nJ\n is a side profile of a seismic while drilling test being performed at a wellbore site.\n \nFIG.', '1\nK\n is a side profile of a cross-well seismic test being performed at a wellbore site.\n \nFIG.', '1\nL\n is a side profile of a salt proximity test being performed at a wellbore site.\n \nFIG.', '1\nM\n is a side profile of a three dimensional vertical seismic profile test being performed at a wellbore site.\n \nFIG.', '2\n is a method for performing full automation of high-resolution interval velocity estimation for check-shot and other vertical seismic profile-type datasets.\n \nFIG.', '3\nA\n is an example embodiment of a check-shot vertical seismic profile data for strain.\n \nFIG.', '3\nB\n is an example embodiment of a check-shot vertical seismic profile data for particle velocity.\n \nFIG.', '4\n is a graph showing comparisons of conventional time picking velocity and fully automated velocity calculations described in \nFIG.', '2\n.', 'FIG.', '5\n is a computer apparatus used in performing methods and controlling apparatus for the operations of \nFIG.', '1\n.', 'FIG.', '6\n is a side elevational view of a wireline operation being performed in which seismic analysis may be conducted.', 'To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures (“FIGS”).', 'It is contemplated that elements disclosed in one embodiment may be beneficially utilized on other embodiments without specific recitation.', 'DETAILED DESCRIPTION', 'In the following, reference is made to embodiments of the disclosure.', 'It should be understood, however, that the disclosure is not limited to specific described embodiments.', 'Instead, any combination of the following features and elements, whether related to different embodiments or not, is contemplated to implement and practice the disclosure.', 'Furthermore, although embodiments of the disclosure may achieve advantages over other possible solutions and/or over the prior art, whether or not a particular advantage is achieved by a given embodiment is not limiting of the disclosure.', 'Thus, the following aspects, features, embodiments and advantages are merely illustrative and are not considered elements or limitations of the claims except where explicitly recited in a claim.', 'Likewise, reference to “the disclosure” shall not be construed as a generalization of inventive subject matter disclosed herein and should not be considered to be an element or limitation of the claims except where explicitly recited in a claim.', 'Although the terms first, second, third, etc., may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms.', 'These terms may be only used to distinguish one element, component, region, layer or section from another region, layer or section.', 'Terms such as “first”, “second” and other numerical terms, when used herein, do not imply a sequence or order unless clearly indicated by the context.', 'Thus, a first element, component, region, layer or section discussed herein could be termed a second element, component, region, layer or section without departing from the teachings of the example embodiments.', 'When an element or layer is referred to as being “on,” “engaged to,” “connected to,” or “coupled to” another element or layer, it may be directly on, engaged, connected, coupled to the other element or layer, or interleaving elements or layers may be present.', 'In contrast, when an element is referred to as being “directly on,” “directly engaged to,” “directly connected to,” or “directly coupled to” another element or layer, there may be no interleaving elements or layers present.', 'Other words used to describe the relationship between elements should be interpreted in a like fashion.', 'As used herein, the term “and/or” includes any and all combinations of one or more of the associated listed terms.', 'Some embodiments will now be described with reference to the figures.', 'Like elements in the various figures will be referenced with like numbers for consistency.', 'In the following description, numerous details are set forth to provide an understanding of various embodiments and/or features.', 'It will be understood, however, by those skilled in the art, that some embodiments may be practiced without many of these details, and that numerous variations or modifications from the described embodiments are possible.', 'As used herein, the terms “above” and “below”, “up” and “down”, “upper” and “lower”, “upwardly” and “downwardly”, and other like terms indicating relative positions above or below a given point are used in this description to more clearly describe certain embodiments.', 'Aspects of the disclosure also provide methods that may be performed to achieve a stated goal, including controlling components described in the specification.', 'In some embodiments, the methods described may be performed by circuits and/or computers that are configured to perform such tasks.', 'Referring to \nFIG.', '6\n, wireline operations are performed after the creation of a wellbore.', 'In embodiments, seismic analysis can be performed at the surface, within the wellbore, or both.', 'In one example embodiment, wireline operations are conducted to obtain data related to the method described in relation to \nFIG.', '2\n.', 'To this end, a general description of wireline operations will be described to acquaint the reader with the apparatus and methods used.', 'Wireline operations may be accomplished to obtain subsurface petrophysical and geophysical data related to the geological stratum \n604\n encountered by the wellbore.', 'In these operations, a wireline truck \n650\n is provided.', 'The wireline truck \n650\n is provided with a spool \n652\n that houses a cable \n654\n.', 'The cable \n654\n may be a single strand or multiple strand cable unit.', 'The cable \n654\n is configured to allow sensors and equipment to be lowered into the wellbore such that the sensors and equipment may conduct required surveys.', 'The lowering action may be accomplished by a motor \n656\n that is connected to the spool \n652\n.', 'Within the wireline truck \n650\n, an operator may activate and deactivate the motor \n656\n and control associated gearing to allow the spool \n652\n to unwind the cable \n654\n at a desired rate.', 'Sensors \n658\n may be provided to ascertain the amount of cable \n654\n that has been unspooled to allow the operator to identify the location of equipment suspended by the cable \n654\n.', 'Equipment supported by the cable can be a single instrument package or multiple instrument packages.', 'In the case of multiple instrument packages, such instrument packages may be modular such that different types of packages may be added together according to the needs of the operator.', 'Different types of packages may include, but not be limited to: \n \n \n \nPacker systems\n \nPressure meter testing systems\n \nNuclear measurement systems\n \nOptical spectrometry systems\n \nPressure monitoring systems\n \nResistivity calculation systems\n \nSonic and ultrasonic tool systems\n \nBorehole seismic tool systems\n \nNuclear magnetic resonance tool systems\n \nPressure control systems\n \nTractor and motion enhancement systems\n \nPower Generation systems\n \nTelemetry and Data recordation systems\n \nComputing systems\n \n \n \n \n \nGenerally, the different modular systems described above may be added together, as needed, to form a logging tool \n660\n that may be called or known as a sonde.', 'The logging tool \n660\n is lowered into the wellbore to a desired point in the geological stratum \n604\n and the appropriate system is actuated.', 'The wireline operator may take sensor readings at one point or may take multiple readings while changing the elevation of the logging tool \n660\n.', 'The resulting string of measurements may be called a “log”.', 'Wireline operations may also be used in remediation of a wellbore in order to increase production of hydrocarbons.', 'Such operations, known as remediation or “workovers” may include augmenting existing wellbore parameters.', 'The purpose of aspects disclosed here provide a method to process downhole sensor data in order to automatically retrieve high-resolution and high-definition interval velocity information without having to rely on tedious (and sometimes inaccurate, often manual) time-picking.', 'As an example, data may be covered during a field survey and then processed, allowing continuation of field activities.', 'Such capabilities are not currently possible with conventional technologies.', 'Different types of field analysis techniques are present.', 'FIG.', '1\n discloses several types of techniques, including (a) check shot Vertical Seismic Profile (VSP), (b) walkaway VSP, (c) microseismic (d) walkabove VSP, (e) zero-offset VSP, (f) single well seismic, (g) offset VSP, (h) VSP Amplitude', 'Versus Offset (AVO), (i) walkaround VSP, (j) SWD (seismic while drilling), (k) cross well seismic, (l) salt proximity, (m) 3D VSP.', 'Considering the check-shot VSP and ZVSP, velocity (c) along the borehole can be estimated from arrival time picks for direct P or S arrivals using the following equation:\n \n \n \n \n \n \n \n \n \nc\n \n\u2061\n \n(\n \nz\n \n)\n \n \n=\n \n \n \n \nT\n \n\u2061\n \n(\n \n \nz\n \n+\n \n \nΔ\n \n/\n \n2\n \n \n \n)\n \n \n-\n \n \nT\n \n\u2061\n \n(\n \n \nz\n \n-\n \n \nΔ\n \n/\n \n2\n \n \n \n)\n \n \n \nΔ\n \n \n \n \n \n \nEQUATION\n \n\u2062\n \n \n \n1\n \n \n \n \n \n \n \n where z is depth, Δ/2 is the distance from depth z, where arrival time of P or S wave (T) is measured.', 'Equation 1 indicates that to accurately determine the interval velocity c, accurate time picks are needed for P- (or S-) wave arrivals.', 'Furthermore, measured at two neighboring points close to the depth z, spatial resolution depends on the distance delta.', 'This requirement is consistent for all types of VSP survey configurations.', 'In embodiments, aspects of the method described are used to produce a high-resolution velocity profile.', 'In this method, a relation between the amplitude of strain and particle velocity to estimate c(z) (a high-resolution velocity profile) at a specific depth (z).', 'The method does not rely on any time-picking, tedious, relatively precise, manual, high-precision time-picking.', 'The method also does not rely on traditional error-prone automated arrival detection algorithms.', 'The theory behind the method described is starting to emerge in the field of exploration strain seismology, which has been evolving in relation to the interpretation of seismic datasets acquired using optical fiber cables (hDVS in SLB).', 'FIG.', '2\n shows the computation method \n200\n in one embodiment of the disclosure.', 'At \n202\n, the method entails obtaining particle velocity data from a geological borehole seismic survey.', 'At \n204\n, the method also entails obtaining strain data related to the geological borehole seismic survey.', 'In one embodiment, the strain data may be related to optical fiber data.', 'In another example embodiment, the strain data may be related to simulation data.', 'The method progresses at \n206\n for computing a peak-to-peak amplitude for a target phase.', 'The method step at \n206\n follows the step at \n202\n.', 'At \n208\n, the method provides for computing a peak-to-peak amplitude for a target phase using the strain data at \n204\n.', 'In aspects of the disclosure, particle velocity and strain check-shot VSP data is obtained from field seismic activities at \n202\n and \n204\n.', 'For steps \n202\n and \n204\n, sampling should occur at the same depth because the method requires seismic waveform amplitude for each depth.', 'The following data types may be used: \n \n \n \nFiber optic data (hDVS or DAS in the industry in general)\n \nSimulated DAS data from geophone.', 'As a source of geophone data, at \n202\n, the following data types may be used: \n \n \n \nGeophone recordings\n \nInverted particle velocity using the StrainToVelocity (STV)-Multi method.', 'The next step entails computing peak-to-peak amplitude for direct P arrivals (and S-wave arrivals if available).', 'At \n206\n, \n208\n the time window does not need to be defined for the peak-to-peak amplitude reading since the P-wave is usually the biggest amplitude arrival in the record.', 'In case of noisy data, the time window may be defined, the algorithm uses a priori knowledge of P-wave arrivals from various databases.', 'At \n210\n, the phase velocity at depth z may be estimated as \n \nc\n(\nz\n)=\nV\n_\np\n2\np\n(\nz\n)/\nD\n_\np\n2\np\n(\nz\n)\u2003\u2003EQUATION 1A \n \nConsidering the 1D wave propagation problem, which is applicable for check-shot VSP and ZVSP, the following relation is established for infinitesimal strain and particle velocity.', 'ε\n \n\u2061\n \n(\n \n \nz\n \n,\n \nt\n \n \n)\n \n \n=\n \n \n \n1\n \nc\n \n \n\u2062\n \n \nv\n \n\u2061\n \n(\n \n \nz\n \n,\n \nt\n \n \n)\n \n \n \n \n \n \n \nEQUATION\n \n\u2062\n \n \n \n2\n \n \n \n \n \n \n \n where epsilon is the infinitesimal strain and v is the particle velocity recording at the sensor depth (z).', 'In the case of optical fiber and simulated DAS recordings, equation (1) may not be adequate since strain is finite rather than infinitesimal strain.', 'In those cases, \n \n \n \n \n \n \n \n \n \nd\n \n\u2061\n \n(\n \n \nz\n \n,\n \nt\n \n \n)\n \n \n=\n \n \n \n \n \n-\n \n2\n \n \n\u2062\n \ni\n \n \n \nG\n \n\u2062\n \nL\n \n \n \n\u2062\n \n \n(\n \n \nsin\n \n\u2062\n \n \nk\n \n\u2061\n \n(\n \n \nGL\n \n2\n \n \n)\n \n \n \n)\n \n \n\u2062\n \nc\n \n\u2062\n \n \n \nv\n \n\u2061\n \n(\n \n \nz\n \n,\n \nt\n \n \n)\n \n \n.', 'EQUATION\n \n\u2062\n \n \n \n3\n \n \n \n \n \n \n \n \nThe above equation has been employed for the conversion of infinite/finite strain data (epsilon, d) to particle velocity (v).', 'However, it is not used to estimate phase velocity (c) using infinite/finite strain (epsilon, d) and particle velocity (v) previously.', 'For instance, if infinitesimal strain and particle velocity data is available, using equation (2), the phase velocity (c) is estimated as follows:\n \n \n \n \n \n \n \n \n \n \nc\n \n\u2061\n \n(\n \nz\n \n)\n \n \n=\n \n \n \nv\n \n\u2061\n \n(\n \n \nz\n \n,\n \nt\n \n \n)\n \n \n \nε\n \n\u2061\n \n(\n \n \nz\n \n,\n \nt\n \n \n)\n \n \n \n \n.', 'EQUATION\n \n\u2062\n \n \n \n4\n \n \n \n \n \n \n \n \nEquation 4 indicates that the phase velocity at depth z can be estimated by the division of amplitude of two seismic traces, and it is constant for t. The application of this equation is quite challenging since amplitude contains noise.', 'To account for potential noise, amplitude information in the seismic data is used, such as peak-to-peak amplitude.', 'To estimate the velocity, equation 5 uses the peak-to-peak amplitude within a certain time window that contains the direct P wave (and S-wave arrivals if available).', 'c\n \n\u2061\n \n(\n \nz\n \n)\n \n \n∼\n \n \n \n \nv\n \n \nP\n \n\u2062\n \n2\n \n\u2062\n \nP\n \n \n \n(\n \nz\n \n)\n \n \n \n \nε\n \n \nP\n \n\u2062\n \n2\n \n\u2062\n \nP\n \n \n \n(\n \nz\n \n)', 'EQUATION\n \n\u2062\n \n \n \n5\n \n \n \n \n \n \n \n \nFIGS.', '3\nA and \n3\nB\n show the synthetic waveform in the velocity domain as well as the strain domain.', 'In one embodiment, it is assumed that the P wave arrives within a time window between 250 msec-1000 msec from the shot time.', 'FIG.', '4\n shows the phase velocity \n402\n estimated by the method described in relation to \nFIG.', '2\n.', 'The one from the traditional method using precise (theoretical) time pick is provided by the result listed at \n400\n.', 'The new method provides a comparable result to the traditional method without using time pick.', 'In such embodiments, referring to \nFIG.', '5\n, a computing apparatus used in the control of equipment to perform analysis steps described in \nFIG.', '2\n.', 'In \nFIG.', '5\n, a processor \n500\n is provided to perform computational analysis for instructions provided.', 'The instruction provided, code, may be written to achieve the desired goal and the processor \n500\n may access the instructions.', 'In other embodiments, the instructions may be provided directly to the processor \n500\n.', 'In other embodiments, other components may be substituted for generalized processors.', 'These specifically designed components, known as application specific integrated circuits (“ASICs”) are specially designed to perform the desired task.', 'As such, the ASICs generally have a smaller footprint than generalized computer processors.', 'The ASICs, when used in embodiments of the disclosure, may use field programmable gate array technology, that allows a user to make variations in computing, as necessary.', 'Thus, the methods described herein are not specifically held to a precise embodiment, rather alterations of the programming may be achieved through these configurations.', 'In embodiments, when equipped with a processor \n500\n, the processor \n500\n may have arithmetic logic unit (“ALU”) \n502\n, a floating point unit (“FPU”) \n504\n, registers \n506\n and a single or multiple layer cache \n508\n.', 'The arithmetic logic unit \n502\n may perform arithmetic functions as well as logic functions.', 'The floating point unit \n504\n may be math coprocessor or numeric coprocessor to manipulate numbers more efficiently and quickly than other types of circuits.', 'The registers \n506\n are configured to store data that will be used by the processor \n500\n during calculations and supply operands to the arithmetic unit \n502\n and store the result of operations.', 'The single or multiple layer caches \n508\n are provided as a storehouse for data to help in calculation speed by preventing the processor \n500\n from continually accessing random access memory (“RAM”) \n514\n.', 'Aspects of the disclosure provide for the use of a single processor \n500\n.', 'Other embodiments of the disclosure allow the use of more than a single processor.', 'Such configurations may be called a multi-core processor where different functions are conducted by different processors to aid in calculation speed.', 'In embodiments, when different processors are used, calculations may be performed simultaneously by different processors, a process known as parallel processing.', 'The processor \n500\n may be located on a motherboard \n510\n.', 'The motherboard \n510\n is a printed circuit board that incorporates the processor \n500\n as well as other components helpful in processing, such as memory modules (“DIMMS”) \n512\n, random access memory \n514\n, read only memory \n515\n, non-volatile memory chips \n516\n, a clock generator \n518\n that keeps components in synchronization, as well as connectors for connecting other components to the motherboard \n510\n.', 'The motherboard \n510\n may have different sizes according to the needs of the computer architect.', 'To this end, the different sizes, known as form factors, may vary from sizes from a cellular telephone size to a desktop personal computer size.', 'The motherboard \n510\n may also provide other services to aid in functioning of the processor \n500\n, such as cooling capacity.', 'Cooling capacity may include a thermometer \n520\n and a temperature controlled fan \n522\n that conveys cooling air over the motherboard \n510\n to reduce temperature.', 'Data stored for execution by the processor \n500\n may be stored in several locations, including the random access memory \n514\n, read only memory \n515\n, flash memory \n524\n, computer hard disk drives \n526\n, compact disks \n528\n, floppy disks \n530\n and solid state drives \n532\n.', 'For booting purposes, data may be stored in an integrated chip called an EEPROM, that is accessed during start-up of the processor \n500\n.', 'The data, known as a Basic Input/Output System (“BIOS”), contains, in some example embodiments, an operating system that controls both internal and peripheral components.', 'Different components may be added to the motherboard or may be connected to the motherboard to enhance processing.', 'Examples of such connections of peripheral components may be video input/output sockets, storage configurations (such as hard disks, solid state disks, or access to cloud-based storage), printer communication ports, enhanced video processors, additional random access memory and network cards.', 'The processor and motherboard may be provided in a discrete form factor, such as personal computer, cellular telephone, tablet, personal digital assistant or other component.', 'The processor and motherboard may be connected to other such similar computing arrangement in networked form.', 'Data may be exchanged between different sections of the network to enhance desired outputs.', 'The network may be a public computing network or may be a secured network where only authorized users or devices may be allowed access.', 'As will be understood, method steps for completion may be stored in the random access memory, read only memory, flash memory, computer hard disk drives, compact disks, floppy disks and solid state drives.', 'Different input/output devices may be used in conjunction with the motherboard and processor.', 'Input of data may be through a keyboard, voice, Universal Serial Bus (“USB”) device, mouse, pen, stylus, Firewire, video camera, light pen, joystick, trackball, scanner, bar code reader and touch screen.', 'Output devices may include monitors, printers, headphones, plotters, televisions, speakers and projectors.', 'In the following description, description is provided related to measurements obtained during wireline operations generally performed, as described above.', 'As will be understood, various changes and alterations may be accomplished during the attainment of the desired measurements and, as such, methods described should not be considered limiting.', 'In one example embodiment, a method is disclosed.', 'The method may comprise testing and obtaining particle velocity data from at least one geological stratum in a field location.', 'The method may further comprise obtaining strain data from the at least one geological stratum in the field location.', 'The method may further comprise performing a peak-to-peak amplitude analysis for the particle velocity data for a target phase.', 'The method may further comprise performing a peak-to-peak amplitude analysis for the strain data for the target phase.', 'The method may further comprise estimating a velocity of waves in the at least one geological stratum based upon the peak-to-peak amplitude analysis for the particle velocity data for the target phase and the peak-to-peak amplitude analysis for the strain data for the target phase.', 'In another example embodiment, the method may be performed wherein the testing and obtaining strain data is obtained from a geophone.', 'In another example embodiment, the method may be performed wherein the strain data is from optical fiber data.', 'In another example embodiment, the method may be performed wherein the particle velocity data is obtained from a geophone.', 'In another example embodiment, the method may further comprise outputting the velocity in a form of a log.', 'In another example embodiment, the method may be performed wherein the log is displayed as a chart.', 'In another example embodiment, the method may be performed wherein the testing and obtaining the particle velocity data from the at least one geological stratum in the field location and the obtaining the strain data from the at least one geological stratum in the field location is at one location.', 'In another example embodiment, the method may be performed wherein the one location has a specified depth.', 'In another example embodiment, the method may be performed wherein the strain data is simulated data.', 'In another example embodiment, the method may be performed wherein the strain data is obtained through field testing.', 'In another example embodiment, the method may be performed wherein the velocity data is Inverted particle velocity.', 'In another example embodiment, the method may be performed wherein the inverted particle velocity is obtained using the Strain-To-Velocity multi-method.', 'In another example embodiment, the method may be performed wherein the velocity of waves is estimated by a division of amplitude of two seismic traces.', 'In another example embodiment, the method may be performed wherein the velocity of waves is estimated by an equation of c(z)=V_p2p(z)/D_p2p(z).', 'In another example embodiment, the method may be performed wherein the particle velocity data is obtained from a checkshot vertical profile data set.', 'In another example embodiment, the method may be performed wherein the particle velocity data is obtained from a walkaway vertical seismic profile.', 'In another example embodiment, the method may be performed wherein the particle velocity data is obtained from a microseismic survey.', 'In another example embodiment, the method may be performed wherein the particle velocity data is obtained from a walkabove vertical seismic profile.', 'In another example embodiment, the method may be performed wherein the particle velocity data is obtained from a zero-offset vertical seismic profile.', 'In another example embodiment, the method may be performed wherein the particle data is obtained from a cross-well survey.', 'The foregoing description of the embodiments has been provided for purposes of illustration and description.', 'It is not intended to be exhaustive or to limit the disclosure.', 'Individual elements or features of a particular embodiment are generally not limited to that particular embodiment, but, where applicable, are interchangeable and can be used in a selected embodiment, even if not specifically shown or described.', 'The same may be varied in many ways.', 'Such variations are not to be regarded as a departure from the disclosure, and all such modifications are intended to be included within the scope of the disclosure.', 'While embodiments have been described herein, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments are envisioned that do not depart from the inventive scope.', 'Accordingly, the scope of the present claims or any subsequent claims shall not be unduly limited by the description of the embodiments described herein.']

['1.', 'A method, comprising:\nlowering one or more sensors into a wellbore;\nperforming a seismic test using one or more seismic sources;\nobtaining particle velocity data from the seismic test from at least one geological stratum in a field location using the one or more sensors;\nobtaining strain data from the seismic test from the at least one geological stratum in the field location using the one or more sensors;\nperforming a first peak-to-peak amplitude analysis for the particle velocity data at the at least one geological stratum for at least one of a direct P wave, a reflected P wave, a direct S wave, or a reflected S wave;\nperforming a second peak-to-peak amplitude analysis for the strain data at the at least one geological stratum for the at least one of the direct P wave, the reflected P wave, the direct S wave, or the reflected S wave; and\nestimating a velocity of waves in the at least one geological stratum based upon the first peak-to-peak amplitude analysis for the particle velocity data and the second peak-to-peak amplitude analysis for the strain data.', '2.', 'The method according to claim 1, wherein each of the one or more sensors used to obtain the strain data is a geophone.', '3.', 'The method according to claim 1, wherein each of the one or more sensors used to obtain strain data is an optical fiber cable.', '4.', 'The method according to claim 1, wherein each of the one or more sensors used to obtain the particle velocity data is a geophone.', '5.', 'The method according to claim 1, further comprising:\noutputting the velocity in a form of a log.', '6.', 'The method according to claim 5, wherein the log is displayed as a chart.', '7.', 'The method according to claim 1, wherein the obtaining the particle velocity data from the seismic test from the at least one geological stratum in the field location and the obtaining the strain data from the seismic test from the at least one geological stratum in the field location is at one location.', '8.', 'The method according to claim 7, wherein the one location has a specified depth.', '9.', 'The method according to claim 1, wherein the strain data is simulated data.', '10.', 'The method according to claim 1, wherein the strain data is obtained through field testing.', '11.', 'The method according to claim 1, wherein the velocity data is inverted particle velocity.', '12.', 'The method according to claim 11, wherein the inverted particle velocity is obtained using the Strain-To-Velocity multi-method.', '13.', 'The method according to claim 1, wherein the velocity of waves is estimated by a ratio of the first peak-to-peak amplitude analysis for the particle velocity data at the at least one geological stratum to the second peak-to-peak amplitude analysis for the particle velocity data at the at least one geological stratum.', '14.', 'The method according to claim 1, wherein the particle velocity data is obtained from a checkshot vertical profile.', '15.', 'The method according to claim 1, wherein the particle velocity data is obtained from a walkaway vertical seismic profile.', '16.', 'The method according to claim 1, wherein the particle velocity data is obtained from a microseismic survey.', '17.', 'The method according to claim 1, wherein the particle velocity data is obtained from a walkabove vertical seismic profile.', '18.', 'The method according to claim 1, wherein the particle velocity data is obtained from a zero-offset vertical seismic profile.', '19.', 'The method according to claim 1, wherein the particle data is obtained from a cross-well survey.', '20.', 'The method according to claim 1, wherein the particle velocity data is obtained from a walkaround vertical seismic profile.']

['FIG.', '1A is a side profile of a check shot vertical seismic profile being performed at a wellbore site.;', 'FIG.', '1B is a side profile of a walkaway vertical seismic profile being performed at a wellbore site.; FIG.', '1C is a side profile of a monoseismic test being performed at a wellbore site.;', 'FIG.', '1D is a side profile of a walkabove vertical seismic profile test being performed at a wellbore site.; FIG.', '1E is a side profile of a zero-offset vertical seismic profile being performed at a wellbore site.;', 'FIG.', '1F is a side profile of a single well seismic profile being performed at a wellbore site.; FIG.', '1G is a side profile of an offset vertical seismic profile being performed at a wellbore site.;', 'FIG.', '1H is a side profile of a vertical seismic profile versus offset test being performed at a wellbore site.;', 'FIG.', '1I is a side profile of a walkaround vertical seismic profile being performed at a wellbore site.;', 'FIG.', '1J is a side profile of a seismic while drilling test being performed at a wellbore site.; FIG.', '1K is a side profile of a cross-well seismic test being performed at a wellbore site.;', 'FIG.', '1L is a side profile of a salt proximity test being performed at a wellbore site.; FIG.', '1M is a side profile of a three dimensional vertical seismic profile test being performed at a wellbore site.;', 'FIG. 2 is a method for performing full automation of high-resolution interval velocity estimation for check-shot and other vertical seismic profile-type datasets.; FIG.', '3A is an example embodiment of a check-shot vertical seismic profile data for strain.', '; FIG.', '3B is an example embodiment of a check-shot vertical seismic profile data for particle velocity.', '; FIG.', '4 is a graph showing comparisons of conventional time picking velocity and fully automated velocity calculations described in FIG.', '2.; FIG.', '5 is a computer apparatus used in performing methods and controlling apparatus for the operations of FIG.', '1.; FIG. 6 is a side elevational view of a wireline operation being performed in which seismic analysis may be conducted.; FIG.', '2 shows the computation method 200 in one embodiment of the disclosure.', 'At 202, the method entails obtaining particle velocity data from a geological borehole seismic survey.', 'At 204, the method also entails obtaining strain data related to the geological borehole seismic survey.', 'In one embodiment, the strain data may be related to optical fiber data.', 'In another example embodiment, the strain data may be related to simulation data.', 'The method progresses at 206 for computing a peak-to-peak amplitude for a target phase.', 'The method step at 206 follows the step at 202.', 'At 208, the method provides for computing a peak-to-peak amplitude for a target phase using the strain data at 204.; FIGS.', '3A and 3B show the synthetic waveform in the velocity domain as well as the strain domain.', 'In one embodiment, it is assumed that the P wave arrives within a time window between 250 msec-1000 msec from the shot time.', '; FIG.', '4 shows the phase velocity 402 estimated by the method described in relation to FIG.', '2.', 'The one from the traditional method using precise (theoretical) time pick is provided by the result listed at 400.', 'The new method provides a comparable result to the traditional method without using time pick.']

US11940588

Clay detection and quantification using downhole low frequency electromagnetic measurements

Jan 31, 2022

Shouxiang Ma, Ping Zhang, Wael Abdallah, Chengbing Liu

No Companies Listed

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2018067757; April 2018; WO

['Methods and systems are provided for clay detection, clay typing, and clay volume quantification using downhole electromagnetic measurements conducted by a downhole logging tool on a formation at a low frequency less than 5000 Hz.', 'The downhole electromagnetic measurements are used to determine permittivity data that characterizes permittivity of the formation at the low frequency less than 5000 Hz.', 'The downhole low frequency electromagnetic measurements are nondestructive, and the results indicate it is with high sensitivity to the existence of clays.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application is a Continuation of U.S. Non-Provisional application Ser.', 'No. 16/663,636, filed on Oct. 25, 2019 which is hereby incorporated by reference in its entirety for all purposes.', 'FIELD\n \nThe present disclosure relates to methods and systems that can detect clay in a rock sample and that can also determine data characterizing clay type and volume fraction of clay in the rock sample.', 'BACKGROUND\n \nGeological knowledge of formation rock is important for resources exploration, field development and production planning.', 'To assess reservoir quality and the amount of hydrocarbons in-place, characterization of the mineralogy of the formation rock is needed in order to accurately calculate reservoir porosity and hydrocarbon saturation from logs.', 'This is particularly true in the event that clay is present in the formation rock.', 'Each hydrocarbon reservoir can contain different types of clays and different amounts of such clay types.', 'Each clay type has its own different characteristics, which can be translated to what is called cation exchange capacity (CEC) in common petrophysical applications.', 'Clays are hydrous aluminum silicate minerals that are platy in structure and can form by the alteration of silicate minerals like feldspar and amphibole.', 'Clays are commonly grouped into a number of clay types, including but not limited smectite, kaolinite, chlorite, illite.', 'Some clays have a tendency to swell when exposed to water, creating a potential drilling hazard when clay-bearing rock formations are exposed to water-base fluids during drilling, possibly reducing the permeability of a good reservoir rock.', 'Some clays are used in drilling fluids to form an impermeable mudcake to isolate a formation from the invasion of drilling fluid.', 'The structural differences amongst the clay types (smectite, kaolinite, chlorite, illite) can determine the surface area exposed to reservoir fluids or stimulating fluids.', 'Clays can be found in pore spaces, as part of the matrix or as grain-cementing material.', 'Authigenic clays, which grow in the pores from minerals in the connate water, can be pore-filling or pore-lining.', 'These clays have considerable surface area exposed in the pore and can be reactive, while detrital clays that are part of the matrix are usually less reactive.', 'Additionally, clays can be cementing, or grain-binding, materials that react with water or acid to disaggregate the formation if they are not protected by quartz overgrowths.', 'The most common clays that create clay problems in hydrocarbon reservoirs are kaolinite, smectite, illite and chlorite.', 'Clays in formation rock can significantly impact estimation of hydrocarbon reserves and the methods and costs for producing the stored hydrocarbons from formation rock.', 'In evaluating unconventional formation rock such as shale that contains clays, determining clay type and composition is a significant challenge considering the chemical complexity and heterogeneous nature of the unconventional formation rock.', 'In the downhole environment, gamma ray logs have been traditionally used to estimate formation shale/clay volume based on correlation related to inherent elements such as potassium, uranium and thorium.', 'Combining density, neutron and spectral natural gamma ray logs, one can determine clay density and neutron response to 100% clay at every depth and also determine clay volume independent of the clay types.', 'Combining such knowledge allows the calculation of CEC and hydrogen index (HI), and from the CEC vs. HI crossplot, clay typing is possible.', 'Nonetheless, such measurements do not have enough sensitivity to allow for the determination of complex mineralogy.', 'In a laboratory setting, there are multiple techniques for elemental and mineralogical analysis for rock samples, most important are X-ray fluorescence (XRF), X-ray diffractometry (XRD), Fourier transform infrared spectroscopy (FTIR), and Diffuse reflectance infrared Fourier-transform spectroscopy (DRIFTS) in addition to qualitative thin section analysis under polarized transmitted light.', 'In all cases, it is necessary to prepare the required samples to certain standards.', 'XRF is an electroscopic technique that employs a secondary or fluorescent emission generated by exciting a sample with a source of X-radiation.', 'The energy absorbed by the atoms cause the production of secondary x-ray and fluorescence, emitted by the sample.', 'The intensity of these secondary x-rays is proportional to the concentration of each element in the sample.', 'XRF allows fast identification of elements heavier than Lithium (Z=3) in theory.', 'But in practice, it is often difficult to quantify elements lighter than Sodium (Z=11).', 'Currently, portable fluorescence devices allow real-time measurements, which translate to fast decision making on the field.', 'They offer the possibility to analyze samples without the need of any previous preparation.', 'Despite the advances in portable devices, the accuracy that can be expected from its results is still lower than the one that can be obtained by means of laboratory analytic techniques although it can be enhanced using reference samples.', 'It is also noted that XRF measures elements, converting elements to minerals is an inversion process which may require calibrations and boundary conditions to ensure converging solutions.', 'In XRD, when an x-ray diffraction beam strikes the surface, the matter absorbs the radiation to a greater or lesser extent, depending on the different mechanisms of interaction that are registered, either fluorescent type or disperse radiations.', 'The dispersive one constituted by the fraction of the incident energy that is emitted again without changing its wavelength.', 'X-ray diffraction is a particular case of this type of radiation.', 'The constant distances of each crystalline structure originate a characteristic distribution of maximums (peaks), which allows identifying the crystals qualitatively; the intensity of these peaks is proportional to the number of planes that diffract the incident beams, what happens just with certain angles of incidence.', 'In such a case, a semi-quantitative concentration of a specific structure can be obtained by analyzing the area under the curve.', 'Each peak is assigned to an intensity value and, with this information, the crystal or crystals to which the diffraction pattern investigated belongs are identified.', 'Peaks of some minerals overlap and therefore depending on their concentration, minerals with little concentration can be completely mischaracterized with others.', 'This can create large quantification errors in sample mineral analysis which can be above 20% depending on the characterized mineral.', 'In addition, for low angle diffraction lines (peaks) such as clays, the signal to noise ratio is usually poor, and due to the amount of disorders that can occur in clays structures, quantifying clays accurately is often difficult.', 'It is also noted that XRD works only for crystalline, not for amorphous materials.', 'FTIR have been extensively used for mineral identification.', 'Generally, sample preparation is extensive for FTIR.', 'Specifically, potassium bromide (KBr) is mixed with specific mesh size sample powder and then pressed into a pellet and heated at 120° C. to remove water.', 'Data is usually recorded in the range of 4000 to 400 cm\n−1 \nusing a spectral resolution of 4 cm\n−1\n.', 'FTIR can provide chemical and mineral information on complex samples such as shales without the need for separating clays.', 'Although FTIR is a powerful technique for mineral characterization, it does have some limitations with respect to clay quantification.', 'DRIFTS has recently been introduced as a commercial service for material mineralogy characterization.', 'It is a fast and efficient technique for quantifying mineralogy from OBM-free core and cuttings samples.', 'DRIFTS can be used in a laboratory or at a wellsite.', 'It is not a downhole technique.', 'It measures the vibrational absorbance due to chemical bonds and is capable of resolving illite, smectite, kaolinite, and chlorite.', 'Samples are usually scanned as bulk powders without dilution in reflectance mode and spectra are collected over the mid-IR range from 375 to 4000 cm\n−1 \nwith 4 cm\n−1 \nresolution.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'In accordance with the subject disclosure, methods and systems are provided for clay detection, clay typing, and clay volume quantification using downhole electromagnetic measurements on a subsurface formation conducted by a logging tool.', 'The downhole electromagnetic measurements are conducted at a low frequency less than 5000 Hertz (“Hz”) and used to determine and store permittivity data that characterizes permittivity of the formation at the low frequency less than 5000 Hz.', 'The downhole low frequency electromagnetic measurements are nondestructive, and the results indicate the methods and systems are highly sensitive to the existence of clays.', 'In embodiments, the methods and systems can employ a computational model that relates a parameter extracted from measurement of permittivity of a formation at a low frequency less than 5000 Hz to data that characterizes at least one clay type and corresponding clay volume fraction.', 'Downhole electromagnetic measurements can be conducted on a formation of interest at a low frequency less than 5000 Hz, and the results of such downhole electromagnetic measurements can be used to determine and store permittivity data that characterizes permittivity of the formation of interest at the low frequency less than 5000 Hz.', 'A parameter can be extracted from the permittivity data.', 'The extracted parameter can be used as input to the computational model, wherein the computational model outputs data that characterizes at least one clay type and corresponding clay volume fraction for the formation of interest.', 'The data that characterizes at least one clay type and corresponding clay volume fraction for the formation of interest as provided by the computational model can be stored or output for use, such as for use in evaluating the formation of interest.', 'In embodiments, the computational model can be derived by measuring permittivity of formations of different known clay types and different clay volume fractions at the low frequency less than 5000 Hz (such as multiple low frequencies less than 5000 Hz) and correlating a parameter extracted from the resultant permittivity to data that characterizes at least one clay type and corresponding clay volume fraction.', 'In embodiments, the computational model can relate a parameter extracted from measurement of permittivity of a formation at multiple low frequencies less than 5000 Hz to data that characterizes at least one clay type and corresponding clay volume fraction.', 'The permittivity data of the formation of interest as well as the parameter extracted from the permittivity data can be derived from the electromagnetic measurements of permittivity of the formation of interest at the multiple low frequencies less than 5000 Hz.', 'In embodiments, the multiple low frequencies less than 5000 Hz can comprise at least three frequencies less than or equal to 100 Hz (and possibly a set of at least three frequencies between 100 Hz and 1 Hz).', 'In embodiments, the parameter of the computational model as well as the parameter extracted from the measurement of permittivity of the formation of interest can be selected from the group consisting of a frequency-specific slope, a frequency-specific permittivity, a critical frequency where the measurement of permittivity of the formation of interest diverges from permittivity of a formation that does not have clay, and combinations thereof.', 'In embodiments, the at least one clay type can be selected from the group consisting of kaolinite, smectite, illite, chlorite, and combinations thereof.', 'In embodiments, the porous media sample can be a formation rock sample.', 'In this case, the data that characterizes at least one clay type and corresponding clay volume fraction as output from the computational model can be used to calculate a value of cation exchange capacity (CEC) for the formation rock sample.', 'The data that characterizes at least one clay type and corresponding clay volume fraction as output from the computational model can also be used for evaluation of a hydrocarbon reservoir corresponding to the formation rock sample.', 'In embodiment, the extracting of the parameter can be performed by a processor.', 'The computational model can also be embodied by a processor.', 'The operations of the method or system or parts thereof can also be controlled by a processor.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe subject disclosure is further described in the detailed description which follows, in reference to the noted plurality of drawings by way of non-limiting examples of the subject disclosure, in which like reference numerals represent similar parts throughout the several views of the drawings, and wherein:\n \nFIG.', '1\n is a schematic diagram illustrating an electrical double layer model of interfacial polarization of clay particles;\n \nFIG.', '2\n depicts plots of relative permittivity ε\nr \ncomputed as a function of frequency (in Hz) for a shaly sandstone formation rock under different saturation conditions (including 10% water saturation/90% oil saturation, 40% water saturation/60% oil saturation, 60% water saturation/40% oil saturation, 80% water saturation/20% oil saturation, and 100% water saturation/0% oil saturation);\n \nFIG.', '3\n depicts plots of relative permittivity ε\nr \ncomputed as a function of frequency (in Hz) for quartz mixed with smectite of different volume fractions (including 0.1%, 0.5%, 1%, 2%, 5%, 10%, 30% and 50%).', 'For comparison, the relative permittivity ε\nr \ncomputed as a function of frequency for clean sandstone (pure quartz) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%;\n \nFIG.', '4\n depicts a correlation curve that represents a relationship between relative permittivity at 1 Hz (ε\nr\n, 1 Hz) and a volume fraction of smectite clay (V\nsmectite\n) using data extracted from the measurements of \nFIG.', '3\n;\n \nFIG.', '5\n depicts a plot of relative permittivity ε\nr \ncomputed as a function of frequency (in Hz) for sandstone samples mixed with different clay types (kaolinite, illite, chlorite and smectite) of the same 20% volume fraction with a total porosity of 30%.', 'For comparison, the relative permittivity ε\nr \ncomputed as a function of frequency for a clean sandstone sample (no clay) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%;\n \nFIG.', '6\nA\n is a block diagram of a well logging system that can incorporate aspects of the subject disclosure;\n \nFIG.', '6\nB\n is a schematic illustration of a logging tool that can be part of the well logging system of \nFIG.', '6\nA\n;\n \nFIG.', '7\n is a flowchart illustrating a methodology for clay detection, clay typing, and clay volume quantification using a logging tool (such as the logging tool of \nFIGS.', '6\nA and \n6\nB\n) for downhole electromagnetic measurements performed on a formation of interest and dispersed at low frequencies (below 5000 Hz).', 'The downhole electromagnetic measurements are used to determine permittivity of the formation of interest at the low frequencies (below 5000 Hz);\n \nFIG.', '8\n is block diagram of a computer processing system, which can be used to embody parts of the methodology for clay detection, clay typing, and clay volume quantification as described herein;\n \nFIG.', '9\n is a schematic diagram illustrating the combination of mineralogy data obtained from low-frequency downhole electromagnetic measurements with other minerology log data (such as minerology data obtained from conventional nuclear-based measurements) in order to characterize and evaluate lateral reservoir geological heterogeneity in a vertical wellbore environment.', 'DETAILED DESCRIPTION', 'The particulars shown herein are by way of example and for purposes of illustrative discussion of the embodiments of the subject disclosure only and are presented in the cause of providing what is believed to be the most useful and readily understood description of the principles and conceptual aspects of the subject disclosure.', 'In this regard, no attempt is made to show structural details in more detail than is necessary for the fundamental understanding of the subject disclosure, the description taken with the drawings making apparent to those skilled in the art how the several forms of the subject disclosure may be embodied in practice.', 'Furthermore, like reference numbers and designations in the various drawings indicate like elements.', 'Interfacial polarization can be observed in formation rock containing clays (such as shaly sands) and in other porous media containing clays.', 'When the surface of a nonconductive mineral, such as clay minerals and silica grains, are exposed to electrolytes, it acquires charges due to ionic adsorption, protonation/deprotonation of the hydroxyl groups, and dissociation of other potentially active surface groups.', 'In the presence of an external electromagnetic (EM) field, these surface charges form electric dipoles and cause interfacial polarization (IP) effects.', 'The strength of the IP effects is regulated by permittivity of the formation rock or other porous media.', 'The present disclosure provides a framework or methodology for clay detection, clay typing, and clay volume quantification using a downhole logging tool for downhole electromagnetic measurements on a formation of interest that are dispersed at low frequencies (below 5000 Hz).', 'The low frequency downhole electromagnetic measurements are used to determine permittivity of the formation of interest at the low frequencies (below 5000 Hz).', 'The low frequency downhole electromagnetic are nondestructive, and the results indicate the methodology is with high sensitivity to the existence of clays compared to other conventional specialized mineralogical and elemental clay quantification methods such as x-ray diffraction, x-ray fluorescence, and Fourier-transform infrared spectroscopy.', 'In embodiments, clay minerals can be lumped together on the basis of molecular structure and composition into four commonly encountered and representative clay types: kaolinite, illite, chlorite and smectite.', 'Although each one of these clay types impacts formation conductivity differently, the fundamental mechanism is similar.', 'When the surface of a clay mineral grain is exposed to electrolytes, it acquires charges due to ionic adsorption, protonation/deprotonation of the hydroxyl groups, and dissociation of other potentially active surface groups.', 'Under an external electromagnetic (EM) field, both electrical conduction (due to charge carries) and interfacial polarization (due to surface charges) influences the measured EM fields.', 'Electrical conduction describes the movement of the charge carries under the influence of the external EM field.', "This is a well understood phenomena and can be described by Ohm's law.", 'The polarization of clay particles is mostly due to charge accumulation and movements at host-inclusion interfaces.', 'The most common theory to describe the interfacial polarization is the electrical double layer shown in \nFIG.', '1\n.', 'At the surface of the clay particles, both Stern and diffuse layers are formed due to charge absorptions and movements.', 'In the presence of an applied external electromagnetic field, the double layer develops a counter ion cloud and diffused-charge distribution around host-inclusion interfaces.', 'Dynamics of accumulation/depletion of charge concentrations around host-inclusion interfaces influence the magnitude and phase of the EM response of the formation rock containing clay minerals or other porous media containing clay minerals.', 'The electrical conductivity of the porous media can be described by a complex conductivity σ given by: \n σ=σ\nR\n+iωε\n0\nε\nr\n, and\u2003\u2003Eqn.', '(1a) \n σ=σ\nR\n+iωε\neff\n\u2003\u2003Eqn. (1b) \n \nwhere σ\nR \nis the in-phase component and ωε\n0\nε\nr \nis the quadrature (out-phase) component of a complex conductivity σ, respectively; \n \n \n \nω is frequency,\n \nε\n0 \nis the permittivity of vacuum (e.g., 8.854×10\n−12 \nF·m\n−1\n),\n \nε\nr \nis the relative permittivity, and\n \nε\neff \nis the effective permittivity given by the product ε\n0\n*ε\nr\n.', 'For a porous media containing clay minerals, the relative permittivity ε\nr \nand the effective permittivity ε\neff \ndepend on clay type and volume of each clay type.', 'In addition, the relative permittivity ε\nr \nand the effective permittivity ε\neff \ncan be calculated based on effective media theory.', 'In embodiments, the EM response signal of the porous media can be detected by one or more receiver antennae (e.g., receiver coil(s)).', 'Phased-lock detection and amplification of the EM response signal can determine the amplitude and phase of the voltage levels detected by the one or more receiver antennae.', 'By recording and processing the amplitude and phase of such voltage levels, a measurement of the complex conductivity σ of the porous media can be obtained.', 'The relative permittivity ε\nr \nand/or the effective permittivity ε\neff \nof the porous media can be extracted from the quadrature component of the complex conductivity σ according to eqns.', '(1a) and (1b) as set forth above.', 'FIG.', '2\n shows relative permittivity ε\nr \n(no unit) computed as a function of frequency (in Hz) for a shaly sandstone formation rock under different saturation conditions (including 10% water saturation/90% oil saturation, 40% water saturation/60% oil saturation, 60% water saturation/40% oil saturation, 80% water saturation/20% oil saturation, and 100% water saturation).', 'The shaly sandstone formation rock has 90% quartz and 10% smectite with a total porosity of 30%.', 'Very strong dispersion effects are observed below 1000 Hz.', 'The largest permittivity value can reach 2×10\n4 \n(F·m\n−1\n) at 1 Hz.', 'For frequencies larger than 1000 Hz, the permittivity has much smaller values and is non-dispersive.', 'Note that while parts of the curves show dependence on saturations, the dispersion section of the curves, for example in frequencies less than 100 Hz, is very insensitive to saturation.', 'This implies that the measurement of relative permittivity ε\nr \nof formation rock as a function of frequency, at low frequencies less than 100 Hz, is a sensitive indicator for clay detection and quantification of clay volumes irrespective of the saturation conditions of the formation rock.\n \nFIG.', '3\n shows relative permittivity ε\nr \n(no unit) computed as a function of frequency (in Hz) for quartz mixed with smectite of different volume fractions (including 0.1%, 0.5%, 1%, 2%, 5%, 10%, 30% and 50%).', 'For comparison, the relative permittivity ε\nr \n(no unit) computed as a function of frequency for clean sandstone (pure quartz) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%.', 'It is observed that while the clean sandstone has no dispersion effect, the shaly sandstone shows strong dispersion effects.', 'Specifically, the relative permittivities of the formation rock samples at a low frequency such as 1 Hz strongly depends on the respective volume fractions of the smectite clay component in the formation rock samples.', 'Even with 1% or less clay content, the dispersion curves show a huge difference from the clean sandstone, indicating the measurement of relative permittivity of the formation rock sample at a low frequency (such as, for example, 1 Hz) is a very sensitive technique to detect small amount of clays for characterization of the clay components of the formation rock sample.', 'In addition, the descending values of the relative permittivities of the formation rock samples at the low frequency (such as, for example, 1 Hz) are easily differentiable for different volume fractions of the smectite clay component in the formation rock samples.', 'The sensitivity to differentiate clean and slightly shaly rock appears to be an improvement over downhole nuclear elemental spectroscopy measurements as described herein.', 'In order to quantify clay volume, a computational model can be built that relates measurements of relative permittivity (or effective permittivity) at one or more low frequencies less than 5000 Hz to clay volume fraction.', 'In embodiments, the computational model can relate measurements of relative permittivity (or effective permittivity) at multiple (at least three) low frequencies (e.g. 1 Hz, 10 Hz and 100 Hz) to clay volume fraction.', 'For example, measurements of relative permittivity of a formation rock sample at 1 Hz can be related to clay volume fraction as shown in the correlation curve of \nFIG.', '4\n, which shows a relationship between relative permittivity at 1 Hz (ε\nr\n,1 Hz) and a volume fraction of smectite clay (V\nsmectite\n) using data extracted from the measurements of \nFIG.', '3\n.', 'This relationship demonstrates the sensitivity of low frequency permittivity on smectite clay volume and can be represented by:\n \n \n \n \n \n \n \n \n \nɛ\n \nr\n \n \n,', '1\n \n\u2062\n \n \n \n \n\u2062\n \nHz\n \n \n=\n \n \n \n1856.7\n \n*\n \n \nV\n \nsmectite\n \n \n \n+\n \n7.0\n \n \n \n,\n \nor\n \n \n \n \n \nEqn\n \n.', '\u2062\n \n \n(\n \n \n2\n \n\u2062\n \na\n \n \n)\n \n \n \n \n \n \n \n \n \nv\n \nsmectite\n \n \n=\n \n \n \n \n \nɛ\n \n \nr\n \n,\n \n \n1\n \n\u2062\n \n \n \n \n\u2062\n \nHz\n \n \n \n \n-\n \n \nɛ\n \n \nr\n \n,\n \n \nclean\n \n\u2062\n \n \n \n \n\u2062\n \nrock\n \n \n \n \n \nSlope\n \n \n=\n \n \n \n \nɛ\n \n \nr\n \n,\n \n \n1\n \n\u2062\n \n \n \n \n\u2062\n \nHz\n \n \n \n \n-\n \n7.0\n \n \n1856.7\n \n \n \n \n \n \n \nEqn\n \n.', '\u2062\n \n \n(\n \n \n2\n \n\u2062\n \nb\n \n \n)\n \n \n \n \n \n \n \n \n \nNote that the relationship of \nFIG.', '4\n and Eqns.', '(2a) and (2b) is an example, and thus other correlations and computational models can be used depending on the clay type, clay volume and a mixture of different clay types and clay volumes.', 'Laboratory measurements of relative permittivity (or effective permittivity) at the low frequency(ies) on reservoir rock samples of known or measured clay volumes can be used to determine the relationship between measured permittivity at one or more low frequencies and clay volume fractions individually or in mixtures.', 'FIG.', '5\n shows relative permittivity ε\nr \n(no unit) computed as a function of frequency (in Hz) for sandstone samples mixed with different clay types (kaolinite, illite, chlorite and smectite) of the same 20% volume fraction with a total porosity of 30%.', 'For comparison, the relative permittivity ε\nr \n(no unit) computed as a function of frequency for a clean sandstone sample (no clay) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%.', 'It is clearly observed that smectite and kaolinite have different relative permittivities at a low frequency such as 1 Hz, which are easily distinguishable from one another.', 'More specifically, the sandstone sample mixed with kaolinite at 20% volume fraction has a relative permittivity on the order of 40, while the sandstone sample mixed with smectite at 20% volume fraction has a relative permittivity ε\nr \non the order of 2.5×10\n4\n.', 'Furthermore, it is clearly observed that smectite and kaolinite have different critical frequencies where the measured relative permittivity deviates significantly from that of clean sandstone.', 'More specifically, the sandstone sample mixed with kaolinite at 20% volume fraction has a critical frequency at or near 10 Hz, while the sandstone sample mixed with smectite at 20% volume fraction has a critical frequency near 900 Hz.', 'Note that these two parameters of the measured permittivity at a low frequency cannot be used to distinguish the illite and chlorite clay types because these two clay types have almost the same electric properties.', 'In practical applications, permittivities at multiple low frequencies (e.g. 1 Hz, 10 Hz and 100 Hz) can be measured on core samples of the known different clay types (including the kaolinite, illite, chlorite, smectite and combinations of such clay types) and of known different clay type volume fractions, and such measurements can be processed in order to build a computational model (such as a correlation model) that relates parameters extracted from low frequency permittivity measurements into one or more clay types and corresponding clay type volume fractions.', 'The following conclusions can be based on \nFIGS.', '2\n, \n3\n, \n4\n and \n5\n.', 'First, measurements of relative permittivity ε\nr \n(or effective permittivity ε\neff\n) as a function of frequency at low frequencies have almost no dependence on water saturation of shaly sandstone formation rock.', 'This makes such measurements an ideal clay detector for all saturation conditions, pay zones or otherwise.', 'Second, the measurements of relative permittivity ε\nr \n(or effective permittivity ε\neff\n) of the formation rock at low frequencies (such as less than 1000 Hz) strongly depends on clay volume fractions for shaly sandstone formation rock.', 'Even with 1% or less clay content, the relative permittivity ε\nr \n(or the effective permittivity ε\neff\n) of the formation rock at the low frequency shows a huge difference from that of clean sandstone.', 'In addition, for formation rocks with different clay volume fractions, the relative permittivities (or effective permittivities) of the formation rocks at low frequency are easily differentiable for the different clay volume fractions.', 'Third, the measurements of relative permittivity ε\nr \n(or effective permittivity ε\neff\n) of formation rock at low frequencies (such as less than 1000 Hz) also strongly depends on clay types for shaly sandstone formation rock.', 'Furthermore, the presence of smectite and kaolinite clay types that commonly occur in a reservoir environment can be detected based on the measurements of relative permittivity ε\nr \n(or effective permittivity ε\neff\n) of formation rock at low frequency (such as less than 1000 Hz).', 'For example, the measurement of relative permittivity ε\nr \n(or effective permittivity ε\neff\n) of formation rock at a low frequency such as 1 Hz and/or the critical frequency that relative permittivity ε\nr \n(or effective permittivity ε\neff\n) of formation rock deviates from that of clean sandstone can be used to detect the presence of smectite and kaolinite clay types.', 'Note that these measurements cannot distinguish between illite and chlorite clay types as these two clays have almost the same electric properties.', 'Fourth, in order to detect different clays types (including smectite, kaolinite, illite and chlorite and combinations thereof) and to quantify the corresponding volume fraction of the different clay types, relative permittivity ε\nr \n(or effective permittivity ε\neff\n) of the formation rock can be measured at multiple low frequencies below 5000 Hz.', 'One or more parameters (such as a frequency-specific slope or frequency-specific measure(s) of permittivity) can be extracted from the multiple low frequency permittivity measurements and used in conjunction with a computational model (such as a correlation model) that relates such parameters to one or more clay types (such as smectite, kaolinite, illite, chlorite, and combinations thereof) and corresponding clay type volume fractions.', 'During the exploration and production of oil and gas, many well logging techniques can be deployed to log data of a subsurface formation.', 'The data contain information that can be used to locate subsurface hydrocarbon reservoirs and to determine types and quantities of subsurface hydrocarbons.', 'In such logging processes, a tool may be lowered into a borehole traversing a subsurface formation, either after the well has been drilled or during the drilling process.', 'A typical logging tool includes a “sonde”, that emits, for example, acoustic or EM waves to interact with the surrounding formation.', 'The signals produced from such interactions are then detected and measured by one or more sensors on the instrument.', 'By processing the detected signals, a profile or log of the formation properties can be obtained.', 'Logging techniques known in the art include “wireline” logging, logging-while-drilling (LWD), measurement-while-drilling (MWD), and logging-while-tripping (LWT).', 'Wireline logging involves lowering an instrument into an already-drilled borehole at the end of an electrical cable to obtain measurements as the instrument is moved along the borehole.', 'LWD and MWD involve disposing an instrument in a drilling assembly for use while a borehole is being drilled through earth formations.', 'LWT involves disposing sources or sensors within the drill string to obtain measurements while the string is being withdrawn from the borehole.', 'Turning now to \nFIG.', '6\nA\n, a wireline logging system \n1\n is shown that includes an electromagnetic (EM) logging tool \n10\n which is suspended via a cable \n12\n in a borehole \n14\n which traverses a formation \n15\n.', 'The cable \n12\n is wound about a winch \n17\n or suitable suspension means located at the surface of the earth formation, and may be utilized, if desired, to carry data (information) which is sent by the tool \n10\n to a processor \n20\n.', 'As is well known in the art, the gathered data may be preprocessed downhole by a processor (not shown) associated with the tool \n10\n and may be sent via the cable \n12\n, or via wireless mechanisms (e.g., mud pulsing) to the surface-located processor \n20\n for additional processing.', 'The processor \n20\n may be located in the vicinity of the formation \n15\n or at another site as desired.', 'Alternatively, raw data may be sent to the processor \n20\n.', 'As has been previously established, the mudcake on the borehole wall may be relatively conductive in the case where water-base mud is used in the borehole, or may be relatively resistive in the case where oil-base mud is used in the borehole.', 'It is desirable that the tool \n10\n can be configured for use in both situations.', 'In other embodiments, the logging tool \n10\n can be an LWD logging tool or MWD logging or LWT logging tool.', 'EM logging tools are widely used for formation logging applications.', 'EM logging tools include antennas that are operable as transmitters and/or receivers.', 'The antennas are typically solenoid coils.', 'During operation, a coil may function as a transmitter antenna when it is energized with an alternating current or an oscillating electrical signal.', 'The transmitter antenna emits EM waves through the borehole mud and into the surrounding earth formation.', 'The same coil or another coil may function as a receiver antenna that collects EM signals carrying information about the interactions between the EM waves and the mud/formation.', 'In conventional EM logging tools, the transmitter and receiver antennas are mounted with their axes aligned with the longitudinal axis of the instrument.', 'Thus, these tools are implemented with antennas having longitudinal magnetic dipoles (LMD).', 'When an LMD antenna is placed in a borehole and energized to transmit EM energy, the induced electric currents flow around the antenna in the borehole and in the surrounding earth formations, and no net current flows up or down the borehole.', "More recent EM well logging tools have tilted or transverse coils, i.e., the coil's axis is not parallel with the longitudinal axis of the support.", 'Consequently, the antenna has a transverse or tilted magnetic dipole (TMD).', 'The TMD configuration permits a tool to have a three-dimensional evaluation capability, such as information about resistivity anisotropy or locations and orientations of dips and faults.', 'In addition, directional sensitivity of the data can be used for directional drilling.', 'Under certain conditions, a TMD-antenna may cause a net current to flow up or down the borehole.', 'Some TMD-antennas are configured with multiple coils.', 'For example, a particular TMD-antenna design includes a set of three coils, and such an antenna is known as a triaxial antenna.', 'In wireline applications, the antennas are typically enclosed in a housing made of tough non-conductive materials such as a laminated fiberglass material.', 'In LWD applications, the antennas are generally encased into a metallic support so that it can withstand the hostile environment and conditions encountered during drilling.', 'Alternatively, logging instruments may be made of composite materials, thus, providing a non-conductive structure for mounting the antennas.', 'Induction logging is a well-known form of EM logging.', 'In this type of logging, induction tools are used to produce a conductivity or resistivity profile of earth formations surrounding a borehole.', 'A conventional induction logging tool or “sonde” may include a transmitter antenna and a receiver antenna.', 'Note that the designation of a transmitter and a receiver is for clarity of illustration.', 'One skilled in the art would appreciate that a transmitter may be used as a receiver and a receiver may also be used as a transmitter depending on the application.', 'Each antenna may include one or more coils, and may be mounted on the same support member or on different support members, i.e., the transmitter antenna and the receiver antenna may be on different tool sections.', 'The antennas are axially spaced from each other in the longitudinal direction of the tool.', 'In use, the transmitter antenna is energized with an alternating current.', 'This generates an EM field that induces eddy currents in the earth formation surrounding the borehole.', 'The intensity of the eddy currents is proportional to the conductivity of the formation.', 'The EM field generated by the eddy currents, in turn, induces an electromotive force in one or more receiving coils.', 'Phase-locked detection, amplification, and digitization of this electromotive force signal determines the amplitude and the phase of the voltage on the receiver coil.', 'By recording and processing the receiver voltages, a measurement of complex conductivity of the earth formation can be obtained.', 'The relative permittivity and/or the effective permittivity of the earth formation can be extracted from the quadrature component of the complex conductivity according to eqns.', '(1a) and (1b) as set forth above.', 'FIG.', '6\nB\n illustrates an induction logging tool \n10\n that includes a transmitter coil \n110\n, a receiver coil \n112\n for probing a shallow depth into the formation, a receiver coil \n115\n for probing a medium depth into the formation, and a receiver coil \n118\n for probing deeper into the formation.', 'Buckling coils or trim coils \n111\n, \n114\n, \n113\n, \n116\n, \n117\n and \n119\n are provided to eliminate or reduce direct coupling between the transmitter coil \n110\n and the receiver coils \n112\n, \n115\n and \n118\n.', 'In addition, the logging tool \n10\n can also include one or more electrodes (one shown as \n120\n in \nFIG.', '6\nB\n), such as those used in conventional conductivity/resistivity tools.', 'Details of the induction logging tool \n10\n are set forth in U.S. Pat.', 'No. 7,501,829, commonly assigned to assignee of the subject application and herein incorporated by reference in its entirety.', 'The transmitter antenna coil \n110\n can be energized with an alternating current of desired frequency (in Hz).', 'This generates an EM field that induces eddy currents in the earth formation surrounding the borehole.', 'The intensity of the eddy currents is proportional to the conductivity of the formation.', 'The EM field generated by the eddy currents, in turn, induces an electromotive force in the receiver coils \n112\n, \n115\n, \n118\n.', 'Phase-locked detection, amplification, and digitization of this electromotive force signal determines the amplitude and the phase of the voltage on the respective receiver coils \n112\n, \n115\n, \n118\n.', 'By recording and processing the receiver voltage signal sensed by the receiver coils \n112\n, \n115\n, \n118\n, measurements of complex conductivity of the earth formation can be obtained for three different radial depths (shallow/medium, deep) into the formation.', 'The relative permittivity and/or the effective permittivity of the earth formation at the respective depth locations (shallow, medium, deeper) can be extracted from the quadrature component of the complex conductivity measurements according to eqns.', '(1a) and (1b) as set forth above.', 'FIG.', '7\n depicts a workflow for clay detection, clay typing, and clay volume quantification using a logging tool (such as the logging tool of \nFIGS.', '6\nA and \n6\nB\n) for downhole electromagnetic measurements performed on a formation of interest and dispersed at low frequencies (below 5000 Hz).', 'The downhole electromagnetic measurements are used to determine permittivity of the formation of interest at the low frequencies (below 5000 Hz).', 'In block \n701\n, a computational model is built (or provided) that relates relevant parameters extracted from low frequency permittivity data (which is data derived from low frequency electromagnetic measurements that are used to determine permittivity of a formation) to data characterizing clay type(s) and clay volume fraction(s) of the formation.', 'The computational model can be built by configuring a downhole EM logging tool (such as the logging tools of \nFIGS.', '6\nA and \n6\nB\n) to conduct downhole electromagnetic measurements and determine permittivity of formations of known different clay types (including kaolinite, illite, chlorite, smectite and combinations of such clay types) and of known different clay type volume fractions at multiple low frequencies (e.g. 1 Hz, 10 Hz and 100 Hz).', 'Such low frequency downhole electromagnetic measurements can measure complex conductance of the formation.', 'Permittivity data can be determined from the complex conductance of the formation.', 'The permittivity data can represent effective permittivity or relative permittivity of the formation.', 'The permittivity data that results from such low frequency downhole electromagnetic measurements can be processed to extract one or more relevant parameters from the low frequency permittivity data (such as a frequency-specific slope or frequency-specific measure(s) of permittivity or critical frequency) and determine a correlation function or other data structure that describes the relationship between the extracted relevant parameter(s) and one or more clay types and corresponding clay type volume fractions.', 'The correlation function or other data structure can then be integrated as part of the computational model.', 'The computational model can be designed to take as input one or more relevant parameters extracted from low-frequency permittivity data.', 'The correlation function or other data structure of the computational model is used to output one or more clay types and corresponding clay type volume fractions that correspond to the relevant parameter(s) supplied as input to the computational model.', 'Although current laboratory techniques do not have the capabilities to detect low concentration of clays, calibration curves can be built based on artificial cores where a known amount of clay is synthesized and prepared for the different clay types as individual and in a mixed known amount.', 'Resistivity measurements can be conducted and at different frequencies and a calibration curve/model can be built and used to identify clay and its volume.', 'A similar or close calibration curve or model can be produced using the current available inversion models.', 'In block \n703\n, a downhole EM logging tool (such as the EM logging tool of \nFIGS.', '6\nA and \n6\nB\n) is configured to measure and store conductivity data representing conductivity of a formation of interest at multiple low frequencies less than 5000 Hz (e.g. 1 Hz, 10 Hz and 100 Hz).', 'In this block \n702\n, the downhole EM logging tool can be located in a desired depth location in a borehole that traverses the formation of interest and operated to measure complex conductivity data representing conductivity of the formation of interest at the multiple low frequencies less than 5000 Hz (e.g. 1 Hz, 10 Hz and 100 Hz).', 'For each one of the multiple low frequencies (e.g. 1 Hz, 10 Hz and 100 Hz) of the experiment, the frequency of the applied time varying external electromagnetic field produced by the transmitter antenna of the downhole EM logging tool can be controlled to correspond to the particular low frequency, and the electromagnetic response of the formation of interest can be measured by the downhole EM logging tool for that particular low frequency.', 'In block \n705\n, the conductivity data measured and stored in block \n703\n is processed to extract permittivity data representing permittivity of the formation of interest at the multiple low frequencies less than 5000 Hz (e.g. 1 Hz, 10 Hz and 100 Hz).', 'Such permittivity data can represent effective permittivity or relative permittivity of the formation of interest at the multiple low frequencies less than 5000 Hz (e.g. 1 Hz, 10 Hz and 100 Hz).', 'For example, the relative permittivity and/or the effective permittivity of the formation of interest can be extracted from the quadrature component of the complex conductivity of the formation of interest according to Eqn.', '(1a) and (1b) as set forth above.', 'In blocks \n707\n, \n709\n, \n711\n and \n713\n, the permittivity data measured and stored in block \n705\n, which represents permittivities of the formation of interest as a function of frequency, can be analyzed for clay detection and qualitative clay assessment.', 'For example, the permittivity data measured and stored in block \n705\n can be plotted in block \n707\n and the plot (or the permittivity data itself) can be analyzed for clay detection in block \n709\n.', 'For example, the plot (or the permittivity data itself) can be compared to measured permittivity values (e.g. curves) for one or more formations that are known to not have clay as well as to measured permittivity values (e.g. curves) for one or more formations of known clay types.', 'If the permittivity data measured and stored in block \n705\n is dissimilar to the measured permittivity values (e.g. curves) for the one or more formations that are known to not have clay and similar to the measured permittivity values (e.g. curves) for one or more formations of known clay types, the process can determine that the formation does contain clays in block \n711\n and continue to blocks \n713\n to \n719\n.', 'On the other hand, when the permittivity data measured and stored in block \n705\n is similar to measured permittivity values (e.g. curves) for the one or more formations that are known to not have clay and dissimilar to the measured permittivity values (e.g. curves) for the one or more formations of known clay types, the process can determine in block \n711\n that the formation does not contain clays and continue to block \n721\n.', 'In block \n713\n, the permittivity data measured and stored in block \n705\n can be analyzed for qualitative clay assessment.', 'For example, the permittivity data measured and stored in block \n705\n can be plotted and compared to measured permittivity values (e.g. curves) for one or more formations of known clay types.', 'The known clay type of the formation whose measured permittivity values best match the permittivity data measured and stored in block \n705\n can be identified as the clay type for the formation of interest.', 'In block \n715\n, the permittivity data measured and stored in block \n705\n can be processed to extract relevant parameter(s) of such data for input to the computational model of block \n701\n.', 'In block \n717\n, the relevant parameter(s) extracted in \n715\n can be used as input to the computational model, which outputs data characterizing one or more clay types and corresponding clay volume fractions for the formation of interest.', 'The data characterizing one or more clay types and corresponding clay volume fractions for the formation of interest as output by the computational model can be stored in computer memory for subsequent access or possibly output for analysis (for example, plotted as part of a well log).', 'In block \n719\n, the process can identify the formation of interest as shaly type and possibly use the data that characterizes the one or more clay types and corresponding clay volume fractions as output from the computational model in block \n717\n to evaluate the formation of interest.', 'For example, the data that characterizes the one or more clay types and corresponding clay volume fractions as output from the computational model in block \n717\n can be used to calculate a value of cation exchange capacity (CEC) for the formation of interest.', 'The value of CEC represents a quantity of positively charged ions (cations) that the formation of interest can accommodate on its negative charged surface.', 'It is typically expressed as milliequivalents per 100 grams.', 'The CEC value can be used in formation modeling and simulation of the formation of interest.', 'For example, if both clay types and clay volume fractions are known for each clay type, the total CEC values can be calculated using a mixing law as follows: \n CEC=\nw\nC\n×CEC\nC\n+w\nI\n×CEC\nI\n+w\nK\n×CEC\nK\n+w\nS\n×CEC\nS\n,\u2003\u2003Eqn.', '(3) \n where w\nC\n, w\nI\n, w\nK\n, w\nS \nare clay weight fractions for chlorite, illite, kaolinite and smectite, respectively; and CEC\nC\n, CEC\nI\n, CEC\nK \nand CEC\nS \nare CEC values for chlorite, illite, kaolinite and smectite.', 'The CEC value for each above-mentioned clay mineral is well defined and can be treated as a known parameter.', 'For example, the clay volume can be calculated as follows:\n \n \n \n \n \n \n \n \n \n \nV\n \ncl\n \n \n=\n \n \n \n \n \nρ\n \nmatrix\n \n \n\u2061\n \n \n(\n \n \n1\n \n-\n \n \n∅\n \ntotal\n \n \n \n)\n \n \n \n×\n \n \nW\n \ncl\n \n \n \n \nρ\n \ncl\n \n \n \n \n,\n \n \n \n \n \nEqn\n \n.', '\u2062\n \n \n(\n \n4\n \n)\n \n \n \n \n \n \n \n \n where ϕ\ntotal \nis the formation total porosity, ρ\nmatrix \nis matrix density, W\ncl \nis weight of clay, and ρ\ncl \nis density of clay.', 'In block \n721\n, the process can identify the formation of interest as non-shaly type for evaluation of the formation.', 'In other examples, for vertical wellbore environments, the mineralogy data that characterizes the one or more clay types and corresponding clay volume fractions as output from the computational model in block \n717\n can be combined with other minerology log data (such as minerology data obtained from conventional nuclear-based measurements) as part of block \n719\n in order to characterize and evaluate lateral reservoir geological heterogeneity.', 'This application is shown schematically in \nFIG. \n9\n.', 'Note that the mineralogy data output from the computational model in block \n717\n can characterize the mineralogy of the formation rock at a deeper lateral (or radial) offset into the formation relative to the vertical wellbore as compared to the mineralogy data of the other minerology log data, which can characterize the mineralogy of the formation rock at a shallower lateral (or radial) offset into the formation relative to the vertical wellbore.', 'In yet other examples, for while-drilling applications in horizontal wellbore environments, the minerology data that characterizes the one or more clay types and corresponding clay volume fractions as output from the computational model in block \n717\n can be used to identify shaly formation rock and control geosteering of the drill bit based thereon as part of block \n719\n in order to avoid shaly formation rock and maximize reservoir contact and well performance.\n \nFIG.', '8\n illustrates an example device \n2500\n, with a processor \n2502\n and memory \n2504\n that can be configured to implement various embodiments of the logging methodology and logging systems as discussed in this disclosure.', 'Memory \n2504\n can also host one or more databases and can include one or more forms of volatile data storage media such as random-access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).', 'Device \n2500\n is one example of a computing device or programmable device and is not intended to suggest any limitation as to scope of use or functionality of device \n2500\n and/or its possible architectures.', 'For example, device \n2500\n can comprise one or more computing devices, programmable logic controllers (PLCs), etc.', 'Further, device \n2500\n should not be interpreted as having any dependency relating to one or a combination of components illustrated in device \n2500\n.', 'For example, device \n2500\n may include one or more of computers, such as a laptop computer, a desktop computer, a mainframe computer, etc., or any combination or accumulation thereof.', 'Device \n2500\n can also include a bus \n2508\n configured to allow various components and devices, such as processors \n2502\n, memory \n2504\n, and local data storage \n2510\n, among other components, to communicate with each other.', 'Bus \n2508\n can include one or more of any of several types of bus structures, including a memory bus or memory controller, a peripheral bus, an accelerated graphics port, and a processor or local bus using any of a variety of bus architectures.', 'Bus \n2508\n can also include wired and/or wireless buses.', 'Local data storage \n2510\n can include fixed media (e.g., RAM, ROM, a fixed hard drive, etc.) as well as removable media (e.g., a flash memory drive, a removable hard drive, optical disks, magnetic disks, and so forth).', 'One or more input/output (I/O) device(s) \n2512\n may also communicate via a user interface (UI) controller \n2514\n, which may connect with I/O device(s) \n2512\n either directly or through bus \n2508\n.', 'In one possible implementation, a network interface \n2516\n may communicate outside of device \n2500\n via a connected network.', 'A media drive/interface \n2518\n can accept removable tangible media \n2520\n, such as flash drives, optical disks, removable hard drives, software products, etc.', 'In one possible implementation, logic, computing instructions, and/or software programs comprising elements of module \n2506\n may reside on removable media \n2520\n readable by media drive/interface \n2518\n.', 'In one possible embodiment, input/output device(s) \n2512\n can allow a user (such as a human annotator) to enter commands and information to device \n2500\n, and also allow information to be presented to the user and/or other components or devices.', 'Examples of input device(s) \n2512\n include, for example, sensors, a keyboard, a cursor control device (e.g., a mouse), a microphone, a scanner, and any other input devices known in the art.', 'Examples of output devices include a display device (e.g., a monitor or projector), speakers, a printer, a network card, and so on.', 'Some of the methods and processes described above, can be performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any particular device type or system.', 'The processor may include a computer system.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, or general-purpose computer) for executing any of the methods and processes described above.', 'The computer system may further include a memory such as a semiconductor memory device (e.g., a RAM, ROM, PROM, EEPROM, or Flash-Programmable RAM), a magnetic memory device (e.g., a diskette or fixed disk), an optical memory device (e.g., a CD-ROM), a PC card (e.g., PCMCIA card), or other memory device.', 'Some of the methods and processes described above, can be implemented as computer program logic for use with the computer processor.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Alternatively or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples without materially departing from this subject disclosure.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.']

['1.', 'A method for characterizing clay content of a subsurface formation of interest, the method comprising:\ni) configuring and operating a downhole logging tool to conduct a downhole electromagnetic measurement on the formation of interest at a frequency less than 5000 Hertz, wherein the downhole electromagnetic measurement is used to determine and store permittivity data that characterizes permittivity of the formation of interest at the frequency less than 5000 Hertz;\nii) extracting a parameter from the permittivity data that characterizes permittivity of the formation of interest at the frequency less than 5000 Hertz;\niii) comparing the parameter extracted from the permittivity data in ii) as an input to a computational model, wherein the computational model compares the parameter extracted from the permittivity data in ii) to measured data from at least one formation known to not have clay; and if the model determines the formation has clay;\niv) comparing, with the model, the parameter extracted from the permittivity data in ii) to measured data from at least one formation known to have clay; and\nv) identifying, with the model, at least one clay type and corresponding clay volume fraction for the formation of interest.', '2.', 'The method according to claim 1, further comprising:\nstoring or outputting the data that characterizes at least one clay type and corresponding clay volume fraction for the formation of interest as provided by the computational model in iii).', '3.', 'The method according to claim 1, wherein:\nthe computational model of iii) is derived by measuring permittivity of formations of different known clay types and different clay volume fractions at the frequency less than 5000 Hz and correlating a parameter extracted from the resultant permittivity to data that characterizes at least one clay type and corresponding clay volume fraction.', '4.', 'The method according to claim 1, wherein:\nthe computational model of iii) is derived by measuring permittivity of formations of different known clay types and different clay volume fractions at multiple frequencies less than 5000 Hertz and correlating a parameter extracted from the resultant permittivity to data that characterizes at least one clay type and corresponding clay volume fraction.', '5.', 'The method according to claim 1, wherein:\nthe computational model of iii) relates a parameter extracted from measurement of permittivity of a formation at multiple frequencies less than 5000 Hertz to data that characterizes at least one clay type and corresponding clay volume fraction;\nthe permittivity data determined and stored in i) as well as the parameter extracted from the permittivity data in ii) are derived from electromagnetic measurements conducted by the downhole logging tool on the formation of interest at the multiple frequencies less than 5000 Hertz.', '6.', 'The method according to claim 5, wherein:\nthe multiple frequencies less than 5000 Hertz comprises at least three frequencies less than or equal to 100 Hertz.', '7.', 'The method according to claim 5, wherein:\nthe multiple frequencies less than 5000 Hertz comprises a set of at least three frequencies between 100 Hertz and 1 Hertz.', '8.', 'The method according to claim 1, wherein:\nthe parameter extracted from the permittivity data in ii) and input to the computational model of iii) is selected from the group consisting of: a frequency-specific slope, a frequency-specific permittivity, a critical frequency where permittivity of the formation of interest diverges from permittivity of a formation that does not have clay, and combinations thereof.', '9.', 'The method according to claim 1, wherein:\nthe permittivity data of i) represents relative permittivity or effective permittivity of the formation of interest.', '10.', 'The method according to claim 1, wherein:\nthe permittivity data of i) is derived from a quadrature component of a measurement of complex conductivity of the formation of interest.', '11.', 'The method according to claim 1, wherein:\nthe at least one clay type is selected from the group consisting of: kaolinite, smectite, illite, chlorite, and combinations thereof.', '12.', 'The method according to claim 1, further comprising:\nusing the data that characterizes at least one clay type and corresponding clay volume fraction for the formation as output from the computational model in iii) to calculate a value of cation exchange capacity (CEC) for the formation.', '13.', 'The method according to claim 1, further comprising:\nusing the data that characterizes at least one clay type and corresponding clay volume fraction for the formation of interest as output from the computational model in iii) for evaluation of the formation of interest.\n\n\n\n\n\n\n14.', 'The method according to claim 1, further comprising:\ncombining the data that characterizes at least one clay type and corresponding clay volume fraction for the formation of interest as output from the computational model in iii) with other log data (such as conventional nuclear based mineralogy log data) for characterizing and evaluating near wellbore reservoir geological heterogeneity in a vertical wellbore.\n\n\n\n\n\n\n15.', 'The method according to claim 1, further comprising:\nusing the data that characterizes at least one clay type and corresponding clay volume fraction for the formation of interest as output from the computational model in iii) to identify shaly formation rock and control geosteering of the drill bit while drilling a horizontal wellbore based thereon in order to avoid shaly formation rock.\n\n\n\n\n\n\n16.', 'The method according to claim 1, wherein:\nthe extracting of the parameter in ii) is performed by a processor.', '17.', 'The method according to claim 1, wherein:\nthe computational model of iii) is embodied by a processor.', '18.', 'A system for characterizing clay content of a subsurface formation of interest, the system comprising:\na downhole logging tool that is configured to conduct an electromagnetic measurement on the formation of interest at a frequency less than 5000 Hertz, wherein the electromagnetic measurement measures and stores conductivity data that characterizes complex conductivity of the formation of interest at the frequency less than 5000 Hertz; and\nat least one processor that, when executing program instructions stored in memory, is configured to: i) obtain the conductivity data that characterizes complex conductivity of the formation of interest at the frequency less than 5000 Hertz, ii) process the conductivity data of i) to determine permittivity data that characterizes permittivity of the formation of interest at the frequency less than 5000 Hertz;\niii) extract a parameter from the permittivity data of ii); and\niv) use the parameter extracted from the permittivity data in iii) as an input to a computational model, wherein the computational model compares the parameter extracted from the permittivity data in ii) to measured data from at least one formation known to not have clay and, if the model determines the formation of interest contains clay, the computational model compares the parameter extracted from the permittivity data in ii) to at least one formation known to have clay, wherein the computation model further characterizes at least one clay type and corresponding clay volume fraction for the formation of interest.', '19.', 'The system according to claim 18, wherein:\nthe at least one processor is further configured to store or output the data that characterizes at least one clay type and corresponding clay volume fraction for the formation of interest as provided by the computational model in iv).', '20.', 'The system according to claim 18, wherein:\nthe permittivity data determined in ii) is derived from a quadrature component of the complex conductivity of the formation of interest.']

['FIG.', '1 is a schematic diagram illustrating an electrical double layer model of interfacial polarization of clay particles;; FIG.', '2 depicts plots of relative permittivity εr computed as a function of frequency (in Hz) for a shaly sandstone formation rock under different saturation conditions (including 10% water saturation/90% oil saturation, 40% water saturation/60% oil saturation, 60% water saturation/40% oil saturation, 80% water saturation/20% oil saturation, and 100% water saturation/0% oil saturation);; FIG.', '3 depicts plots of relative permittivity εr computed as a function of frequency (in Hz) for quartz mixed with smectite of different volume fractions (including 0.1%, 0.5%, 1%, 2%, 5%, 10%, 30% and 50%).', 'For comparison, the relative permittivity εr computed as a function of frequency for clean sandstone (pure quartz) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%;; FIG.', '4 depicts a correlation curve that represents a relationship between relative permittivity at 1 Hz (εr, 1 Hz) and a volume fraction of smectite clay (Vsmectite) using data extracted from the measurements of FIG. 3;; FIG.', '5 depicts a plot of relative permittivity εr computed as a function of frequency (in Hz) for sandstone samples mixed with different clay types (kaolinite, illite, chlorite and smectite) of the same 20% volume fraction with a total porosity of 30%.', 'For comparison, the relative permittivity εr computed as a function of frequency for a clean sandstone sample (no clay) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%;; FIG.', '6A is a block diagram of a well logging system that can incorporate aspects of the subject disclosure;; FIG.', '6B is a schematic illustration of a logging tool that can be part of the well logging system of FIG.', '6A;; FIG. 7 is a flowchart illustrating a methodology for clay detection, clay typing, and clay volume quantification using a logging tool (such as the logging tool of FIGS.', '6A and 6B) for downhole electromagnetic measurements performed on a formation of interest and dispersed at low frequencies (below 5000 Hz).', 'The downhole electromagnetic measurements are used to determine permittivity of the formation of interest at the low frequencies (below 5000 Hz);; FIG. 8 is block diagram of a computer processing system, which can be used to embody parts of the methodology for clay detection, clay typing, and clay volume quantification as described herein;; FIG.', '9 is a schematic diagram illustrating the combination of mineralogy data obtained from low-frequency downhole electromagnetic measurements with other minerology log data (such as minerology data obtained from conventional nuclear-based measurements) in order to characterize and evaluate lateral reservoir geological heterogeneity in a vertical wellbore environment.; FIG.', '2 shows relative permittivity εr (no unit) computed as a function of frequency (in Hz) for a shaly sandstone formation rock under different saturation conditions (including 10% water saturation/90% oil saturation, 40% water saturation/60% oil saturation, 60% water saturation/40% oil saturation, 80% water saturation/20% oil saturation, and 100% water saturation).', 'The shaly sandstone formation rock has 90% quartz and 10% smectite with a total porosity of 30%.', 'Very strong dispersion effects are observed below 1000 Hz.', 'The largest permittivity value can reach 2×104 (F·m−1) at 1 Hz.', 'For frequencies larger than 1000 Hz, the permittivity has much smaller values and is non-dispersive.', 'Note that while parts of the curves show dependence on saturations, the dispersion section of the curves, for example in frequencies less than 100 Hz, is very insensitive to saturation.', 'This implies that the measurement of relative permittivity εr of formation rock as a function of frequency, at low frequencies less than 100 Hz, is a sensitive indicator for clay detection and quantification of clay volumes irrespective of the saturation conditions of the formation rock.; FIG.', '3 shows relative permittivity εr (no unit) computed as a function of frequency (in Hz) for quartz mixed with smectite of different volume fractions (including 0.1%, 0.5%, 1%, 2%, 5%, 10%, 30% and 50%).', 'For comparison, the relative permittivity εr (no unit) computed as a function of frequency for clean sandstone (pure quartz) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%.', 'It is observed that while the clean sandstone has no dispersion effect, the shaly sandstone shows strong dispersion effects.', 'Specifically, the relative permittivities of the formation rock samples at a low frequency such as 1 Hz strongly depends on the respective volume fractions of the smectite clay component in the formation rock samples.', 'Even with 1% or less clay content, the dispersion curves show a huge difference from the clean sandstone, indicating the measurement of relative permittivity of the formation rock sample at a low frequency (such as, for example, 1 Hz) is a very sensitive technique to detect small amount of clays for characterization of the clay components of the formation rock sample.', 'In addition, the descending values of the relative permittivities of the formation rock samples at the low frequency (such as, for example, 1 Hz) are easily differentiable for different volume fractions of the smectite clay component in the formation rock samples.', 'The sensitivity to differentiate clean and slightly shaly rock appears to be an improvement over downhole nuclear elemental spectroscopy measurements as described herein.; FIG.', '5 shows relative permittivity εr (no unit) computed as a function of frequency (in Hz) for sandstone samples mixed with different clay types (kaolinite, illite, chlorite and smectite) of the same 20% volume fraction with a total porosity of 30%.', 'For comparison, the relative permittivity εr (no unit) computed as a function of frequency for a clean sandstone sample (no clay) is also plotted.', 'All the curves have a water saturation level of 20% and an oil saturation level of 80%.', 'It is clearly observed that smectite and kaolinite have different relative permittivities at a low frequency such as 1 Hz, which are easily distinguishable from one another.', 'More specifically, the sandstone sample mixed with kaolinite at 20% volume fraction has a relative permittivity on the order of 40, while the sandstone sample mixed with smectite at 20% volume fraction has a relative permittivity εr on the order of 2.5×104.', 'Furthermore, it is clearly observed that smectite and kaolinite have different critical frequencies where the measured relative permittivity deviates significantly from that of clean sandstone.', 'More specifically, the sandstone sample mixed with kaolinite at 20% volume fraction has a critical frequency at or near 10 Hz, while the sandstone sample mixed with smectite at 20% volume fraction has a critical frequency near 900 Hz.', 'Note that these two parameters of the measured permittivity at a low frequency cannot be used to distinguish the illite and chlorite clay types because these two clay types have almost the same electric properties.', 'In practical applications, permittivities at multiple low frequencies (e.g. 1 Hz, 10 Hz and 100 Hz) can be measured on core samples of the known different clay types (including the kaolinite, illite, chlorite, smectite and combinations of such clay types) and of known different clay type volume fractions, and such measurements can be processed in order to build a computational model (such as a correlation model) that relates parameters extracted from low frequency permittivity measurements into one or more clay types and corresponding clay type volume fractions.; FIG.', '6B illustrates an induction logging tool 10 that includes a transmitter coil 110, a receiver coil 112 for probing a shallow depth into the formation, a receiver coil 115 for probing a medium depth into the formation, and a receiver coil 118 for probing deeper into the formation.', 'Buckling coils or trim coils 111, 114, 113, 116, 117 and 119 are provided to eliminate or reduce direct coupling between the transmitter coil 110 and the receiver coils 112, 115 and 118.', 'In addition, the logging tool 10 can also include one or more electrodes (one shown as 120 in FIG.', '6B), such as those used in conventional conductivity/resistivity tools.', 'Details of the induction logging tool 10 are set forth in U.S. Pat.', 'No. 7,501,829, commonly assigned to assignee of the subject application and herein incorporated by reference in its entirety.', 'The transmitter antenna coil 110 can be energized with an alternating current of desired frequency (in Hz).', 'This generates an EM field that induces eddy currents in the earth formation surrounding the borehole.', 'The intensity of the eddy currents is proportional to the conductivity of the formation.', 'The EM field generated by the eddy currents, in turn, induces an electromotive force in the receiver coils 112, 115, 118.', 'Phase-locked detection, amplification, and digitization of this electromotive force signal determines the amplitude and the phase of the voltage on the respective receiver coils 112, 115, 118.', 'By recording and processing the receiver voltage signal sensed by the receiver coils 112, 115, 118, measurements of complex conductivity of the earth formation can be obtained for three different radial depths (shallow/medium, deep) into the formation.', 'The relative permittivity and/or the effective permittivity of the earth formation at the respective depth locations (shallow, medium, deeper) can be extracted from the quadrature component of the complex conductivity measurements according to eqns.', '(1a) and (1b) as set forth above.; FIG.', '7 depicts a workflow for clay detection, clay typing, and clay volume quantification using a logging tool (such as the logging tool of FIGS.', '6A and 6B) for downhole electromagnetic measurements performed on a formation of interest and dispersed at low frequencies (below 5000 Hz).', 'The downhole electromagnetic measurements are used to determine permittivity of the formation of interest at the low frequencies (below 5000 Hz).', '; FIG.', '8 illustrates an example device 2500, with a processor 2502 and memory 2504 that can be configured to implement various embodiments of the logging methodology and logging systems as discussed in this disclosure.', 'Memory 2504 can also host one or more databases and can include one or more forms of volatile data storage media such as random-access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).']

US11788540

Submersible pumping system thrust bearing gas venting

Aug 8, 2022

Arthur Ignatius Watson

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in the PCT Application PCT/US2016/055242, dated Dec. 14, 2016 (15 pages).; International Preliminary Report on Patentability issued in the PCT Application PCT/US2016/055242, dated Apr. 17, 2018 (11 pages).; International Search Report and Written Opinion issued in the PCT Application PCT/US2017/057777, dated Feb. 7, 2018 (18 pages).; International Preliminary Report on Patentability issued in the PCT Application PCT/US2017/057777, dated Apr. 23, 2019 (14 pages).; Office action issued in the U.S. Appl. No. 15/767,152, dated Nov. 5, 2020 (27 pages).; Office Action issued in the U.S. Appl. No. 16/344,290, dated Dec. 22, 2020 (25 pages).

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100364407; December 2002; KR; 2015178887; November 2015; WO; 2016053588; April 2016; WO

['A system and methodology are provided for enhancing the life and usefulness of a thrust bearing assembly in a submersible pumping system component.', 'The technique utilizes a thrust runner positioned adjacent a thrust bearing in the submersible pumping system component.', 'The thrust runner is rotated relative to the thrust bearing via a shaft.', 'Gas that may accumulate in a lower region beneath the thrust runner is vented through a passageway from the lower region to an upper region above the thrust runner.', 'The gas is vented to help maintain a hydrodynamic fluid film between the thrust runner and the thrust bearing.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'The present document is a continuation application of U.S. application Ser.', 'No. 15/767,152, filed Apr. 10, 2018, which is a National Phase filing of PCT Application No. PCT/US2016/055242, filed Oct. 4, 2016, which claims priority to U.S. Provisional Application Ser.', 'No. 62/239,958 filed Oct. 11, 2015, each of which is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nElectric submersible pumping (ESP) systems are used in a variety of well related applications and often comprise a submersible pump powered by a submersible motor which is protected by a motor protector, e.g. a seal section.', 'The traditional motor protector is located between the submersible pump and the submersible motor.', "The motor protector includes chambers which combine the functions of compensating for thermal expansion and contraction of motor oil, discharging motor oil into the well when the volume of motor oil exceeds the motor's capacity due to thermal expansion, and sealing of an internal driveshaft against leakage.", 'The motor protector comprises a thrust chamber assembly to carry axial thrust loads generated by operation of the submersible pump and by the weight of a rotating pumping assembly of the pump.', 'Additionally, the submersible motor may comprise a thrust chamber assembly to carry the weight of the motor shaft and rotors.', 'In some systems, the shaft of the protector and the shaft of the motor are rigidly joined and one thrust chamber is used to carry the entire thrust load as well as the weight of the shafts and internal assemblies supported by the shafts.', 'Generally, a thrust chamber assembly comprises a thrust runner and a thrust bearing.', 'The thrust runner is rotationally and axially affixed to the corresponding shaft, e.g. the motor protector shaft or the submersible motor shaft, and may be in the form of a thick disk with flat upper and lower faces.', 'The thrust runner rotates against a stationary thrust bearing.', 'A hydrodynamic fluid film of motor oil is generated between the thrust runner and the bearing support areas of the thrust bearing so as to support the thrust runner without excessive contact or wear between the thrust runner and the thrust bearing.', 'The effectiveness of the fluid film depends on adequate viscosity and lubricity of the motor oil with which the motor protector and submersible motor are filled.', 'During operation of the electric submersible pumping system, however, gas bubbles may be present in the motor oil.', 'The gas may be from a variety of sources, e.g. residual air from incomplete oil filling, dissolved gas that is liberated from the oil by agitation of the motor oil (or by changes in pressure or temperature), and/or gasification of components of the motor oil.', 'Gas between the thrust runner and the thrust bearing enables contact therebetween which can lead to excessive wear.', 'SUMMARY', 'In general, a system and methodology are provided for enhancing the life and usefulness of a thrust bearing assembly in a submersible pumping system component.', 'The technique utilizes a thrust runner positioned adjacent a thrust bearing in the submersible pumping system component.', 'The thrust runner is rotated relative to the thrust bearing via a shaft.', 'Gas that may accumulate in a lower region beneath the thrust runner is vented through a passageway from the lower region to an upper region above the thrust runner to help maintain a hydrodynamic fluid film between the thrust runner and the thrust bearing.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is an illustration of an electric submersible pumping system disposed in a borehole, according to an embodiment of the disclosure;\n \nFIG.', '2\n is a partial cross-sectional view of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;\n \nFIG.', '3\n is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;\n \nFIG.', '4\n is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;\n \nFIG.', '5\n is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;\n \nFIG.', '6\n is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;\n \nFIG.', '7\n is a schematic illustration of an example of a passageway with features to facilitate venting of gas from below a thrust runner, according to an embodiment of the disclosure; and\n \nFIG.', '8\n is a schematic illustration of another example of a passageway configured to facilitate venting of gas from below a thrust runner, according to an embodiment of the disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'Embodiments described herein provide a system and methodology which are able to enhance the life and usefulness of a thrust bearing assembly in a submersible pumping system component.', 'The system and methodology facilitate the venting of gas which could otherwise lead to excess wear and potential failure of thrust bearing system components.', 'Embodiments described herein may utilize a thrust runner positioned adjacent a thrust bearing in the submersible pumping system component.', 'For example, the thrust runner and thrust bearing may be part of a thrust bearing system in a submersible motor and/or motor protector.', 'The thrust bearing may generally be located beneath the thrust runner and the thrust runner may be rotated relative to the thrust bearing via a shaft.', 'Gas that may accumulate in a lower region beneath the thrust runner is vented through a passageway from the lower region to an upper region above the thrust runner to help maintain a hydrodynamic fluid film between the thrust runner and the thrust bearing.', 'It should be noted the terms upper/upward/above and lower/downward/beneath refer to relative positions along the wellbore.', 'In a non-vertical wellbore, for example, the direction leading toward the surface of the earth is the upper/upward/above direction and the direction leading away from the surface of the earth is the lower/downward/beneath direction.', 'The venting capability protects against gas bubbles which can arise in motor oil of an electric submersible pumping system, e.g. within a submersible motor or motor protector.', 'If gas bubbles are rising during operation of the electric submersible pumping system, the gas can become trapped in the thrust bearing assembly under a thrust runner unless vented as described herein.', 'One reason gas bubbles become trapped under the thrust runner is that centrifugal forces resist travel of the gas radially outwardly and around an outer diameter of the thrust runner.', 'While the shaft and the thrust runner are rapidly rotating with respect to the thrust bearing, centrifugal separation of gas from liquid occurs.', 'The liquid motor oil is segregated outwardly to an inner diameter of the surrounding component housing while the gas is segregated inwardly to a region surrounding the shaft.', 'As the layer of gas builds up around the shaft it may invade the region between the thrust runner and the thrust bearing and ultimately displace the motor oil therebetween.', 'Loss of the oil film between the thrust runner and the thrust bearing can cause friction damage to the bearing surfaces, but the venting passageway or passageways may be used to remove this gas and to protect the oil film.', 'Damage to the thrust bearing components or failure of those components may occur in a variety of operational situations unless the detrimental gas is properly vented.', 'For example, the damage or failure may occur while testing electric submersible pumping systems in test wells before shipping them to the field.', 'Because test wells generally are not pressurized other than by submergence of the electric submersible pumping system, air pockets remaining in the equipment due to imperfect filling are not readily dissolved in the motor oil.', 'However, damage due to the gas invasion between thrust bearing and thrust runner can be difficult to detect.', 'While in the field, damage may eventually escalate to cause thrust bearing failure without leaving evidence as to the root cause.', 'Furthermore, the possibility of gas damage tends to be discounted as the root cause of field failure because the elevated well pressure dissolves small atmospheric air bubbles.', 'However, well gases can temporarily dissolve into the motor oil during periods of higher pressure, e.g. shut down.', 'When the well pressure is subsequently drawn down as a result of pumping, gas can be liberated throughout the motor oil and may rise into the thrust chamber of the thrust bearing system.', 'Additionally, components of the motor oil itself can gasify over time at elevated temperatures.', 'The resulting gas can gradually rise and accumulate in the lower region under the thrust runner without proper venting.', 'According to embodiments described herein, a system and methodology are provided for venting gas that would otherwise be trapped under a thrust runner.', 'In some embodiments, passageways, e.g. axial passageways, near an outer surface of the shaft may be used to route trapped gas upwardly from a lower region below the thrust runner to an upper region above the thrust runner.', 'This venting prevents the gas from continually increasing and invading the bearing interface between the thrust runner and the thrust bearing.', 'In some embodiments, the venting passageway or passageways may take the form of holes through the runner near its inner diameter about the shaft.', 'In other examples, the passageway may be in the form of channels along a bore of the thrust runner or channels in an outer surface of the shaft.', 'The passageway also may comprise interconnecting holes formed through the shaft from the region below the thrust runner to the region above the thrust runner.', 'The venting passageway also may have other configurations, including canted passageways which are angled with respect to the axial direction to promote flow of gas up through the thrust runner.', 'The passageway or passageways also may be helical in shape or otherwise curvilinear to similarly facilitate movement of the gas up through the thrust runner.', 'In some embodiments, the passageway may comprise or work in cooperation with pumping features, such as eccentric openings, angled openings, scoops, or other features which facilitate the pumping action and flow of gas from the lower region to the upper region.', 'In addition to venting gas, the passageways described herein also increase the flow of oil heated by shearing in the thrust bearing.', 'The passageways enable flow of the heated oil to a region above the thrust runner, thus transferring heat away from the bearing.', 'As a result, the bearing is able to run at a lower temperature which maintains the viscosity and lubricity of the oil.', 'Referring generally to \nFIG.', '1\n, an embodiment of a submersible pumping system \n20\n, e.g. an electric submersible pumping system, is illustrated.', 'The submersible pumping system \n20\n may comprise a variety of components depending on the particular application or environment in which it is operated.', 'In the example illustrated, the pumping system \n20\n is in the form of an electric submersible pumping system comprising a submersible motor \n22\n, a submersible pump \n24\n powered by the submersible motor \n22\n, and a motor protector \n26\n.', 'As illustrated, the electric submersible pumping system \n20\n may be deployed in a borehole \n28\n, e.g. a wellbore, drilled in a geologic formation \n30\n.', 'The geologic formation \n30\n may contain desirable production fluids, such as petroleum.', 'In well applications, the borehole \n28\n may be lined with a wellbore casing \n32\n and a plurality of perforations \n34\n may be formed through the wellbore casing \n32\n and out into the geologic formation \n30\n.', 'The perforations \n34\n facilitate the flow of fluids, e.g. production fluids, from the formation \n30\n and into borehole \n28\n for pumping via submersible pumping system \n20\n.', 'The submersible pumping system \n20\n may be deployed downhole from a surface location \n36\n via a conveyance \n38\n.', 'By way of example, the conveyance \n38\n may comprise tubing \n40\n, e.g. production tubing or coiled tubing, coupled to submersible pumping system \n20\n via a connector \n42\n.', 'Electric power may be provided to submersible motor \n22\n through a power cable \n44\n.', 'When submersible motor \n22\n is electrically powered, the submersible motor \n22\n operates to power submersible pump \n24\n, e.g. a centrifugal pump, which then draws in fluid from borehole \n28\n through a pump intake \n46\n.', 'In the example illustrated, the fluid drawn in through pump intake \n46\n is pumped via submersible pump \n24\n upwardly through tubing \n40\n to a desired surface collection location or other collection location.', 'During operation of submersible pump \n24\n, the pumping of fluids upwardly through tubing \n40\n can place substantial axial loading on the system of shafts and couplings by which submersible motor \n22\n drives submersible pump \n24\n.', 'The system of shafts and couplings extends from submersible pump \n24\n down through motor protector \n26\n and into or through submersible motor \n22\n.', 'This axial loading is carried by at least one thrust bearing system \n48\n which may be located in motor protector \n26\n.', 'The submersible motor \n22\n also may comprise at least one thrust bearing system \n48\n to carry the weight of, for example, the shaft and rotors within submersible motor \n22\n.', 'Each thrust bearing system \n48\n comprises a thrust runner mounted on the shaft and a thrust bearing located in a thrust chamber, as described in greater detail below.', 'Referring generally to \nFIG.', '2\n, an embodiment of thrust bearing system \n48\n is partially illustrated in cross-section.', 'In this example, the thrust bearing system \n48\n is illustrated as deployed in a submersible pumping system component, and specifically in motor protector \n26\n.', 'However, the thrust bearing system \n48\n also may be employed in submersible motor \n22\n or in other suitable submersible pumping system components.', 'As illustrated, the motor protector \n26\n (or other submersible pumping system component) has an outer housing \n50\n which creates a thrust bearing chamber \n52\n for receiving the thrust bearing system \n48\n.', 'In the embodiment illustrated, the thrust bearing system \n48\n comprises a thrust bearing \n54\n, a thrust runner \n56\n, a shaft \n58\n, and a retention system \n60\n used to securely lock thrust runner \n56\n to shaft \n58\n.', 'The thrust bearing \n54\n may have various configurations, including the illustrated configuration in which the thrust bearing \n54\n comprises a thrust bearing pad \n62\n positioned to engage thrust runner \n56\n.', 'The thrust bearing \n54\n also may comprise a mounting structure \n64\n by which the thrust bearing \n54\n is secured to housing \n50\n.', 'For example, the thrust bearing \n54\n may be coupled with housing \n50\n via threaded engagement, spacers, pins, clips, fasteners, or other suitable mounting features.', 'The thrust runner \n56\n is rotationally and axially coupled to shaft \n58\n for rotation with shaft \n58\n.', 'The retention system \n60\n may comprise a variety of components for coupling thrust runner \n56\n to shaft \n58\n, but one embodiment utilizes a retainer ring \n66\n on a lower side of the thrust runner \n56\n and a two-piece ring \n68\n on an upper side of the thrust runner \n56\n.', 'The two-piece ring \n68\n axially locks the thrust runner \n56\n to the shaft \n58\n and cooperates with the retainer ring \n66\n to hold the thrust runner \n56\n at the desired axial position along shaft \n58\n.', 'It should be noted that shaft \n58\n may be constructed with a plurality of shaft sections coupled together and extending from submersible motor \n22\n to at least submersible pump \n24\n.', 'Prior to operation, the submersible motor \n22\n and motor protector \n26\n, including thrust bearing chamber \n52\n, are filled with a motor oil.', 'The motor oil may perform a variety of functions including establishing a hydrodynamic fluid film at an interface \n70\n between thrust bearing \n54\n, e.g. thrust pad \n62\n, and thrust runner \n56\n.', 'The hydrodynamic fluid film enables rotation of thrust runner \n56\n relative to thrust bearing \n54\n without undue wear.', 'As described above, however, gas bubbles may form in or migrate into thrust bearing system \n48\n and may migrate into a lower region \n72\n beneath thrust runner \n56\n.', 'If a sufficient amount of gas builds up in lower region \n72\n, the gas can invade into the interface \n70\n and cause damage or failure as thrust runner \n56\n is rotated with respect to thrust bearing \n54\n.', 'In the embodiment illustrated, gas that may build up is vented out of the lower region \n72\n and to a less harmful location, such as an upper region \n74\n located above the thrust runner \n56\n.', 'The gas is vented from the lower region \n72\n to the upper region \n74\n via a passageway \n76\n disposed within an outer surface \n78\n of the thrust runner \n56\n.', 'As illustrated, the outer surface \n78\n may be the outer circumferential surface of the thrust runner \n56\n.', 'In some applications, the gas may further be vented from upper region \n74\n to another location in the submersible pumping system \n20\n and/or to a wellbore annulus surrounding the submersible pumping system \n20\n.', 'The passageway \n76\n may be routed along a variety of pathways in various positions, orientations, and patterns.', 'Additionally, the passageway \n76\n may comprise a single passageway or a plurality of passageways between lower region \n72\n and upper region \n74\n.', 'In many applications, the passageway \n76\n comprises a plurality of passageways disposed at or proximate shaft \n58\n.', 'The central location of passageway \n76\n is useful because centrifugal separation moves gas toward the central location of shaft \n58\n during operation of thrust bearing system \n48\n.', 'In the example illustrated in \nFIG.', '2\n, the passageway \n76\n comprises at least one passageway disposed through thrust runner \n56\n in an axial direction from lower region \n72\n to upper region \n74\n.', 'The retainer ring \n66\n and the two-piece ring \n68\n may be formed with recesses or gaps \n80\n, \n82\n, respectively, to avoid blocking the free flow of gas from lower region \n72\n to upper region \n74\n.', 'In some applications, a pin \n84\n or other suitable retention member may be used to secure the two-piece ring \n68\n at a desired rotational position to maintain alignment of passageway \n76\n with gap \n82\n.', 'A similar retention member may be used to hold retainer ring \n66\n in the desired rotational position.', 'During operation of thrust bearing system \n48\n, the gas that may accumulate in lower region \n72\n is thus provided with a vent path via passageway \n76\n to a less problematic region, e.g. upper region \n74\n.', 'Referring generally to \nFIG.', '3\n, another embodiment of thrust bearing system \n48\n is illustrated.', 'In this example, at least one passageway \n76\n is in the form of a channel disposed along an inside surface \n86\n of the thrust runner \n56\n.', 'The inside surface \n86\n is the surface defining the bore which receives shaft \n58\n, and thus the passageway \n76\n is effectively positioned between the thrust runner \n56\n and the shaft \n58\n.', 'The passageway \n76\n may be oriented in an axial direction, i.e. parallel with the axis of shaft \n58\n, or the passageway \n76\n may be canted with respect to the axis of shaft \n58\n, e.g. helically canted.', 'Additionally, the passageway \n76\n may comprise a single channel or a plurality of channels having desired cross-sectional configurations.', 'For example, each channel of passageway \n76\n may be in the form of a rectangular groove such as a keyway or other type of groove with a rounded bottom.', 'The gaps \n80\n, \n82\n may similarly be located in retainer ring \n66\n and two-piece ring \n68\n to facilitate the flow of gas from lower region \n72\n to upper region \n74\n.', 'Referring generally to \nFIG.', '4\n, another embodiment of thrust bearing system \n48\n is illustrated.', 'In this example, at least one passageway \n76\n is in the form of a channel disposed along an outside surface \n88\n of the shaft \n58\n.', 'Again, the passageway \n76\n is effectively positioned between the thrust runner \n56\n and the shaft \n58\n.', 'The passageway \n76\n along outside surface \n88\n may be axial and parallel with the axis of shaft \n58\n or the passageway \n76\n may be canted with respect to the axis of shaft \n58\n, e.g. helically canted.', 'Additionally, the passageway \n76\n may comprise a single channel or a plurality of channels having desired cross-sectional configurations.', 'For example, each channel of passageway \n76\n may be in the form of a rectangular groove such as a keyway or other type of groove with a rounded bottom.', 'The gaps \n80\n, \n82\n may similarly be located in retainer ring \n66\n and two-piece ring \n68\n to facilitate the flow of gas from lower region \n72\n to upper region \n74\n.', 'Referring generally to \nFIG.', '5\n, another embodiment of thrust bearing system \n48\n is illustrated.', 'In this example, passageway \n76\n is routed along a central region within shaft \n58\n.', 'According to an embodiment, the passageway \n76\n comprises an internal axial passage \n90\n extending along a central region of shaft \n58\n.', 'In some applications, the internal axial passage \n90\n is a central bore which runs generally parallel with the shaft \n58\n along the longitudinal axis of shaft \n58\n.', 'The internal axial passage \n90\n is placed in communication with lower region \n72\n and upper region \n74\n via lateral passages \n92\n, e.g. radial passages, to enable the flow of gas from lower region \n72\n to upper region \n74\n.', 'In some embodiments, the lateral passages \n92\n may be canted with respect to a radial line so as to promote positive pumping of fluid, e.g. gas, from the lower region \n72\n to the upper region \n74\n.', 'Referring generally to \nFIG.', '6\n, another embodiment of the thrust bearing system \n48\n is illustrated.', 'In this example, passageway \n76\n may be routed along a variety of pathways such as the illustrated channel along inner surface \n86\n of thrust runner \n56\n.', 'Additionally, the illustrated embodiment comprises an outer pumping feature \n94\n, e.g. a groove, disposed along an outer region of the thrust runner \n56\n.', 'The groove may be in the form of a channel or of a space between sides of a vane or vanes disposed along the outer surface of the thrust runner \n56\n and extending from the lower region \n72\n to the upper region \n74\n.', 'The groove \n94\n may be a single groove or a plurality of grooves which work in cooperation with the passageway \n76\n to enable circulation of flow between the upper region and the lower region.', 'In this type of embodiment, the radially inward passageway \n76\n effectively pumps fluid/gas upwardly and the radially outward groove \n94\n enables recirculation of fluid flow back to the lower region \n72\n.', 'The circulation reduces resistance to upward fluid flow through passageway \n76\n and can increase the effectiveness of gas venting to the upper region \n74\n.', 'The radially outward groove \n94\n also may be angled from vertical, e.g. helically oriented, to further promote a pumping action with respect to the flowing fluid.', 'In some embodiments, the outer pumping feature \n94\n may comprise features other than the illustrated groove and may include veins in the outer surface of the thrust runner \n56\n or holes near the outer surface of the thrust runner \n56\n.', 'The thrust bearing system \n48\n may utilize a variety of features to promote a pumping action and thus a flow of fluid along passageway \n76\n.', 'As illustrated in \nFIG.', '7\n, the passageway \n76\n may be canted at an angle \n96\n with respect to an axial direction along a longitudinal axis of shaft \n58\n.', 'For example, the passageway \n76\n may comprise one or more vent holes canted outwardly from the shaft \n58\n such that the upper end of the passageway \n76\n is located radially outward relative to the lower end of the passageway \n76\n.', 'In some applications, the passageway \n76\n may be canted to follow a helical path \n98\n, as illustrated in \nFIG.', '8\n.', 'The features to facilitate flow also may comprise intake and/or discharge features \n100\n located at the intake and/or discharge ends of the passageway \n76\n.', 'Examples of intake and discharge features \n100\n may comprise enlarged openings \n102\n.', 'As illustrated, the enlarged openings \n102\n may be asymmetric or eccentric with respect to the passageway \n76\n and oriented to facilitate incoming and/or outgoing flow with respect to passage \n76\n.', 'The enlarged openings \n102\n also may be constructed in the form of protruding scoops to capture and direct fluid, e.g. gas, into the passageway \n76\n or to draw fluid out of the passageway \n76\n.', 'Features \n100\n also may comprise funnel shaped passages to concentrate fluid flow or other features which cooperate with passage \n76\n to facilitate the pumping action which moves fluid/gas from lower region \n72\n to upper region \n74\n.', 'As discussed above, the gas in upper region \n74\n may be directed to other locations within electric submersible pumping system \n20\n and/or to regions in the surrounding wellbore annulus.', 'For example, the gas may be vented to the wellbore annulus by suitable components, such as a labyrinth chamber, a relief valve, a gravity separation chamber, or another suitable device.', 'In various embodiments described herein, the passageways \n76\n for venting gas from under the thrust runner \n56\n are located at a position radially inward of the inner diameter of thrust bearing \n54\n.', 'In other words, the passageway \n76\n is located at a smaller radius position relative to shaft \n58\n than the bearing surface being protected, e.g. radially inward from thrust bearing pad \n62\n.', 'The passageway \n76\n also may be canted or otherwise routed to facilitate a pumping action and/or to provide an unobstructed path for movement of gas from lower region \n72\n to upper region \n74\n.', 'Depending on the application, the thrust bearing system \n48\n may be located in motor protector \n26\n, submersible motor \n22\n, and/or in another suitable pumping system component.', 'Additionally, the thrust bearing system \n48\n may comprise various arrangements of components constructed from suitable materials to provide the desired support with respect to thrust loading during operation of the submersible pumping system.', 'Various types of fastening mechanisms may be utilized in coupling the thrust runner to the shaft and in mounting the thrust bearing.', 'Additionally, the passageway \n76\n may comprise a single vent path or a plurality of vent paths routed along the shaft \n58\n and/or thrust runner \n56\n.', 'Similarly, the submersible pumping system \n20\n may comprise many types of components in a variety of arrangements to enable pumping of desired fluids in a given operation.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A method, comprising:\npositioning a thrust runner adjacent a thrust bearing in a submersible pumping system component;\nplacing an upper region above the thrust runner in communication with a lower region below the thrust runner via a passageway located at or proximate the shaft;\ncoupling the thrust runner to a shaft via a retention system comprising one or more gaps in fluid communication with the passageway to allow gas to flow at least one of from the lower region into the passageway or from the passageway into the upper region;\nrotating the thrust runner relative to the thrust bearing via the shaft; and\nventing gas through the passageway from the lower region beneath the thrust runner to the upper region above the thrust runner.', '2.', 'The method as recited in claim 1, wherein the positioning comprises positioning the thrust runner and the thrust bearing in the submersible pumping system component which is in the form of a submersible motor.', '3.', 'The method as recited in claim 1, wherein the positioning comprises positioning the thrust runner and the thrust bearing in the submersible pumping system component which is in the form of a motor protector.', '4.', 'The method as recited in claim 1, wherein the venting comprises routing the passageway through at least a portion of the thrust runner.', '5.', 'A method, comprising:\npositioning a thrust runner entirely axially above and adjacent a thrust bearing in a motor protector or submersible motor of a submersible pumping system;\nrotating the thrust runner relative to the thrust bearing via a shaft; and\nventing gas bubbles separated from motor oil through a passageway from a lower region beneath the thrust runner to an upper region above the thrust runner, wherein the venting comprises routing the passageway along an outer surface of the shaft from the lower region beneath the thrust runner to the upper region above the thrust runner.', '6.', 'The method as recited in claim 5, wherein the positioning comprises positioning the thrust runner and the thrust bearing in the submersible pumping system component which is in the form of a submersible motor.', '7.', 'The method as recited in claim 5, wherein the positioning comprises positioning the thrust runner and the thrust bearing in the submersible pumping system component which is in the form of a motor protector.']

['FIG.', '1 is an illustration of an electric submersible pumping system disposed in a borehole, according to an embodiment of the disclosure;; FIG.', '2 is a partial cross-sectional view of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;; FIG.', '3 is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;; FIG.', '4 is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;; FIG.', '5 is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;; FIG.', '6 is a partial cross-sectional view of another example of a thrust bearing system for use in a submersible pumping system component, according to an embodiment of the disclosure;; FIG. 7 is a schematic illustration of an example of a passageway with features to facilitate venting of gas from below a thrust runner, according to an embodiment of the disclosure; and; FIG. 8 is a schematic illustration of another example of a passageway configured to facilitate venting of gas from below a thrust runner, according to an embodiment of the disclosure.']

US11913766

Shaped charge integrated canister

Mar 10, 2022

Andrew Prisbell, Atsushi Nakano, Terry Butler

Schlumberger Technology Corporation

NPL References not found.

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['A charge canister for a perforation tool has a cylindrical body with an expansion portion extending along a radius of the cylindrical body, the expansion portion having a narrow portion at a first end of the expansion portion and a wide portion at a second end of the expansion portion opposite from the first end.', 'An explosive material is disposed within the expansion portion in direct contact with an interior surface thereof.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis patent application claims benefit of U.S. Provisional Patent Application Ser.', 'No. 63/160,426 filed Mar. 12, 2021, which is entirely incorporated herein by reference.', 'FIELD\n \nPerforation tools and components used in hydrocarbon production are described herein.', 'Specifically, charge-integrated loading tubes and perforation tools employing such loading tubes are described herein.', 'BACKGROUND\n \nPerforation tools are tools used in oil and gas production to form holes, passages, and/or fractures in hydrocarbon-bearing geologic formations to promote flow of hydrocarbons from the formation into the well for production.', 'The tools generally have explosive charges shaped to project a jet of reaction products, including hot gases and molten metal, into the formation.', 'Typically, the tool has a generally tubular profile, and includes support frames, ignition circuits, and potentially wiring for activating the charges and communicating signals and/or data along the tool.', 'The charges are generally shaped like a cone or a bell, and the charges are generally activated by delivering energy, such as thermochemical energy and/or electrical energy, to an apex region of the charge.', 'The shaped charges conventionally used have a casing to hold explosive material, the explosive material pressed into the casing, and a liner pressed onto the explosive material to retain the explosive material and protect the explosive material from the environment.', 'The shaped charges are installed into a frame that has retention features to secure the shaped charge within the frame.', 'Installing and removing shaped charges from frames lengthens assembly time for perforation tools and increases cost and complexity of shaped charge frames.', 'Improved shaped charge perforation tools are needed.', 'SUMMARY\n \nEmbodiments described herein provide a charge canister for a perforation tool, the charge canister comprising a cylindrical body having an expansion portion extending along a radius of the cylindrical body, the expansion portion having a narrow portion at a first end of the expansion portion and a wide portion at a second end of the expansion portion opposite from the first end; and an explosive material disposed within the expansion portion in direct contact with an interior surface thereof.', 'Other embodiments described herein provide a perforation tool, comprising a tubular housing; an initiation module disposed within the housing, the initiation module comprising a detonator housing protruding from an end of the initiation module for housing a detonator; and a charge canister disposed within the housing, the charge canister comprising a cylindrical body an expansion portion extending along a radius of the cylindrical body, the expansion portion having a narrow portion at a first end of the expansion portion and a wide portion at a second end of the expansion portion opposite from the first end; and an explosive material disposed within the expansion portion in direct contact with an interior surface thereof.', 'Other embodiments described herein provide a method of making a charge canister for a perforation tool, the method comprising disposing an explosive mixture into an expansion portion of a charge canister, the charge canister comprising a cylindrical body having the expansion portion extending along a radius of the cylindrical body, the expansion portion having a narrow portion at a first end of the expansion portion and a wide portion at a second end of the expansion portion opposite from the first end, the explosive material in direct contact with an interior surface of the expansion portion; disposing a liner against the explosive material within the expansion portion; and pressing the liner against the explosive material to set the explosive material and the liner into the expansion portion.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a perspective view of a charge canister according to one embodiment.\n \nFIG.', '2\n is a cross-sectional view of the charge canister of \nFIG.', '1\n.', 'FIG.', '3\n is a cross-sectional view of a perforation tool, according to one embodiment.\n \nFIG.', '4\n is a cross-sectional view of a charge canister according to another embodiment.', 'DETAILED DESCRIPTION', 'The perforation tools described herein use charge canisters that have explosive material integrated into the canister so that charges do not need to be attached and detached from a frame.', 'In one category, canisters described herein have a cylindrical body with a central passage along an axis thereof, and one or more expansion portions formed in the cylindrical body.', 'Each expansion portion has a narrow portion disposed near the central passage and extends radially outward from the central passage to a wide portion.', 'The narrow portion of each expansion portion has an opening that provides fluid communication with the central passage.', 'Explosive material is integrated into each expansion portion in direct contact with an interior surface of the expansion portion, without the use of a casing or other body to carry the explosive material.', 'In another category, canisters described herein do not have a central passage.', 'In such canisters the expansion portions extend substantially from one side of the cylindrical body to the opposite side, such that the axis of the cylindrical body is between the narrow portion and the wide portion of each expansion portion.', 'The explosive material of the canisters described herein cannot be removed as a modular unit.', 'For example, these canisters do not have self-contained modular shaped charges that can be installed and removed.', 'The explosive material is integrally disposed within the canister in a way that the explosive material becomes an unremovable component of the canister.', 'Such construction simplifies use of perforation tools because installation of shaped charges into the canister is not needed.', 'The canister is just assembled with an initiator module, and optionally with a seal module, to yield a perforation tool.\n \nFIG.', '1\n is a perspective view of a charge canister \n100\n according to one embodiment.', 'The charge canister \n100\n has a cylindrical body \n102\n with a central axis \n104\n and a central passage \n106\n through the cylindrical body \n102\n along the central axis \n104\n.', 'The central passage \n106\n accommodates an electrical conductor \n108\n, which is a cylindrical body that, in this case, contacts an interior wall of the central passage \n106\n around the entire circumference of the electrical conductor \n108\n.', 'The electrical conductor \n108\n is tubular, with a central passage of its own to accommodate a booster charge or other ballistic transfer device.', 'The electrical conductor \n108\n is formed with a “male” end and a “female” end, when installed in the charge canister \n100\n the male and female ends located at opposite ends of the cylindrical body \n102\n.', 'The male and female ends of the electrical conductor \n108\n facilitate physical and electrical connection with another similar electrical conductor of another module.', 'When the charge canister \n100\n is deployed in a perforation tool, the electrical conductor \n108\n will engage physically and electrically with another electrical conductor of another module, as further described below.', 'The electrical conductor \n108\n is inserted into the central passage \n106\n until the female end contacts the cylindrical body \n102\n.', 'In that position, both the male and female ends of the electrical conductor \n108\n may protrude from opposite ends of the cylindrical body \n102\n.', 'The electrical conductor \n108\n can be secured within the central passage \n106\n by using a fastening feature, such as a snap ring or other device, at the male end of the electrical conductor \n108\n.', 'It should be noted that in other embodiments, the electrical conductor \n108\n might not contact the inner wall of the central passage \n106\n around its entire circumference.', 'For example, the central passage \n106\n may be formed with axial ridges that maintain a space between the outer wall of the electrical conductor \n108\n and the inner wall of the central passage \n106\n.', 'The cylindrical body \n102\n has at least one expansion portion \n110\n.', 'The expansion portion \n110\n is generally radially symmetric and extends along a radius of the cylindrical body \n102\n from a narrow portion, at a first end of the expansion portion \n110\n, to a wide portion, at a second end of the expansion portion \n110\n opposite from the first end.', 'In some cases, the expansion portion \n110\n can extend along an axis of radial symmetry of the expansion portion \n110\n that is angled with respect to a radius of the cylindrical body \n102\n.', 'The narrow portion of the expansion portion \n110\n is adjacent to the central passage \n106\n of the cylindrical body \n102\n.', 'There can be any number of expansion portions \n110\n, which can be disposed in the same transvers plane of the cylindrical body \n102\n or can be displaced along the axis of the cylindrical body \n102\n in any convenient way.', 'The expansion portion, or portions \n110\n, are thus generally conical in shape or cup-shaped with a linear or monotonically curved profile, the profile being continuous or discontinuous.', 'At the narrow portion of the expansion portion \n110\n is an opening (not shown) that provides fluid communication between the interior of the central passage \n106\n and an interior of the expansion portion \n110\n.', 'The opening transmits ballistic energy from the central passage \n106\n, for example from a booster charge or other ballistic device located within the central passage \n106\n, to the interior of the expansion portion \n110\n.', 'A primer may be located in the opening to ensure ballistic energy reaches the interior of the expansion portion \n110\n.', 'The central passage \n106\n thus extends between the expansion portions \n110\n of the cylindrical body \n102\n with the narrow ends of the expansion portions \n110\n adjacent to the central passage \n106\n and the expansion portions \n110\n extending radially outward from the central passage \n106\n, and the narrow ends adjacent thereto, to the wide ends of the expansion portions.', 'Two expansion portions \n110\n are visible in \nFIG.', '1\n, located generally along the same transverse plane of the cylindrical body \n102\n.', 'Any number of expansion portions \n110\n may be provided in the charge canister \n100\n.', 'The expansion portions \n110\n are generally uniformly distributed around the cylindrical body \n102\n, with uniform azimuthal distribution.', 'Here, the expansion portions \n110\n are arranged in coplanar fashion along one plane perpendicular to the central axis \n104\n.', 'In other cases, the expansion portions \n110\n may be distributed along the central axis \n104\n, and a mixture of coplanar and axially distributed expansion portions may be used in some cases.', 'The expansion portions \n110\n have no retention features for holding shaped charges.', 'The interior surface of the expansion portions \n110\n are generally smooth, and the wide portion of each expansion portion \n110\n has a smooth rim, with no retention feature for holding a shaped charge.', 'A liner \n112\n is disposed within the expansion portion \n110\n.', 'The liner \n112\n is pressed into the expansion portion \n110\n and holds an explosive material (not shown in \nFIG.', '1\n) within the expansion portion \n110\n.', 'The liner \n112\n is typically secured into the expansion portion \n110\n using an adhesive material or an adhering device.', 'The interior surface of the expansion portions \n110\n may have a surface treatment to enhance adhesion of the explosive material to the interior surface.', 'The surface treatment may include applying an adhesive or may include creating a roughness, for example by sand blasting, scoring, abrading, and the like.', 'Pressing the explosive material into the interior surface of the expansion portions \n110\n results in adhesion of the explosive material to the interior surfaces.', 'Where an adhesive is applied to the interior surface the adhesive is generally applied in a way that does not obstruct the opening at the narrow portion of the expansion portion.', 'The liner \n112\n is a conical or dome-shaped object with a rim and an apex.', 'The apex is typically pressed into the explosive material, and the rim generally contacts the interior surface of the expansion portion \n110\n when pressed down onto the explosive material.', 'The liner \n112\n may be secured by applying an adhesive to the rim before pressing into the explosive material so that when the liner \n112\n contacts the interior surface, the adhesive holds the liner \n112\n in place.', 'Alternately, a retention feature, such as a groove, tab, ledge, or other suitable feature may be provided at the interior surface of the expansion portion \n110\n to capture the rim of the liner \n112\n.', 'The cylindrical body \n102\n may have alignment features for setting the direction of the expansion portions \n110\n and/or for aligning the charge canister \n100\n with other modules.', 'A first alignment feature \n114\n is located at an end of the cylindrical body \n102\n for aligning the charge canister \n100\n with another module in a downhole tool assembly such as a perforation tool.', 'Here, the first alignment feature \n114\n is a plurality of recesses, but any convenient configuration can be used, such as bumps, ridges, grooves, textured surfaces, and the like.', 'The recesses of the first alignment feature \n114\n would engage with matching bumps on another module to align the charge canister \n100\n with the module.', 'Note that here the plurality of recesses facilitates an adjustable alignment between the charge canister \n100\n and another module.', 'A similar alignment feature may be provided on the opposite end of the cylindrical body \n102\n (not visible in \nFIG.', '1\n).', 'A second alignment feature \n116\n is shown on a side of the cylindrical body \n102\n for aligning the charge canister \n100\n within a housing, for example a housing of a perforation tool.', 'The second alignment feature \n116\n is configured here as a plurality of grooves formed in the external surface of the side of the cylindrical body \n102\n, the grooves extending in the direction of the central axis \n104\n.', 'The grooves can engage with matching ridges formed on an interior surface of a housing for accepting the charge canister \n100\n, such that the charge canister \n100\n can be disposed in a desired alignment within the housing.', 'A plurality of the grooves, and matching ridges, can be provided for adjustable alignment.', 'The second alignment feature \n116\n can take any convenient form, such as grooves, ridges, tabs, and the like, but will typically allow the charge canister \n100\n to be moved within the housing in an axial direction for installation and removal.', 'Here, the second alignment feature \n116\n is formed at both ends of the charge canister \n100\n to facilitate insertion into a housing in either axial orientation (either end can be inserted first into the housing).', 'The cylindrical body \n102\n is shown here as a homogeneous, monolithic, member.', 'Generally, the cylindrical body \n102\n is a structurally strong member capable of withstanding the rigors of downhole detonation.', 'The cylindrical body \n102\n may be made of metal, for example steel, or another hard material such as a hard plastic.', 'The cylindrical body may be a combination of steel and plastic.', 'For example, a plastic cylindrical body may have steel inserts in the expansion portions thereof to support application of high pressure to set the explosive material and liners.', 'Where the inner wall of the central passage \n106\n is metal, an insulator may be used between the electrical conductor \n108\n and the central passage \n106\n.', 'The insulator may be a coating on the outside of the electrical conductor \n108\n, a coating on the inner wall of the central passage \n106\n, or a separate member inserted into the central passage \n106\n between the inner wall of the central passage \n106\n and the electrical conductor.', 'The charge canister \n100\n is shown with expansion portions \n110\n that are recesses within the cylindrical body \n102\n.', 'In another embodiment, the charge canister can be a substantially tubular body with expansion bells extending radially outward from the tubular body as expansion portions.', 'Such a charge canister can be a single metal piece with a hollow tubular portion for electrical and ballistic conductivity, the expansion bells having openings at the narrow ends thereof to provide fluid communication with the interior of the tubular portion.', 'Such a charge canister can be overmolded with plastic, if desired, to form alignment features.', 'FIG.', '2\n is a cross-sectional view of the charge canister \n100\n.', 'As described above, an explosive material \n202\n is disposed in the expansion portion \n110\n in direct physical contact with an interior surface thereof.', 'The explosive material \n202\n is pressed between the liner \n112\n and the interior surface of the expansion portion \n110\n.', 'The liner \n112\n and the interior surface of the expansion portion \n110\n are shaped to mold the explosive material \n202\n into a desired shape for projecting an optimized jet of material outward from the expansion portion \n110\n into a subterranean formation.', 'The liner \n112\n is also in direct physical contact with the interior surface of the expansion portion \n110\n to hold the explosive material \n202\n securely by adhering to the interior surface.', 'As noted above, a retention feature can also be provided to secure the liner \n112\n.', 'A thin wall \n204\n at the narrow end of the expansion portion \n110\n separates the interior of the expansion portion \n110\n from the interior of the central passage \n106\n.', 'A booster material is disposed within the central passage \n106\n, adjacent to the narrow end of the expansion portion \n110\n, to provide ballistic energy that penetrates through the wall \n204\n into the expansion portion \n110\n to discharge the explosive material \n202\n.', 'A primer \n206\n may be disposed at the narrow end of the expansion portion \n110\n, adjacent to the wall \n204\n, to amplify the ballistic energy transfer from the central passage \n106\n.', 'The booster material may be a booster charge or a detonation cord.', 'Where a booster charge is used, the electrical conductor (not shown in \nFIG.', '2\n) may have an interior circumferential ridge to position the booster charge adjacent to the wall \n204\n.', 'The wall \n204\n has a thickness sufficient to provide support during insertion and fixing of the explosive material \n202\n and the liner \n112\n within the expansion portion \n110\n.', 'Alternately, a small pinhole may be provided in the wall \n204\n, so long as the wall \n204\n retains enough strength to support the explosive material \n202\n and the liner \n112\n during fixing in the expansion portion \n110\n.\n \nFIG.', '3\n is a cross-sectional view of a perforation tool \n300\n according to one embodiment.', 'The perforation tool \n300\n has a housing \n302\n that contains an initiation module \n304\n, a bulkhead module \n306\n, and one or more of the charge canisters \n100\n.', 'Two canisters \n100\n are shown in the perforation tool \n300\n, but any number can be installed in a housing \n302\n.', 'The housing \n302\n has grooves \n308\n formed in an external surface of the housing.', 'The grooves \n308\n are formed, in this case, around the entire circumference of the housing \n302\n.', 'The grooves \n308\n provide a thin wall section to promote penetration of the perforation jet through the housing \n302\n upon activation of the charges.', 'The housing \n302\n may have positioning features, such as ridges or tabs protruding radially inward from the inner wall of the housing \n302\n, to aid in positioning the charge canisters \n100\n with the expansion portions \n110\n adjacent to the grooves \n308\n.', 'The initiation module \n304\n has an initiation circuit \n310\n, in this case positioned in an orientation transverse to a central axis \n312\n of the perforation tool \n300\n.', 'The central axis \n312\n of the perforation tool \n300\n aligns with the central axis \n104\n of the charge canisters \n100\n in this case, but the modules could be configured to provide an offset of the central axis \n104\n from the central axis \n312\n.', 'The initiation circuit \n310\n is electrically coupled to a detonator \n316\n disposed in a detonator housing \n314\n of the initiation module \n304\n.', 'The detonator housing \n314\n, and detonator \n316\n, may protrude from an end of the initiation module \n304\n into the end of a charge canister \n100\n to provide ballistic discharge into the interior of the electrical conductor \n108\n.', 'A booster \n318\n is disposed within the electrical conductor \n108\n of each charge canister \n100\n.', 'The electrical conductors \n108\n of the charge canisters engage by male/female connection to provide a continuous fluid pathway along the central passages \n106\n of the charge canisters \n100\n.', 'The bulkhead module \n306\n is disposed within the housing \n302\n, with the charge canisters \n100\n between the bulkhead module \n306\n and the initiation module \n304\n.', 'The bulkhead module \n306\n has a central passage \n320\n, similar to the charge canisters \n100\n, with a bulkhead electrical conductor \n322\n disposed therein.', 'The bulkhead electrical conductor \n322\n has a female end that engages with a male end of an electrical conductor \n108\n of a charge canister \n100\n to provide electrical continuity from the charge canisters \n100\n to the bulkhead module \n306\n.', 'The electrical conductor \n322\n conducts electricity from the end of the bulkhead module \n306\n near the charge canister \n100\n to the opposite end of the bulkhead module \n306\n to provide electrical continuity for the charge canister \n100\n.', 'As described above in connection with \nFIG.', '1\n, the canisters \n100\n have an explosive material \n330\n disposed in the expansion portions \n110\n thereof in direct contact with an interior surface \n332\n of the expansion portion.', 'The liner \n112\n is in direct contact with the explosive material \n330\n and with the interior surface \n332\n of the expansion portion \n110\n.', 'The liner is secured by adhesion, or other retention device, within the expansion portion \n110\n.', 'The embodiments described herein include a method of making a charge canister for a perforation tool.', 'An explosive mixture is disposed into an expansion portion of a cylindrical body.', 'The cylindrical body may have one expansion portion or a plurality of expansion portions.', 'The expansion portion is a bell-shaped, or generally expansion-shaped, body or recess with an interior for accepting the explosive mixture.', 'The expansion portion has a narrow portion at a first end thereof and a wide portion at a second end thereof, opposite from the first end.', 'The explosive mixture is deployed through the wide end to the narrow end of the expansion portion and rests in direct physical contact with the interior surface of the expansion portion at the narrow end thereof.', 'The cylindrical body, with expansion portion, may be according to any of the embodiments described herein.', 'A liner is disposed in the expansion portion in direct physical contact with the explosive mixture and with the interior surface of the expansion portion.', 'The liner is then pressed, using high pressure such as 40,000 psi, into the expansion portion against the explosive material.', 'The explosive material is pressed against the interior surface of the expansion portion, and is held in place by adhering, of otherwise securing, the liner to the interior surface of the expansion portion.', 'The explosive material may contain a binder material that can enhance adhesion of the explosive material to the interior surface, and the interior surface can be provided with a texture, for example a roughening, grooving, abrasion, scratching, or the like to enhance adhesion.', 'The liner and interior surface of the expansion portion are shaped to mold the explosive material into a desired shape with a volume defined between the liner and the interior surface to provide an optimized jet of combustion products and liner material outward from the wide end of the expansion portion into a subterranean formation.', 'The cylindrical body includes a central passage adjacent to the narrow end of the expansion portion.', 'An opening is provided at the narrow end of the expansion portion for fluid communication between the central passage and the interior of the expansion portion.', 'Ballistic energy is provided in the central passage, and flows through the opening to the explosive material disposed in the interior of the expansion portion to discharge the explosive material.\n \nFIG.', '4\n is a cross-sectional view of a shaped charge canister \n400\n according to another embodiment.', 'The canister \n400\n uses large shaped charges that extend across the canister \n400\n from side to side, with no central passage.', 'The shaped charge canister \n400\n is also modular, comprising a plurality of frames \n402\n that hold shaped charges, each frame \n402\n holding one charge.', 'Two frames \n402\n are shown here, but the canister \n400\n could have one frame \n402\n, three frames \n402\n, or more, in concept without limit.', 'Each frame \n402\n has an expansion portion \n404\n that holds a shaped charge \n405\n.', 'The shaped charge canister \n400\n is a generally cylindrical body, and each frame \n402\n has a generally cylindrical profile.', 'The canister \n400\n has a central axis \n406\n that is an axis of the cylindrical shape of the canister \n400\n.', 'Each expansion portion \n404\n has a narrow portion \n408\n at a first end of the expansion portion \n404\n and a wide portion \n410\n at a second end of the expansion portion \n404\n opposite from the first end.', 'The expansion portion \n404\n expands in width from the narrow portion \n408\n to the wide portion \n410\n, providing a recess to house the shaped charge \n405\n.', 'The central axis \n406\n is between the narrow portion \n408\n and the wide portion \n410\n of each expansion portion \n404\n.', 'A ballistic transfer device \n412\n is disposed near the narrow portion \n408\n to provide ballistic discharge to detonate explosive material of the shaped charge \n405\n.', 'A port \n414\n at the narrow portion \n408\n provides fluid communication from the ballistic transfer device \n412\n into the expansion portion \n404\n to detonate the explosive material.', 'Explosive material \n420\n is disposed in direct contact with an interior surface \n418\n of the expansion portion \n404\n.', 'A liner \n422\n is disposed in the expansion portion \n404\n.', 'An outer surface of the liner \n422\n, together with the interior surface \n418\n of the expansion portion \n404\n defines a space into which the explosive material \n420\n is disposed.', 'The liner \n422\n is thus in direct contact with the explosive material \n420\n, which in turn is also in direct contact with the interior surface \n418\n.', 'The liner \n422\n comes into direct contact with the interior surface \n418\n at a rim area \n416\n of the interior surface \n418\n, which is near the wide portion \n410\n.', 'The liner \n422\n may be secured using adhesive to attach the liner \n422\n to the interior surface \n418\n at the rim area \n416\n.', 'Securing the liner \n422\n in the expansion portion \n404\n also secures the explosive material \n420\n between the liner \n422\n and the interior surface \n418\n.', 'The liner \n422\n may have a flat rim surface \n423\n substantially parallel to the rim area \n416\n to enhance adhesion.', 'The contact area between the liner \n422\n and the rim area \n416\n can be selected to provide a specified amount of adhesion.', 'One of the expansion portions \n404\n is shown here with a retention feature \n424\n that can be used to secure the liner \n422\n within the expansion portion \n404\n.', 'This retention feature \n424\n is shown to illustrate the idea of using a retention feature instead of, or in addition to, using an adhesive to secure the liner within the expansion portion.', 'Thus, the two expansion portions \n404\n shown in \nFIG.', '4\n are different since one has a retention feature and the other does not.', 'The canister \n400\n can have expansion portions that are different, as shown here, or all expansion portions \n404\n can be the same, with or without retention features.', 'The retention feature \n424\n can be a ledge, tab, or groove that engages with the rim of the liner \n422\n to hold the liner \n422\n within the expansion portion \n404\n.', 'The retention feature \n424\n extends at least partway around the circumference of the rim area \n416\n, and may extend entirely around the circumference of the rim area \n416\n.', 'A combination of protrusions, such as ledges and tabs, with recessions, such as grooves, can be used.', 'In some embodiments, more than one set of retention features can be provided at different depths on the interior surface \n418\n.', 'The liner \n422\n can have a barrier film to minimize unwanted interaction between the liner material and the explosive material.', 'The barrier film is usually applied as a coating to the contact surface of the liner \n422\n.', 'The barrier film may be applied over the entire convex surface of the liner \n422\n, including the rim portion that contacts the interior surface \n418\n of the expansion portion \n404\n, or the barrier film can be applied over only a portion of the convex surface, as appropriate.', 'The barrier film is made of a material that can adhere to the liner surface and is substantially non-reactive or inert with respect to the explosive material.', 'The interior surface \n418\n has a surface preparation that enhances adhesion of the explosive material \n420\n to the interior surface \n418\n.', 'The surface preparation may include, or be, a texture, scoring, abrasion, grooving, adhesive application, or any surface preparation, or combination of surface preparations that can enhance adhesion.', 'To prepare the shaped charge canisters described herein, a blank canister is obtained that has expansion portions with interior surfaces that can be used to contact, and adhere with, an explosive material.', 'The interior surface of each expansion portion to be loaded is prepared by applying a texture or roughness, or an adhesive, or combination thereof to the surface.', 'Texturing can be performed by blasting, for example sand blasting, abrading, scouring, scratching, grooving, or any combination thereof that results in a randomized textured interior surface.', 'Adhesive can be applied to the entire interior surface or to a portion of the interior surface.', 'Generally speaking, the surface preparation is performed in a way that avoids compromising the port at the narrow portion of the expansion portion to avoid reducing or occluding fluid communication to the ignition source.', 'Suitable explosive materials are those commonly used in shaped charges, containing an explosive component and a binder in a paste-like composition that can be shaped using pressure.', 'Alternately, the explosive material, with binder, might have a powder-like consistency, or may be a pellet.', 'A ball, or mass of any shape (such as a pellet), of the explosive material is disposed within the expansion portion or portions to be loaded.', 'The explosive material may be shaped or spread by hand, or using a tool.', 'A liner is then pressed into the explosive material to promote adhesion of the explosive material with the interior surface.', 'As noted herein throughout, the liner has a rim portion that directly contacts the interior surface at a rim area thereof.', 'The rim portion of the liner may be prepared for optimal engagement with the rim area by providing a flat contact area and/or by applying an adhesive.', 'Additionally, or alternately, adhesive may be applied to the rim area of the interior surface where contact with the liner is to be made.', 'When the liner is pressed into the expansion portion containing the explosive material, the explosive material spreads to conform to the volume between the liner and the interior surface.', 'If retention features are used, the liner is pressed into the expansion portion until the retention features engage.', 'If adhesive is used, the liner will be pressed into the expansion portion until the adhesive sets enough to secure the liner in place.', 'It should be noted that where a retention feature is used to secure the liner into the expansion portion, adhesion of the explosive material to the interior surface of the expansion portion is not as important since the liner will hold the explosive material in the volume between the liner and the interior surface.', 'In such cases, little or no adhesion of the explosive material to the interior surface is needed.', 'As described herein, the expansion portions of the canisters can have retention features or can be free of retention features.', 'The shaped charge canisters described herein simply field preparation of perforation tools.', 'Charges are pre-loaded into the canisters so the charges do not need to be installed in the field.', 'Ballistic transfer devices and electrical continuity devices can also be pre-installed so the canister is ready to be connected into a perforation tool upon arrival in the field.', 'The perforation tool is assembled by connecting one or more of the canisters described herein with other tool modules, such as initiators and seal members.', 'Because the canisters are already loaded, time consuming steps of installing charges and connecting electrical and ballistic elements can be skipped.', 'While the foregoing is directed to embodiments of the present invention, other and further embodiments of the present disclosure may be devised without departing from the basic scope thereof, and the scope thereof is determined by the claims that follow.']

['1.', 'A charge canister for a perforation tool, the charge canister comprising:\na cylindrical body having an expansion portion extending along a radius of the cylindrical body, the expansion portion having a randomized textured interior surface, a narrow portion at a first end of the expansion portion, and a wide portion at a second end of the expansion portion opposite from the first end; and\nan explosive material disposed within the expansion portion in direct contact with the randomized textured interior surface of the expansion portion.', '2.', 'The charge canister of claim 1, wherein the wide portion of the expansion portion is free of retention features.', '3.', 'The charge canister of claim 2, further comprising a liner disposed in the expansion portion and covering the explosive material.', '4.', 'The charge canister of claim 3, wherein the liner is secured using an adhesive.', '5.', 'The charge canister of claim 3, wherein the liner is secured by engagement of an edge of the liner with a retention feature of the randomized textured interior surface of the expansion portion.', '6.', 'The charge canister of claim 3, wherein the cylindrical body has a central passage disposed along an axis thereof and the first end of the expansion portion is adjacent to the central passage.', '7.', 'The charge canister of claim 3, wherein the liner has a barrier coating.\n\n\n\n\n\n\n8.', 'The charge canister of claim 1, wherein the randomized textured interior surface is a roughened surface configured to enhance adhesion of the explosive material to the roughened surface.', '9.', 'The charge canister of claim 1, wherein the cylindrical body is a homogeneous, monolithic cylindrical body.', '10.', 'A perforation tool, comprising:\na tubular housing;\nan initiation module disposed within the tubular housing, the initiation module comprising a detonator housing protruding from an end of the initiation module for housing a detonator; and\na charge canister disposed within the tubular housing, the charge canister comprising: a cylindrical body having an expansion portion extending along a radius of the cylindrical body, the expansion portion having a randomized textured interior surface, a narrow portion at a first end of the expansion portion and a wide portion at a second end of the expansion portion opposite from the first end; and an explosive material disposed within the expansion portion in direct contact with the randomized textured interior surface of the expansion portion.\n\n\n\n\n\n\n11.', 'The perforation tool of claim 10, wherein the expansion portion of the charge canister is free of retention features.', '12.', 'The perforation tool of claim 10, further comprising a liner disposed in the expansion portion and covering the explosive material.', '13.', 'The perforation tool of claim 12, wherein the liner is secured using an adhesive.', '14.', 'The perforation tool of claim 12, wherein the liner is secured by engagement of an edge of the liner with a retention feature of the randomized textured interior surface of the expansion portion.', '15.', 'The perforation tool of claim 12, wherein the cylindrical body has an additional central passage disposed along an axis thereof and the first end of the expansion portion is adjacent to the additional central passage.', '16.', 'The perforation tool of claim 12, wherein the liner has a barrier coating.', '17.', 'The perforation tool of claim 10, wherein an adhesive material is used to enhance adhesion of the explosive material to the randomized textured interior surface of the expansion portion, wherein the randomized textured interior surface is a roughened interior surface.', '18.', 'The perforation tool of claim 10, further comprising a bulkhead module disposed within the tubular housing, the bulkhead module comprising a central passage and an electrical conductor disposed within the central passage, wherein the electrical conductor is configured to provide electrical continuity from the charge canister to the bulkhead module, and wherein the charge canister is positioned axially between the initiation module and the bulkhead module.', '19.', 'A method of making a charge canister for a perforation tool, the method comprising:\napplying a randomized surface preparation to an interior surface of an expansion portion of a cylindrical body, wherein the randomized surface preparation comprises texturing the interior surface to provide a randomized textured interior surface prior to disposing an explosive material into the expansion portion;\ndisposing the explosive material into the expansion portion of the cylindrical body, the cylindrical body having the expansion portion extending along a radius of the cylindrical body, the expansion portion having a narrow portion at a first end of the expansion portion and a wide portion at a second end of the expansion portion opposite from the first end, the explosive material in direct contact with the randomized textured interior surface of the expansion portion;\ndisposing a liner against the explosive material within the expansion portion; and\npressing the liner against the explosive material to set the explosive material and the liner into the expansion portion.\n\n\n\n\n\n\n20.', 'The method of claim 19, further comprising securing the liner to the randomized textured interior surface of the expansion portion using an adhesive material.']

['FIG.', '1 is a perspective view of a charge canister according to one embodiment.; FIG.', '2 is a cross-sectional view of the charge canister of FIG.', '1.; FIG. 3 is a cross-sectional view of a perforation tool, according to one embodiment.; FIG.', '4 is a cross-sectional view of a charge canister according to another embodiment.; FIG.', '1 is a perspective view of a charge canister 100 according to one embodiment.', 'The charge canister 100 has a cylindrical body 102 with a central axis 104 and a central passage 106 through the cylindrical body 102 along the central axis 104.', 'The central passage 106 accommodates an electrical conductor 108, which is a cylindrical body that, in this case, contacts an interior wall of the central passage 106 around the entire circumference of the electrical conductor 108.', 'The electrical conductor 108 is tubular, with a central passage of its own to accommodate a booster charge or other ballistic transfer device.', 'The electrical conductor 108 is formed with a “male” end and a “female” end, when installed in the charge canister 100 the male and female ends located at opposite ends of the cylindrical body 102.', 'The male and female ends of the electrical conductor 108 facilitate physical and electrical connection with another similar electrical conductor of another module.', 'When the charge canister 100 is deployed in a perforation tool, the electrical conductor 108 will engage physically and electrically with another electrical conductor of another module, as further described below.', 'The electrical conductor 108 is inserted into the central passage 106 until the female end contacts the cylindrical body 102.', 'In that position, both the male and female ends of the electrical conductor 108 may protrude from opposite ends of the cylindrical body 102.', 'The electrical conductor 108 can be secured within the central passage 106 by using a fastening feature, such as a snap ring or other device, at the male end of the electrical conductor 108.; FIG.', '2 is a cross-sectional view of the charge canister 100.', 'As described above, an explosive material 202 is disposed in the expansion portion 110 in direct physical contact with an interior surface thereof.', 'The explosive material 202 is pressed between the liner 112 and the interior surface of the expansion portion 110.', 'The liner 112 and the interior surface of the expansion portion 110 are shaped to mold the explosive material 202 into a desired shape for projecting an optimized jet of material outward from the expansion portion 110 into a subterranean formation.', 'The liner 112 is also in direct physical contact with the interior surface of the expansion portion 110 to hold the explosive material 202 securely by adhering to the interior surface.', 'As noted above, a retention feature can also be provided to secure the liner 112.; FIG.', '3 is a cross-sectional view of a perforation tool 300 according to one embodiment.', 'The perforation tool 300 has a housing 302 that contains an initiation module 304, a bulkhead module 306, and one or more of the charge canisters 100.', 'Two canisters 100 are shown in the perforation tool 300, but any number can be installed in a housing 302.', 'The housing 302 has grooves 308 formed in an external surface of the housing.', 'The grooves 308 are formed, in this case, around the entire circumference of the housing 302.', 'The grooves 308 provide a thin wall section to promote penetration of the perforation jet through the housing 302 upon activation of the charges.', 'The housing 302 may have positioning features, such as ridges or tabs protruding radially inward from the inner wall of the housing 302, to aid in positioning the charge canisters 100 with the expansion portions 110 adjacent to the grooves 308.; FIG.', '4 is a cross-sectional view of a shaped charge canister 400 according to another embodiment.', 'The canister 400 uses large shaped charges that extend across the canister 400 from side to side, with no central passage.', 'The shaped charge canister 400 is also modular, comprising a plurality of frames 402 that hold shaped charges, each frame 402 holding one charge.', 'Two frames 402 are shown here, but the canister 400 could have one frame 402, three frames 402, or more, in concept without limit.', 'Each frame 402 has an expansion portion 404 that holds a shaped charge 405.', 'The shaped charge canister 400 is a generally cylindrical body, and each frame 402 has a generally cylindrical profile.', 'The canister 400 has a central axis 406 that is an axis of the cylindrical shape of the canister 400.']

US11898095

Crosslinking of cellulose fibers

Aug 8, 2022

Giselle Refunjol, Jazmin Godoy-Vargas, Mohan Kanaka Raju Panga

SCHLUMBERGER TECHNOLOGY CORPORATION

Siqueira et al., Carboxymethylcellulose (CMC) as a model compound of cellulose fibers and polyamideamine epichlorohydr in (PAE)-CMC interactions as a model of PAE-fibers interactions of PAE-based wet strength papers, Journal of Applied Polymer Science, 2015, vol. 132, Article No. 42144, 10 pages.; International Search Report and Written Opinion issued in International Patent Appl. No. PCT/US2017/056340 dated Apr. 27, 2018; 12 pages.; Examination report issued in Australian Patent Application No. 2017342365 dated Jun. 25, 2021, 3 pages.; Examination report issued in Saudi Arabian patent application 519401523 dated Jan. 25, 2022, with English Summary, 10 pages.; Examination report issued in Australian Patent Application No. 2017342365 dated Mar. 15, 2022, 2 pages.

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Foreign Citations not found.

['Methods of treating a subterranean formation include forming a treatment fluid including a hydrophilic fiber coated with a water soluble polymer and a crosslinking agent.']

['Description\n\n\n\n\n\n\nThe present application is a continuation of U.S. patent application Ser.', 'No. 16/340,528, now U.S. Pat.', 'No. 11,407,931, filed Apr. 9, 2019, which is a National Stage Entry of International Patent Application Serial No. PCT/US2017/056340, filed Oct. 12, 2017, which claims priority to U.S. Provisional Application Ser.', 'No. 62/407,213 filed Oct. 12, 2016, each of which is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nHydrocarbons (e.g., oil, natural gas, etc.) may be obtained from a subterranean formation by drilling a wellbore that penetrates the hydrocarbon-bearing formation.', 'Fracturing operations may be conducted in a wellbore to improve the production of fluids from the formation surrounding the wellbore.', 'A variety of fracturing techniques can be employed, and available systems enable multi-stage stimulation to be performed along the wellbore.', 'Hydraulic fracturing techniques generally involve pumping a fracturing fluid downhole and into the surrounding formation upon its fracture due to the high pressures involved.', 'More specifically, hydraulic fracturing techniques inject a fracturing fluid into a wellbore penetrating a subterranean formation thereby forcing the fracturing fluid against the wellbore walls at pressures high enough to crack or fracture the formation, creating or enlarging one or more fractures.', 'Proppant present in the fracturing fluid is then entrained within the fracture by the ingress of the fracturing fluid into the created or enlarged crack, thereby preventing the fracture from closing and thus providing for the improved flow produced fluids from the formation.', 'Proppant is thus used to hold the walls of the fractures apart in order to create conductive paths that can facilitate the flow of fluids through the formation and into the wellbore after pumping has stopped.', 'Being able to place the appropriate proppant at the appropriate concentration to form a suitable proppant pack is thus important for the success of a hydraulic fracturing operation.', 'Fibers are incorporated in different oilfield products for various applications.', 'Fibers are used in the fracturing fluids as proppant suspending agents to enable proppant transport down the wellbore and into the fracture by reduction of proppant settling.', 'Additionally, fibers are used in cement fluids to enhance flexural strength of set cement, avoiding failure due to shear and compressional stresses.', 'Another example of fibers in the oilfield is their use in diversion fluids, as well as loss circulation materials due to their ability to bridge in small openings.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'The present application is directed to a method of crosslinking or binding hydrophilic fibers in a well treatment fluid to form hydrophilic fiber networks.', 'This mechanism may have various applications in oilfield operations with enhancements in aqueous fluids such as higher fluid viscosity, assistance with proppant transport, and aid in fluid diversion.', 'Other aspects and advantages of the claimed subject matter will be apparent from the following description and the appended claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIGS.', '1\nA and \n1\nB\n are microscope images of cellulose fibers with surface attached carboxymethylcellulose according to one embodiment.', 'FIGS.', '2\nA and \n2\nB\n are microscope images of the cellulose fibers of \nFIGS.', '1\nA and \n1\nB\n cross-linked using tetraethylenepentamine according to another embodiment.\n \nFIGS.', '3\nA and \n3\nB\n are microscope images of cellulose fibers with surface attached CMC suspended in water with added chitosan according to one embodiment.', 'FIGS.', '4\nA and \n4\nB\n are microscope images of the re-dispersed cellulose fibers with surface attached polyacrylamide.', 'FIGS.', '5\nA and \n5\nB\n are microscope images of cellulose fibers with surface added polyacrylamide dispersed in water and cross-linked using zirconium dioxide.', 'DETAILED DESCRIPTION\n \nEmbodiments disclosed herein relate generally to well treatment compositions and methods of using said compositions during well treatment operations.', 'More specifically, embodiments disclosed herein relate to a well treatment compositions that include crosslinking hydrophilic fibers.', "At the outset, it should be noted that in the development of any such actual embodiment, numerous implementation-specific decisions may be made to achieve the developer's specific goals, such as compliance with system related and business related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort might be complex and time consuming but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'In addition, the composition used/disclosed herein can also comprise some components other than those cited.', 'In the summary and this detailed description, each numerical value should be read once as modified by the term “about” (unless already expressly so modified), and then read again as not so modified unless otherwise indicated in context.', 'The term about should be understood as any amount or range within 10% of the recited amount or range (for example, a range from about 1 to about 10 encompasses a range from 0.9 to 11).', 'Also, in the summary and this detailed description, it should be understood that a range listed or described as being useful, suitable, or the like, is intended to include support for any conceivable sub-range within the range at least because every point within the range, including the end points, is to be considered as having been stated.', 'For example, “a range of from 1 to 10” is to be read as indicating each possible number along the continuum between about 1 and about 10.', 'Furthermore, one or more of the data points in the present examples may be combined together, or may be combined with one of the data points in the specification to create a range, and thus include each possible value or number within this range.', 'Thus, (1) even if numerous specific data points within the range are explicitly identified, (2) even if reference is made to a few specific data points within the range, or (3) even when no data points within the range are explicitly identified, it is to be understood (i) that the inventors appreciate and understand that any conceivable data point within the range is to be considered to have been specified, and (ii) that the inventors possessed knowledge of the entire range, each conceivable sub-range within the range, and each conceivable point within the range.', 'Furthermore, the subject matter of this application illustratively disclosed herein suitably may be practiced in the absence of any element(s) that are not specifically disclosed herein.', 'Fibers are well known to be used for various purposes in oilfield treatment operations.', 'For example, methods such as fiber assisted transport have been used to improve particle transport in fracturing and wellbore cleanout operations while reducing the amount of other fluid viscosifiers employed.', 'Disclosed herein is a method of treating a subterranean formation, the method comprising: forming a treatment fluid comprising: at least one a hydrophilic fiber coated with at least one water soluble polymer, and at least one crosslinking agent, and placing the treatment fluid in the subterranean formation.', 'For instance, the technology described herein may provide numerous benefits to well treatment fluids.', 'More specifically, such a mechanism can increase viscosity of the treatment fluid simply by the formation of the fiber network resulting in an increase in fluid viscosity and thereby enhancing proppant transport without the need for additional polymers or viscosifiers.', 'Furthermore, in sand control applications, the formation of a fiber network can assist with proppant flow back control, while in heterogeneous fluid placement techniques, such fiber networks can aid in forming stronger proppant-fiber pillars.', 'Furthermore, in diversion applications, the formation of fiber networks can be used as a bridging mechanism of fractures within the subterranean formation.', 'The term “treatment,” or “treating,” does not imply any particular action by the fluid.', 'For example, a treatment fluid placed or introduced into a subterranean formation subsequent to a leading-edge fluid may be a hydraulic fracturing fluid, an acidizing fluid (acid fracturing, acid diverting fluid), a stimulation fluid, a sand control fluid, a completion fluid, a wellbore consolidation fluid, a remediation treatment fluid, a cementing fluid, a driller fluid, a frac-packing fluid, or gravel packing fluid\n \nConventionally, synthetic fibers may be used to assist in the formation of the proppant pillars.', 'However, current manufacturing methods for synthetic fibers have limits to the shortest length achievable for the fibers.', 'However, in order for fibers to be effective within a fracture they must be able to enter the fracture and in some instances the fracture width may be less than the shortest length achievable for synthetic fibers, which makes it difficult for even the smallest synthetic fibers to penetrate into the fracture.', 'For example, a fracture width may decrease the further a fracture extends into a formation.', 'Formations that have fractures with widths smaller than the fiber lengths can present problems for proppant placement within said fractures because the fibers that are attempted to be injected therein tend to be screened out and otherwise accumulate at the mouth or openings of the smaller fracture.', 'Therefore, materials that enable efficient proppant transport into fractures, both large and small, are sought after to improve the efficiency of hydraulic fracturing operations.', 'The term “fracturing” refers to the process and methods of breaking down a geological formation and creating a fracture, such as the rock formation around a wellbore, by pumping fluid at very high pressures (pressure above the determined closure pressure of the formation), in order to increase production rates from or injection rates into a hydrocarbon reservoir.', 'The fracturing methods of the present disclosure may include a composition one or more polymers that may be consolidated to form a polymeric structure upon exposure to a predetermined shear rate in one or more of the treatment fluids, but otherwise use conventional techniques known in the art.', 'The term “field” includes land-based (surface and sub-surface) and sub-seabed applications.', 'The term “oilfield,” as used herein, includes hydrocarbon oil and gas reservoirs, and formations or portions of formations where hydrocarbon oil and gas are expected but may additionally contain other materials such as water, brine, or some other composition.', 'As used herein, the term “polymer” or “oligomer” is used interchangeably unless otherwise specified, and both refer to homopolymers, copolymers, interpolymers, terpolymers, and the like.', 'Likewise, a copolymer may refer to a polymer comprising only two monomers, or comprising at least two monomers, optionally with other additional monomers.', 'When a polymer is referred to as comprising a monomer, the monomer is present in the polymer in the polymerized form of the monomer or in the derivative form of the monomer.', 'However, for ease of reference the phrase comprising the (respective) monomer or the like is used as shorthand.', 'Hydrophilic Fiber', 'In one or more embodiments, disclosed herein is a well treatment fluid composition that includes a hydrophilic fiber coated with a water soluble polymer.', 'For example, the coated hydrophilic fiber may be a cellulose based fiber such as pulp fiber or microfibrillated cellulose.', 'Cellulose itself constitutes the most abundant renewable and environmentally friendly raw material available on earth.', 'For example, raw materials including wood, recycled paper, and agricultural residues such as bagasse, cereal straw, bamboo, reeds, esparto grass, jute, flax, and sisal all are comprised of cellulose fibers that may be converted into a variety of product including pulp fiber.', 'Depending on the particular application requirements, the raw material processing conditions may be altered to produce a variety of cellulose-based materials that vary in terms of dimension and shape.', 'For example, pulp fibers may generally range from 1 micron to 10 millimeters in length, powdered cellulose may generally range from 1 micron to 1 millimeter, nanofibrillated cellulose may generally range from 100 nanometers to 1 micron, microfibrillated cellulose may generally range from 100 nanometers to 500 microns, and nanocrystalline cellulose may generally range from 50 nanometers to 1000 nanometers.', 'The above length distributions, and any other dimensional details that follow, are all based off of the values for dry fibers.', 'It is to be understood that the hydrophilic fibers of the present disclosure, upon their hydration from a dried state, may elongate and/or swell.', 'The worldwide annual output of pulp fiber is about 400 million tons, making pulp fiber one of the most abundant raw materials worldwide.', 'Pulp production begins with raw material preparation, which may include debarking (for wood), chipping, depithing (for bagasse), among others.', 'After the raw material preparation the lignin is stripped from the cellulosic fibers by mechanical, thermal, and/or chemical processes.', 'Lignin is a three dimensional polymer that binds the cellulosic fibers together and with its removal from the raw material the cellulosic fibers are freed to act independently or for further processing (e.g., into paper, craft board, etc.).', "Importantly, pulp is a hydrophilic material that is highly flexible (i.e., has a low Young's modulus) and is available in a variety of fiber lengths and diameters.", 'However, other hydrophilic fiber materials having the dimensions and material properties that allow their use in a wide range of fracture widths may be used in one or more embodiments.', 'In one or more embodiments, the hydrophilic fiber used may have a length with a lower limit of any of 50 microns, 100 microns, 200 microns, 250 microns, 325 microns, 400 microns, or 500 microns, with an upper limit of any of 1.5 millimeters, 2 millimeters, 3 millimeters, 5 millimeters, 6 millimeters, 8 millimeters, or 10 millimeters, where any lower limit can be used in combination with any upper limit.', 'In one or more embodiments, a hydrophilic fiber sample may be further fractionated to achieve a more narrow length distribution within the ranges listed above.', 'In one or more embodiments, the width (e.g., dimension opposite the length) of the hydrophilic fibers may be from about 10 microns to 50 microns, or from about 15 microns to 45 microns, or from about 20 microns to 40 microns.', 'In one or more embodiments, the aspect ratio (length to width) of the hydrophilic fibers used in fracturing fluids of the present disclosure may be from about 5 to 1000, or from about 6.5 to 700, or from about 8 to 500, or from about 10 to 300.', 'The hydrophilic fibers of the present disclosure are more elastic and/or flexible than a comparably sized synthetic fiber.', 'Without being bound by theory, the increased elasticity and/or flexibility of the hydrophilic fiber is believed to reduce the amount of bridging that occurs at the mouth/opening of fractures smaller than the hydrophilic fibers attempting to penetrate therein, thereby reducing the screening out of the hydrophilic fibers and facilitating their penetration into smaller fractures.', 'In one or more embodiments, the amount of hydrophilic fibers used in a fracturing fluid may be from about from about 0.012 to about 1.2 wt %, from about 0.06 wt % to about 0.9 wt %, from about 0.12 wt % to about 0.6 wt %, from about 0.18 wt % to about 0.48 wt % and from about 0.24 wt % to about 0.36 wt %.', 'The amount used may depend on the width of the fractures that are to be penetrated by the fracturing fluid.', 'For example, in some embodiments the amount of hydrophilic fibers needed to effectively transport and place proppant within smaller width fractures may be less than that which is needed in larger width fractures due to the proppant size for smaller fractures being correspondingly smaller and the volume of smaller fractures being smaller.', 'In one or more embodiments, combinations of fibers (e.g., synthetic and hydrophilic and/or different types of hydrophilic fibers) may be used.', 'For example, simply using one type or size of fiber for all fracture geometries may not achieve an optimized proppant transport and placement profile.', 'For example, there is commonly a fracture width gradient within a formation, with the fracture width tending to be smaller the farther the fracture is from the wellbore.', 'In these instances, some fibers may be too big to penetrate the smaller fractures and therefore cause bridging and/or plugging at the fracture opening/mouth.', 'Conversely, some fibers may be too small to be able to anchor properly within larger fractures and suspend proppant therein.', 'Water Soluble Polymer\n \nAs discussed above, the hydrophilic fiber may be coated with a water soluble polymer, such as, for example, a polysaccharide, a polyelectrolyte or combinations thereof.', 'Specific examples of polysaccharides include substituted galactomannans, such as guar gums, high-molecular weight polysaccharides composed of mannose and galactose sugars, or guar derivatives such as hydroxypropyl guar (HPG), carboxymethylhydroxypropyl guar (CMHPG) and carboxymethyl guar (CMG), hydrophobically modified guars, guar-containing compounds, cellulose derivatives such as hydroxyethylcellulose (HEC) or hydroxypropylcellulose (HPC), carboxymethylhydroxyethylcellulose (CMHEC) and carboxymethylcellulose (CMC), and synthetic polymers.', 'Specific examples of polyelectrolytes include polyacrylamides, partially hydrolyzed polyacrylamides, partially hydrolyzed polymethacrylamide, sodium alginate, chitosan.', 'Specific examples of polyelectrolyte polymers are described in U.S. Patent Application Pub.', 'Nos. 2013/0056213 and 2013/0048283, the disclosures of which are incorporated by reference herein in their entirety.', 'Additional examples of water soluble polymer include acrylic acid-acrylamide copolymers, acrylic acid-methacrylamide copolymers, polyvinyl polymers, cellulose ethers, lignosulfonates, and their ammonium, alkali metal, and alkaline earth salts thereof, polyalkyleneoxides, other galactomannans, heteropolysaccharides obtained by the fermentation of starch-derived sugar and their ammonium and alkali metal salts thereof.', 'Suitable examples of biopolymers include gellan, κ-carrageenan, gelatin, agar, agarose, maltodextrin, and combinations thereof.', 'The treatment composition may include any combination of the specific water soluble polymers described above.', 'Additional examples of biopolymers are described in U.S. Pat.', 'Nos. 5,726,138 and 7,169,427, and U.S. Patent Application Pub.', 'No. 2005/0042192, the disclosure of each of which is incorporated by reference herein in its entirety.', 'The water soluble polymer may be present in an amount of from about 0.6 mg per gram of the hydrophilic fiber added to 120 mg per gram of the hydrophilic fiber added, from about 3 mg per gram of the hydrophilic fiber added to 60 mg per gram of the hydrophilic fiber added, from about 6 mg per gram of the hydrophilic fiber added to 48 mg per gram of the hydrophilic fiber added, from about 9 mg per gram of the hydrophilic fiber added to 30 mg per gram of the hydrophilic fiber added, from about 12 mg per gram of the hydrophilic fiber added to 30 mg per gram of the hydrophilic fiber added and from about 18 mg per gram of the hydrophilic fiber added to 24 mg per gram of the hydrophilic fiber added.', 'As used herein, the term “coating” merely requires that the water soluble polymer contact the surface and/or adsorb onto the surface of the hydrophilic fiber, resulting in the formation of bonding sites for the hydrophilic fiber.', 'Adsorption of a water soluble polymer is primarily due to similarities between cellulosic backbones and similar chemical nature that induces efficient hydrogen bonds between the polymer and the cellulose surface.', 'Additionally, for cationic polymers the positive charge provides affinity to a slightly negative cellulose fiber surface.', 'In order to efficiently adsorption of a polymer to the fiber surface, the polymer needs to be water soluble, have enough molecular weight to remain on the outer wall of the fiber (about 100,000 g/mol), and have the ability to form hydrogen bonds.', 'The hydrophilic fiber may also be coated with a resin, such as polyamideamine-epichlorohydrin (PAE) resin that may cross-link with the cellulose carboxylate groups or can self-cross-link.', 'Other resins may include formaldehyde resins, epoxide resins, and aldehyde resins.', 'Crosslinking Agent', 'In embodiments, the treatment fluid may comprise one or more cross-linking agents.', 'The phrase “cross-linking agent” refers, for example, to a compound or mixture that assists in the formation of a three-dimensional polymerized structure of the one or more coated hydrophilic fibers.', 'Any crosslinker may be used, for example, organic crosslinkers, inorganic crosslinkers, divalent metals, trivalent metals, and polyvalent metals, such as calcium, iron, chromium, copper, boron, titanium, zirconium, aluminum and the like.', 'Suitable boron crosslinked polymers systems include guar and substituted guars crosslinked with boric acid, sodium tetraborate, and encapsulated borates; borate crosslinkers may be used with buffers and pH control agents such as sodium hydroxide, magnesium oxide, sodium sesquicarbonate, and sodium carbonate, amines (such as hydroxyalkyl amines, anilines, pyridines, pyrimidines, quinolines, and pyrrolidines, and carboxylates such as acetates and oxalates) and with delay agents such as sorbitol, aldehydes, and sodium gluconate.', 'Suitable zirconium crosslinked polymer systems include those crosslinked by zirconium lactates (for example sodium zirconium lactate), triethanolamines, 2,2′-iminodiethanol, and with mixtures of these ligands, including when adjusted with bicarbonate.', 'Suitable titanates include lactates and triethanolamines, and mixtures, for example delayed with hydroxyacetic acid.', 'The concentration of the crosslinker in the treatment fluid may be from about 0.001 wt. % to about 10 wt.', '%, such as about 0.005 wt.', '% to about 2 wt.', '%, or about 0.01 wt.', '% to about 1 wt.', '%.', 'In some embodiments, the treatment fluid in which the crosslinking is triggered may have any suitable viscosity, such as a viscosity of from about 1 cP to about 1,000 cP (or from about 10 cP to about 100 cP) at the treating temperature, which may range from a surface temperature to a bottom-hole static (reservoir) temperature, such as from about −40° C. to about 150° C., or from about 10° C. to about 120° C., or from about 25° C. to about 100° C.,\n \nSuch hydrophilic fiber network structures may form in the treatment fluid anywhere within, or inside of the surface mixing equipment, such as a POD blender, or between the surface mixing equipment and the downhole formation to be treated.', 'In some embodiments, the shear rate applied to this polymer solution may be adjusted as desired to form a predetermined size of polymeric structures in the treatment fluid.', 'The hydrophilic fiber network may be formed by the agglomeration and/or consolidation of the coated hydrophilic fibers such that at least two of the hydrophilic fibers are connected together.', 'As used herein, the phrases “crosslinkable fluid,” “treatment fluid” or “fluid for treatment” (hereinafter generally referred to as a “crosslinkable fluid” unless specified otherwise) mean, for example, a composition comprising a solvent, a crosslinkable material, which includes any crosslinkable compound and/or substance with a crosslinkable moiety, (hereinafter “crosslinkable component”) that may be substantially inert to any produced fluids (gases and liquids) and other fluids injected into the wellbore or around the wellbore, such as workover fluids, and a crosslinking composition which comprises a crosslinker, for example, to seal at least a portion of the area into which the crosslinkable fluid is pumped.', 'The crosslinkable fluid of the present disclosure may be a solution initially having a very low viscosity that can be readily pumped or otherwise handled.', 'For example, the viscosity of the crosslinkable fluid may be from about 1 cP to about 10,000 cP, or be from about 1 cP to about 1,000 cP, or be from about 1 cP to about 100 cP at the treating temperature, which may range from a surface temperature to a bottom-hole static (reservoir) temperature, such as from about 4° C. to about 80° C., or from about 10° C. to about 70° C., or from about 25° C. to about 60° C., or from about 32° C. to about 55° C.\n \nCrosslinking the crosslinkable fluid of the present disclosure generally increases its viscosity.', 'As such, having the composition in the uncrosslinked/unviscosified state allows for pumping of a relatively less viscous fluid having relatively low friction pressures within the well tubing, and the crosslinking may be delayed in a controllable manner such that the properties of thickened crosslinked fluid are available at the rock face instead of within the wellbore.', 'Such a transition to a crosslinked/uncrosslinked state may be achieved over a period of minutes or hours based on the particular molecular make-up of the crosslinker, and results in the initial viscosity of the crosslinkable fluid increasing by at least an order of magnitude, such as at least two orders of magnitude.', 'Suitable solvents for use with the crosslinkable fluid in the present disclosure may be aqueous or organic based.', 'Aqueous solvents may include at least one of fresh water, sea water, brine, mixtures of water and water-soluble organic compounds and mixtures thereof.', 'Organic solvents may include any organic solvent with is able to dissolve or suspend the various components of the crosslinkable fluid.', 'In some embodiments, the crosslinkable fluid may initially have a viscosity similar to that of the aqueous solvent, such as water.', 'An initial water-like viscosity may allow the solution to effectively penetrate voids, small pores, and crevices, such as encountered in fine sands, coarse silts, and other formations.', 'In other embodiments, the viscosity may be varied to obtain a desired degree of flow sufficient for decreasing the flow of water through or increasing the load-bearing capacity of a formation.', 'The rate at which the viscosity of the crosslinkable fluid changes may be varied by the choice of the crosslinker and polymer employed in the crosslinkable fluid.', 'The viscosity of the crosslinkable fluid may also be varied by increasing or decreasing the amount of solvent relative to other components, or by other techniques, such as by employing viscosifying agents.', 'In embodiments, the solvent, such as an aqueous solvent, may represent up to about 99.9 weight percent of the crosslinkable fluid, such as in the range of from about 85 to about 99.9 weight percent of the crosslinkable fluid, or from about 98 to about 99.7 weight percent of the crosslinkable fluid.', 'The crosslinkable fluids or compositions suitable for use in the methods of the present disclosure comprise a crosslinkable component.', 'As discussed above, a “crosslinkable component,” as the term is used herein, is a compound and/or substance that comprises a crosslinkable moiety.', 'For example, the crosslinkable components may contain one or more crosslinkable moieties, such as a carboxylate and/or a cis-hydroxyl (vicinal hydroxyl)', 'moiety that is able to coordinate with the reactive sites of the crosslinker.', 'The reactive sites of the crosslinker may be, for example, the site where the metals (such as Al, Zr and Ti and/or other Group IV metals) are present.', 'The crosslinkable component may be natural or synthetic polymers (or derivatives thereof) that comprise a crosslinkable moiety, for example, substituted galactomannans, guar gums, high-molecular weight polysaccharides composed of mannose and galactose sugars, or guar derivatives, such as hydrophobically modified guars, guar-containing compounds, and synthetic polymers.', 'Suitable crosslinkable components may comprise a guar gum, a locust bean gum, a tara gum, a honey locust gum, a tamarind gum, a karaya gum, an arabic gum, a ghatti gum, a tragacanth gum, a carrageenen, a succinoglycan, a xanthan, a diutan, a hydroxylethylguar hydroxypropyl guar, a carboxymethylhydroxyethyl guar, a carboxymethylhydroxypropylguar, an alkylcarboxyalkyl cellulose, an alkyl cellulose, an alkylhydroxyalkyl cellulose, a carboxyalkyl cellulose ether, a hydroxyethylcellulose, a carboxymethylhydroxyethyl cellulose, a carboxymethyl starch, a copolymer of 2-acrylamido-2methyl-propane sulfonic acid and acrylamide, a terpolymer of 2-acrylamido-2methyl-propane sulfonic acid, acrylic acid, acrylamide, or derivative thereof.', 'In embodiments, the crosslinkable components may present at about 0.01% to about 4.0% by weight based on the total weight of the crosslinkable fluid, such as at about 0.10% to about 2.0% by weight based on the total weight of the crosslinkable fluid.', 'Additional examples of crosslinking agents include, but are not limited to, one or more multifunctional crosslinking agents such as: dihaloalkanes, haloalkyloxiranes, alkyloxirane sulfonates, di(haloalkyl)amines, tri(haloalkyl)amines, diepoxides, triepoxides, tetraepoxides, bis(halomethyl) benzenes, tri(halomethyl) benzenes, tetra(halomethyl) benzenes, epihalohydrins such as epichlorohydrin and epibromohydrin, poly(epichlorohydrin), (iodomethyl)oxirane, bromo-1,2-epoxybutane, 1,2-dibromoethane, 1,3-dichloropropane, 1,2-dichloroethane, 1-bromo-2-chloroethane, 1,3-dibromopropane, bis(2-chloroethyl)amine, tris(2-chloroethyl)amine, and bis(2-chloroethyl)methylamine, 1,3-butadiene diepoxide, 1,5-hexadiene diepoxide, methyl acrylate, a metal, a metal salt, glutaraldehyde, glyoxal, a zinc-based compound, a zirconium-based compound, and the like.', 'Furthermore, the treatment fluid may further comprise an amine crosslinking agent such as, for example, tetraethylenepentamine, 2,2′-(Ethylenedioxy)bis(ethylamine), (2-Aminoethoxy)ethylamine, 2,2′-Oxydiethylamine dihydrochloride, 1,11-Diamino-3,6,9-trioxaundecane, and 4,7,10-Trioxa-1,13-tridecanediamine.', 'If so, hydrophilic material may require pretreatment with a carbodiimide, such as N-(3-Dimethylaminopropyl)-N′-ethylcarbodiimide hydrochloride (EDC), to react with the surface of the hydrophilic fiber (e.g., CMC) to form a ester bond that may react in due course with an amine.', 'Additional examples of carbodiimides include N-(3-Dimethylaminopropyl)-N-ethylcarbodiimide hydrochloride (EDAC), 1-[3-(Dimethylamino)propyl]-3-ethylcarbodiimide methiodide (EDC methiodide), N-Cyclohexyl-N′-(2-morpholinoethyl)carbodiimide metho-p-toluenesulfonate (CME-CDI).', 'The well treatment composition may further include a salt, such as, for example, potassium chloride, calcium chloride, sodium chloride and mixtures thereof.', 'The salt may be present in an amount of from about 0.1 wt % to about 5 wt %, such as, for example, from about 0.5 wt % to about 3 wt %, from about 0.5 wt % to about 2 wt % and from about 1 wt.', '% to about 2 wt %.', 'If present, the salt may further reduce the amount of the water soluble polymer in the well treatment composition.', 'As discussed above, the treatment fluid carrying the one or more polymers may be any well treatment fluid, such as a fluid loss control pill, a water control treatment fluid, a scale inhibition treatment fluid, a fracturing fluid, a gravel packing fluid, a drilling fluid, and a drill-in fluid.', 'The carrier solvent for the treatment fluid may be a pure solvent or a mixture.', 'Suitable solvents for use with the methods of the present disclosure, such as for forming the treatment fluids disclosed herein, may be aqueous or organic based.', 'Aqueous solvents may include at least one of fresh water, sea water, brine, mixtures of water and water-soluble organic compounds and mixtures thereof.', 'Organic solvents may include any organic solvent that is able to dissolve or suspend the various components, such as the chemical entities and/or components of the treatment fluid.', 'While the treatment fluids of the present disclosure are described herein as comprising the above-mentioned components, it should be understood that the fluids of the present disclosure may optionally comprise other chemically different materials.', 'In embodiments, the fluid may further comprise stabilizing agents, surfactants, diverting agents, or other additives.', 'Additionally, the treatment fluid may comprise a mixture various other crosslinking agents, and/or other additives, such as fibers or fillers, provided that the other components chosen for the mixture are compatible with the intended use of forming a polymeric structure.', 'In embodiments, the treatment fluid of the present disclosure may further comprise one or more components such as, for example, a gel breaker, a buffer, a proppant, a clay stabilizer, a gel stabilizer, a chelating agent, an oxygen scavenger and a bactericide.', 'Furthermore, the treatment fluid or treatment fluid may include buffers, pH control agents, and various other additives added to promote the stability or the functionality of the fluid.', 'The treatment fluid or treatment fluid may be based on an aqueous or non-aqueous solution.', 'The components of the treatment fluid or treatment fluid may be selected such that they may or may not react with the subterranean formation that is to be treated.', 'In this regard, the treatment fluid may include components independently selected from any solids, liquids, gases, and combinations thereof, such as slurries, gas-saturated or non-gas-saturated liquids, mixtures of two or more miscible or immiscible liquids, and the like, as long as such additional components allow for the formation of a polymeric structure.', 'For example, the fluid or treatment fluid may comprise organic chemicals, inorganic chemicals, and any combinations thereof.', 'Organic chemicals may be monomeric, oligomeric, polymeric, crosslinked, and combinations, while polymers may be thermoplastic, thermosetting, moisture setting, elastomeric, and the like.', 'Inorganic chemicals may be metals, alkaline and alkaline earth chemicals, minerals, and the like.', 'Fibrous materials may also be included in the fluid or treatment fluid.', 'Suitable fibrous materials may be woven or nonwoven, and may be comprised of organic fibers, inorganic fibers, mixtures thereof and combinations thereof.', 'Surfactants can be added to promote dispersion or emulsification of components of the fluid, or to provide foaming of the crosslinked component upon its formation downhole.', 'Suitable surfactants include alkyl polyethylene oxide sulfates, alkyl alkylolamine sulfates, modified ether alcohol sulfate sodium salts, or sodium lauryl sulfate, among others.', 'Any surfactant which aids the dispersion and/or stabilization of a gas component in the fluid to form an energized fluid can be used.', 'Viscoelastic surfactants, such as those described in U.S. Pat.', 'Nos. 6,703,352, 6,239,183, 6,506,710, 7,303,018 and 6,482,866, each of which are incorporated by reference herein in their entirety, are also suitable for use in fluids in some embodiments.', 'Examples of suitable surfactants also include, but are not limited to, amphoteric surfactants or zwitterionic surfactants.', 'Alkyl betaines, alkyl amido betaines, alkyl imidazolines, alkyl amine oxides and alkyl quaternary ammonium carboxylates are some examples of zwitterionic surfactants.', 'An example of a useful surfactant is the amphoteric alkyl amine contained in the surfactant solution AQUAT 944 (available from Baker Petrolite of Sugar Land, Tex.).', 'A surfactant may be added to the fluid in an amount in the range of about 0.01 wt.', '% to about 10 wt.', '%, such as about 0.1 wt.', '% to about 2 wt.', '% based upon total weight of the treatment fluid.', 'Charge screening surfactants may be employed.', 'In some embodiments, the anionic surfactants such as alkyl carboxylates, alkyl ether carboxylates, alkyl sulfates, alkyl ether sulfates, alkyl sulfonates, α-olefin sulfonates, alkyl ether sulfates, alkyl phosphates and alkyl ether phosphates may be used.', 'Anionic surfactants have a negatively charged moiety and a hydrophobic or aliphatic tail, and can be used to charge screen cationic polymers.', 'Examples of suitable ionic surfactants also include, but are not limited to, cationic surfactants such as alkyl amines, alkyl diamines, alkyl ether amines, alkyl quaternary ammonium, dialkyl quaternary ammonium and ester quaternary ammonium compounds.', 'Cationic surfactants have a positively charged moiety and a hydrophobic or aliphatic tail, and can be used to charge screen anionic polymers such as CMHPG.', 'In the same manner, a charged surfactant can also be employed to form polymer-surfactant complexes as a method for generating consolidated structures.', 'In other embodiments, the surfactant is a blend of two or more of the surfactants described above, or a blend of any of the surfactant or surfactants described above with one or more nonionic surfactants.', 'Examples of suitable nonionic surfactants include, but are not limited to, alkyl alcohol ethoxylates, alkyl phenol ethoxylates, alkyl acid ethoxylates, alkyl amine ethoxylates, sorbitan alkanoates and ethoxylated sorbitan alkanoates.', 'Any effective amount of surfactant or blend of surfactants may be used in aqueous energized fluids.', 'Friction reducers may also be incorporated in any fluid embodiment.', 'Any suitable friction reducer polymer, such as polyacrylamide and copolymers, partially hydrolyzed polyacrylamide, poly(2-acrylamido-2-methyl-1-propane sulfonic acid) (polyAMPS), and polyethylene oxide may be used.', 'Commercial drag reducing chemicals such as those sold by Conoco Inc. under the trademark “CDR” as described in U.S. Pat.', 'No. 3,692,676 or drag reducers such as those sold by Chemlink designated under the trademarks FLO1003, FLO1004, FLO1005 and FLO1008 have also been found to be effective.', 'These polymeric species added as friction reducers or viscosity index improvers may also act as excellent fluid loss additives reducing or even eliminating the use of conventional fluid loss additives.', 'Latex resins or polymer emulsions may be incorporated as fluid loss additives.', 'Shear recovery agents may also be used in embodiments.', 'The above friction reducers, such as polyacrylamide, may also be crosslinking agents.', 'Embodiments may also include proppant particles that are substantially insoluble in the fluids of the formation.', 'Proppant particles carried by the treatment fluid remain in the fracture created, thus propping open the fracture when the fracturing pressure is released and the well is put into production.', 'Suitable proppant materials include, but are not limited to, sand, walnut shells, sintered bauxite, glass beads, ceramic materials, naturally occurring materials, or similar materials.', 'Mixtures of proppants can be used as well.', 'If sand is used, it may be from about 20 to about 100 U.S. Standard Mesh in size.', 'With synthetic proppants, mesh sizes about 8 or greater may be used.', 'Naturally occurring materials may be underived and/or unprocessed naturally occurring materials, as well as materials based on naturally occurring materials that have been processed and/or derived.', 'Suitable examples of naturally occurring particulate materials for use as proppants include: ground or crushed shells of nuts such as walnut, coconut, pecan, almond, ivory nut, brazil nut, etc.; ground or crushed seed shells (including fruit pits) of seeds of fruits such as plum, olive, peach, cherry, apricot, etc.; ground or crushed seed shells of other plants such as maize (e.g., corn cobs or corn kernels), etc.; processed wood materials such as those derived from woods such as oak, hickory, walnut, poplar, mahogany, etc., including such woods that have been processed by grinding, chipping, or other form of particulation, processing, etc.', 'The concentration of proppant in the fluid can be any concentration known in the art.', 'For example, the concentration of proppant in the fluid may be in the range of from about 0.03 to about 3 kilograms of proppant added per liter of liquid phase.', 'Also, any of the proppant particles can further be coated with a resin to potentially improve the strength, clustering ability, and flow back properties of the proppant.', 'A fiber component, in addition to the hydrophilic fiber discussed above, may be included in the fluids to achieve a variety of properties including improving particle suspension, and particle transport capabilities, and gas phase stability.', 'The fiber component may also be hydrophilic or hydrophobic in nature.', 'The fiber component can be any fibrous material, such as, for example, natural organic fibers, comminuted plant materials, synthetic polymer fibers (by non-limiting example polyester, polyaramide, polyamide, novoloid or a novoloid-type polymer), fibrillated synthetic organic fibers, ceramic fibers, inorganic fibers, metal fibers, metal filaments, carbon fibers, glass fibers, ceramic fibers, natural polymer fibers, and any mixtures thereof.', 'Particularly useful fibers are polyester fibers coated to be highly hydrophilic, such as, but not limited to, DACRON® polyethylene terephthalate (PET) fibers available from Invista Corp. Wichita, Kans., USA, 67220.', 'Other examples of useful fiber components include, but are not limited to, polylactic acid polyester fibers, polyglycolic acid polyester fibers, polyvinyl alcohol fibers, and the like.', 'The fiber component may present in the amounts described above for the hydrophilic fiber.', 'Embodiments may further use fluids containing other additives and chemicals that are known to be commonly used in oilfield applications by those skilled in the art.', 'These include materials such as surfactants in addition to those mentioned hereinabove, breaker aids in addition to those mentioned hereinabove, oxygen scavengers, alcohol stabilizers, scale inhibitors, corrosion inhibitors, fluid-loss additives, bactericides and biocides such as 2,2-dibromo-3-nitrilopropionamine or glutaraldehyde, and the like.', 'Also, they may include a co-surfactant to optimize viscosity or to minimize the formation of stable emulsions that contain components of crude oil.', 'In one or more embodiments, the fluid system may include a thickener selected from natural polymers including guar (phytogenous polysaccharide) and guar derivatives (e.g., hydroxypropyl guar and carboxymethylhydroxypropyl guar) and synthetic polymers including polyacrylamide copolymers.', 'Additionally, viscoelastic surfactants that form elongated micelles are another class of non-polymeric viscosifiers that may be added to the fluid in addition to or independently from the polymeric thickeners.', 'Other polymers and other materials, such as xanthan, scleroglucan, cellulose derivatives, polyacrylamide and polyacrylate polymers and copolymers, viscoelastic surfactants, and the like, can be used also as thickeners.', 'For example, water with guar represents a linear gel with a viscosity that increases with polymer concentration.', 'In hydraulic and acid fracturing, a first fluid called the pad may be injected into the formation to initiate and propagate the fracture.', 'This is followed by a second fluid that contains a proppant to keep the fracture open after the pumping pressure is released.', 'The hydrophilic fibers of the present disclosure may be included in either fluid, and in particular embodiments, may be included in the second fluid to help suspend proppants.', 'However, it is envisioned that the hydrophilic fibers may be used for carrying out a variety of subterranean treatments/wellbore operations including, but not limited to, drilling operations, diverting treatments, gravel packing, zonal isolation, or downhole delivery.', 'Such operations are known to persons skilled in the art and involve pumping a wellbore fluid into a wellbore through an earthen formation and performing at least one wellbore operation while the wellbore fluid is in the wellbore.', 'Depending on the type of operation being performed, the size of the fibers selected may vary, i.e., to form a plug in a diversion, longer fibers (relative to a fracture width) may be selected.', 'Additional methods may be employed to implement this technology in the oilfield.', 'For example, the cellulose fiber may be with the water soluble polymer and the resulting product may be dried into sheets, which can later be dispersed into an aqueous medium with a cross-linking agent.', 'Another technique includes forming pellets of pulp (e.g., average diameter of 1-1000 microns) that are held together by drying the fiber.', 'The dried fibers may then be added to aqueous medium and are dispersed in aqueous medium.', 'A crosslinking agent may then be added to crosslink the dispersed fibers in the aqueous medium.', 'Another technique is forming pellets by first coating the hydrophilic fibers with the water soluble polymers.', 'A crosslinking agent may then be added and the resulting solution dried to form pellets.', 'The pellets may then be added to a mixing device, such that the crosslinked bonds may be removed by breakers or breaking agent, resulting in dispersion of the fibers in the aqueous medium.', 'The crosslinking agent may further include a delay agent such that the crosslinking occurs farther into the formation to form diversion plugs on the high pressure side.', 'The foregoing is further illustrated by reference to the following examples, which are presented for purposes of illustration and are not intended to limit the scope of the present disclosure.', 'EXAMPLES\n \nExample 1\n \nExample 1(a)', 'The fibers were first treated to attach a coating of carboxymethyl cellulose (CMC) to the surface.', 'The following steps were taken to achieve this: \n \n1.', 'CMC was fully hydrated by adding 0.12 wt % of CMC to 100 mL of water and mixed at 3000 rpm in a Waring blender for 20 min.\n \n2.', 'After hydration was completed, added 2 wt % of dry cellulose fibers to the Waring blender with hydrated CMC.', 'In addition, 0.5 wt % of calcium chloride was added to the blender.', '3.', 'The components were allowed to mix for 5 minutes in the Waring blender at the same speed.', '4.', 'The fluid was heated in a microwave and maintained at a temperature of 95° C., constantly stirring the sample manually for 15 minutes.', '5.', 'The fluid was then centrifuged for 10 minutes at 350 rpm.', 'The supernatant was disposed of after centrifugation.', '6.', 'A Mettler Toledo moisture analyzer was used to dry the sample.', 'The cellulose fibers were dried at 100° C. for 2 hours.', '7.', 'After the cellulose fibers were completely dried, they were let to cool down to room temperature.', 'In order to obtain a benchmark, 0.6 wt % of cellulose fibers with surface attached CMC was placed in a Waring blender and re-dispersed in water by mixing at 3000 rpm for 1 minute.', 'A volume of 5 mL of this fluid was placed in a petri dish for optimal microscope imaging, using a Leica Model MSV266. \nFIGS.', '1\nA and \n1\nB\n show the microscope images of the re-dispersed cellulose fibers with surface attached CMC.', 'Both figures are the same, except \nFIG.', '1\nB\n indicates the sizes of the flocs formed (from left to right 0.565 mm, 1.196 mm, 1.856 mm).', 'The images of \nFIGS.', '1\nA and \n1\nB\n were taken as a form of comparison for the following examples.', 'Example 1(b)', 'The cellulose fibers with surface attached CMC created in Example 1 (a) were used.', 'These fibers were then cross-linked using an amine.', 'A concentration of 0.6 wt % of dry cellulose fibers with surface attached CMC was dispersed in 50 mL of water (using the method of Example 1 (a)).', 'The 50 mL of fiber suspension was stirred (Corning PC-4200) using a stirrer bar at 240 rpm.', 'Added 0.3 wt % of N-(3-Dimethylaminopropyl)-N′-ethylcarbodiimide hydrochloride (EDC), used as a carboxyl activating agent to bond with amines.', 'The EDC was used to react with the CMC on the surface of the fibers by means of an ester bond.', 'The cellulose fibers and EDC were left to mix for 5 min at the same speed.', 'Then the fibers were cross-linked using tetraethylenepentamine (TEPA).', 'TEPA was added to the mixture at a concentration of 0.2 wt %', 'and it was all allowed to mix for 4 hours at room temperature at the same speed.', 'FIGS.', '2\nA and \n2\nB\n are microscope images of the cellulose fibers of \nFIGS.', '1\nA and \n1\nB\n cross-linked using tetraethylenepentamine.', 'The images of \nFIGS.', '2\nA and \n2\nB\n were taken using the same microscope used to capture the images of \nFIGS.', '1\nA and \n1\nB\n.', 'Where, as in the previous example, both pictures are the same except the one on the right depicts dimensions of the flocculates (4.172 mm, 4.679 mm, from left to right).', 'It can be observed that the flocculates formed (white agglomerates) are at least 4 times larger than those observed in \nFIG.', '1\n, which suggests that the CMC-EDC-TEPA combination was able to cross-link the surface of the fibers and bring them together.', 'Example 2\n \nThis example shows the use of a polyelectrolyte complex (CMC and chitosan) as a method to bring fiber surfaces together.', 'The same dried cellulose fibers with surface attached CMC produced in Example 1(a) were used in this example.', 'A concentration of 0.6 wt % dried cellulose fibers was re-dispersed in 100 mL of water in a Waring blender at 3000 rpm for 1 minute.', 'In parallel, a concentration of 0.12 wt % chitosan of medium molecular weight (˜100,000 g/mol) was hydrated.', 'Chitosan hydrates at low pH, therefore, 0.1 mL of acetic acid was added to 100 mL of water in a Waring blender to achieve a pH=4-5.', 'The weighed chitosan amount was then added to the blender cup and stirred at 3000 rpm for 20 min.', 'In a petri dish, added 2.5 mL of 0.6 wt % suspended cellulose fiber with surface attached CMC.', 'Then, to the same petri dish, added 2.5 mL of chitosan.', 'The ratio of polymer was 1:0.5 CMC to chitosan.', 'After adding the chitosan, the effect was immediate to where majority of the cellulose fibers aggregated together.', 'FIGS.', '3\nA and \n3\nB\n are microscope images of cellulose fibers with surface attached CMC suspended in water with added chitosan.', 'The images of \nFIGS.', '3\nA and \n3\nB\n were taken using the same method as in the previous examples.', 'Both images are the same, except the image of \nFIG.', '3\nB\n depicts the dimensions of the agglomerates: 8.338 mm×22.197 mm.', 'As seen in the images, these aggregates are composed of majority of the fibers in the fluid.', 'Surrounding the aggregates there are almost no observed fibers, which indicate that the polyelectrolyte complex helps in bringing the fiber surfaces together.', 'Example 3 (a)', 'The fibers were first treated to attach a coating of polyacrylamide to the surface.', 'The following steps were taken to achieve this: \n \n1.', 'The polymer was fully hydrated by adding 0.12 wt % of polyacrylamide to 100 mL of water and mixed at 3000 rpm in a Waring blender for 20 min.\n \n2.', 'After hydration was completed, added 2 wt % of dry cellulose fibers to the Waring blender with hydrated polyacrylamide.', '3.', 'The components were allowed to mix for 5 minutes in the Waring blender at the same speed.', '4.', 'The fluid was then centrifuged for 10 minutes at 350 rpm.', 'The supernatant was disposed of after centrifugation.', '5.', 'A Mettler Toledo moisture analyzer was used to dry the sample.', 'The cellulose fibers were dried at 100° C. for 2 hours.', '6.', 'After the cellulose fibers were completely dried, they were let to cool down to room temperature.', 'In order to obtain a benchmark, 0.6 wt % of cellulose fibers with surface attached polyacrylamide was placed in a Waring blender and re-dispersed in water by mixing at 3000 rpm for 1 minute.', 'A volume of 5 mL of this fluid was placed in a petri dish for optimal microscope imaging, using a Leica Model MSV266. \nFIGS.', '4\nA and \n4\nB\n are microscope images of the re-dispersed cellulose fibers with surface attached polyacrylamide.', 'Both images are the same, except the image of \nFIG.', '4\nB\n indicates the sizes of the flocs formed (from left to right 0.859 mm, 1.353 mm, and 3.135 mm).', 'The images of \nFIGS.', '4\nA and \n4\nB\n taken as a form of comparison for the following examples.', 'Example 3 (b)', 'This example shows the use of a zirconium cross-linker as a method to bring the cellulose fiber surfaces together.', 'The same dried cellulose fibers with surface attached polyacrylamide produced in Example 3(a) were used in this example.', 'A concentration of 0.6 wt % dried cellulose fibers was re-dispersed in 100 mL of water in a Waring blender at 3000 rpm for 1 minute.', 'Took 50 mL of the cellulose fiber suspension and placed in a glass beaker on a hot/stirring plate (Corning PC-4200).', 'The fluid was stirred with a stir bar and allowed to heat to 49° C.', 'Once the fluid reached the desired temperature of 49° C., then 0.21 wt % of zirconium dioxide (ZrO\n2\n) was added.', 'The mixture was stirred for 1 minute at the previous conditions.', 'FIGS.', '5\nA and \n5\nB\n are microscope images of cellulose fibers with surface added polyacrylamide dispersed in water and cross-linked using zirconium dioxide.', 'The images of \nFIGS.', '5\nA and \n5\nB\n were taken using the same microscope as in the previous examples.', 'The image of \nFIG.', '5\nB\n depicts dimensions of the flocculates (4.035 mm, 4.410 mm, and 7.102 mm from left to right).', 'The flocculates formed (white agglomerates) are larger than those observed in \nFIG.', '4\nB\n, which suggests that the zirconium dioxide and polyacrylamide combination was able to cross-link the surface of the fibers and bring them together and form bigger agglomerates.', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.']

['1.', 'A method of treating a subterranean formation, the method comprising:\nforming a treatment fluid, comprising: at least one hydrophilic, pulp cellulose-based fiber, wherein an outer wall of the at least one hydrophilic, pulp cellulose-based fiber is coated with a water soluble polymer comprising carboxymethylcellulose, and the at least one hydrophilic, pulp cellulose-based fiber is dried after being coated with the water soluble polymer; and at least one crosslinking agent tetraethylenepentamine; and\nplacing the treatment fluid in the subterranean formation.', '2.', 'The method of claim 1, wherein the at least one hydrophilic, pulp cellulose-based fiber comprises a pulp cellulose fiber, a powdered cellulose fiber, a microfibrillated cellulose fiber, a nanofibrillated cellulose fiber, a nanocrystalline cellulose fiber, or a combination thereof.', '3.', 'The method of claim 1, wherein a ratio between a length of the at least one hydrophilic, pulp cellulose-based fiber and a width of the at least one hydrophilic, pulp cellulose-based fiber is between about 5 and about 1000.', '4.', 'The method of claim 1, wherein the water soluble polymer comprises a polysaccharide, a polyelectrolyte, a non-charged polymer, or a combination thereof.', '5.', 'The method of claim 1, wherein the amount of the water soluble polymer used in the treatment fluid is from about 0.6 mg per gram of the at least one hydrophilic, pulp cellulose-based fiber added to 120 mg per gram of the at least one hydrophilic, pulp cellulose-based fiber added.', '6.', 'The method of claim 1, wherein the water soluble polymer comprises a resin.', '7.', 'The method of claim 6, wherein the resin comprises a polyamideamine-epichlorohydrin (PAE) resin, a formaldehyde resin, an epoxide resin, an aldehyde resin, or a combination thereof.', '8.', 'The method of claim 1, wherein the water soluble polymer is modified or functionalized.', '9.', 'A treatment fluid comprising:\nat least one hydrophilic, pulp cellulose-based fiber, wherein an outer wall of the at least one hydrophilic, pulp cellulose-based fiber is coated with a water soluble polymer comprising carboxymethylcellulose, and the at least one hydrophilic, pulp cellulose-based fiber is dried after being coated with the water soluble polymer; and\nat least one crosslinking agent comprising tetraethylenepentamine.', '10.', 'The treatment fluid of claim 9, further comprising a powdered cellulose fiber, a microfibrillated cellulose fiber, a nanofibrillated cellulose fiber, a nanocrystalline cellulose fiber, or a combination thereof.', '11.', 'The treatment fluid of claim 9, wherein a ratio between a length of the at least one hydrophilic, pulp cellulose-based fiber and a width of the at least one hydrophilic, pulp cellulose-based fiber is between about 5 and about 1000.', '12.', 'The treatment fluid of claim 9, wherein an amount of the water soluble polymer in the treatment fluid is from about 0.6 mg per gram of the hydrophilic, pulp cellulose-based fiber added to 120 mg per gram of the hydrophilic, pulp cellulose-based fiber added.', '13.', 'The treatment fluid of claim 9, wherein the at least one crosslinking agent further comprises glutaraldehyde, glyoxal, a zinc-based compound, a zirconium-based compound, or a combination thereof.', '14.', 'The treatment fluid of claim 9, wherein the at least one hydrophilic, pulp cellulose-based fiber is dried before being coated with the water soluble polymer.', '15.', 'The treatment fluid of claim 9, wherein the at least one crosslinking agent comprises a delay agent.', '16.', 'The treatment fluid of claim 9, wherein the at least one hydrophilic, pulp cellulose-based fiber is dried into one or more sheets, one or more pellets, or both, and subsequently added to an aqueous medium.\n\n\n\n\n\n\n17.', 'The treatment fluid of claim 9, comprising a three-dimensional polymerized structure having a plurality of coated fibers cross-linked via the at least one crosslinking agent, wherein each of the plurality of coated fibers comprises:\nthe hydrophilic, pulp cellulose-based fiber; and\na dried coating disposed on the outer wall of the hydrophilic, pulp cellulose-based fiber, wherein the dried coating comprises the water soluble polymer comprising the carboxymethylcellulose.', '18.', 'A treatment fluid comprising:\na hydrophilic fiber network comprising a plurality of coated fibers cross-linked via at least one crosslinking agent comprising tetraethylenepentamine, wherein each of the plurality of coated fibers comprises:\na hydrophilic, pulp cellulose-based fiber; and\na dried coating disposed on an outer wall of the hydrophilic, pulp cellulose-based fiber, wherein the dried coating comprises a water soluble polymer comprising carboxymethylcellulose.', '19.', 'The treatment fluid of claim 18, comprising a carboxyl activating agent including N-(3-Dimethylaminopropyl)-N′-ethylcarbodiimide hydrochloride (EDC).', '20.', 'The treatment fluid of claim 18, wherein the hydrophilic fiber network is configured to bridge fractures within a subterranean formation.']

['FIGS.', '1A and 1B are microscope images of cellulose fibers with surface attached carboxymethylcellulose according to one embodiment.;', 'FIGS.', '2A and 2B are microscope images of the cellulose fibers of FIGS.', '1A and 1B cross-linked using tetraethylenepentamine according to another embodiment.;', 'FIGS.', '3A and 3B are microscope images of cellulose fibers with surface attached CMC suspended in water with added chitosan according to one embodiment.;', 'FIGS. 4A and 4B are microscope images of the re-dispersed cellulose fibers with surface attached polyacrylamide.;', 'FIGS.', '5A and 5B are microscope images of cellulose fibers with surface added polyacrylamide dispersed in water and cross-linked using zirconium dioxide.;', 'FIGS.', '5A and 5B are microscope images of cellulose fibers with surface added polyacrylamide dispersed in water and cross-linked using zirconium dioxide.', 'The images of FIGS.', '5A and 5B were taken using the same microscope as in the previous examples.', 'The image of FIG.', '5B depicts dimensions of the flocculates (4.035 mm, 4.410 mm, and 7.102 mm from left to right).', 'The flocculates formed (white agglomerates) are larger than those observed in FIG.', '4B, which suggests that the zirconium dioxide and polyacrylamide combination was able to cross-link the surface of the fibers and bring them together and form bigger agglomerates.']

US11831166

Rig power management system

Jun 3, 2019

Alejandro Camacho Cardenas, David Robert Evan Snoswell

SCHLUMBERGER TECHNOLOGY CORPORATION

International Preliminary Report on Patentability issued in International Patent Application No. PCT/US2019/035142 dated Dec. 10, 2020, 11 pages.; International Search Report and Written Opinion issued in International Patent Application No. PCT/US2019/035142 dated Dec. 5, 2019, 12 pages.

20090312885; December 17, 2009; Buiel; 20130234515; September 12, 2013; Boone; 20140077600; March 20, 2014; Cryer; 20180284758; October 4, 2018; Cella; 20190041835; February 7, 2019; Cella; 20190267805; August 29, 2019; Kothuru

2008102166; August 2008; WO; 2011126661; October 2011; WO

['A system for monitoring and optimizing fuel consumption by a genset at an oil rig is described.', 'Gensets require large amounts of fuel to initiate and to maintain in a standby, idling position.', 'The system accesses data in a drill plan to determine the present and future power requirements and initiates gensets if needed; otherwise gensets can be shut down.', 'Excess power can be stored in a power storage unit such as a capacitor, battery, or a liquid air energy storage unit.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED PATENT APPLICATIONS\n \nThis application is the National Stage of International Application No. PCT/US2019/035142, filed Jun. 3, 2019, which claims priority to and the benefit of U.S. Provisional Application No. 62/679,373, filed Jun. 1, 2018.', 'Both applications are hereby incorporated herein by reference.', 'BACKGROUND\n \nIn the oilfield there are many large-scale operations that consume relative large amounts of fuel and output similarly large amounts of power.', 'One popular way to achieve the power required is referred to commonly as a “genset,” consisting of a combination of a prime mover (such as an engine) and an alternator.', 'The prime mover converts the chemical energy of fuel to a mechanical energy.', 'Gensets are large and can consume many gallons of diesel fuel per day.', "The demands of a modern oil rig require a certain amount of power to be available at a moment's notice so for much of the time gensets are set to idle, which consumes fuel.", 'There is a need in the art for an increased efficiency with the use of gensets.', 'SUMMARY\n \nEmbodiments of the present disclosure are directed to systems for managing fuel expenditures at an oil rig.', 'The systems may include a plurality of gensets, individual gensets comprising a prime mover and an alternator.', 'The system also includes a load operatively coupled to one or more of the gensets and being configured to receive power from the gensets to execute one or more tasks at the oil rig.', 'The system also includes a controller operatively coupled to the gensets and the load.', 'The controller is configured to monitor power consumption by the load and to monitor an operating status of the gensets.', 'The system also includes a database being configured to store a drill plan detailing the tasks including power consumption and duration for the tasks.', 'The controller is configured to calculate a total expected power consumption for tasks at a certain time period, identify a number of gensets necessary to provide sufficient power to execute the tasks at the certain time period, and to ensure that the number of gensets necessary are running at a sufficient level at the certain time.', 'In further embodiments the system further includes a power storage unit operatively coupled to one or more of the gensets and being configured to receive power from one or more of the gensets and to store the power for later use.', 'The power storage unit is also being operatively coupled to the load and configured to deliver the power stored in the power storage unit to the load to execute one or more of the tasks.', 'In further embodiments the controller is further configured to analyze data in the drill plan pertaining to a second time later than the certain time, calculate a second total expected power consumption for tasks at the second time, identify a number of gensets necessary to provide sufficient power to execute the tasks at the second time period, and to ensure that the number of gensets necessary are running at a sufficient level at the second time.', 'Further embodiments of the present disclosure are directed to a method for optimizing fuel consumption by gensets at an oil rig.', 'The method includes accessing a rig plan including data describing times and power consumption loads associated with a plurality of tasks at the oil rig and, for a given time period, summing the power consumption loads for the tasks scheduled during the given time period in the rig plan.', 'The method also includes calculating a number of gensets required to provide sufficient power for the tasks scheduled during the given time period while allowing at least a predetermined quantity of headroom power in addition to the summed power consumption loads, and ensuring that sufficient gensets are running at the given time.', 'The method can also include diverting the headroom power to a power storage unit, and accessing the headroom power stored in the power storage unit as required by the tasks.', 'Further embodiments are directed to methods which include monitoring a power consumption associated with a specific task, comparing the power consumption load in the rig plan for the specific task, and issuing an alarm if a difference between the power consumption associated with the specific task differs from the power consumption load in the rig plan for the specific task by an amount greater than a predetermined threshold.', 'Yet further embodiments of the present disclosure are directed to a system for managing a plurality of gensets at an oil rig.', 'The system includes a plurality of gensets configured to consume fuel and deliver power, a load configured to receive power from the gensets, the load defining a drilling operation at the oil rig.', 'Power consumption and scheduling data for the load is described in a drill plan.', 'The system also includes a power storage unit configured to receive power from at least one of the gensets and to deliver the stored power to the load as needed, and a computational unit configured to monitor the gensets, monitor the load, access the drill plan to determine how much power will be required at a given time during the drilling operation, and to ensure that a sufficient number of gensets are running at the given time to meet the power demands of the load.', 'The computational unit is further configured to monitor the power storage unit for capacity and availability of power, to divert power to the power storage unit when the power is not needed for the load, and to access power stored in the power storage unit when the load exceeds the available power from the gensets.', 'In still further embodiments the system includes a system health monitoring component configured to monitor actual power consumed for specific tasks in the load and to compare the actual power consumed to corresponding data in the drill plan, and if they differ by more than a predetermined tolerance value, the system health monitoring component is configured to notify an operator.', 'BRIEF DESCRIPTION OF THE FIGURES\n \nFIG.', '1\n is a graph of power and time according to embodiments of the present disclosure.\n \nFIG.', '2\n shows a relationship between genset, load, and storage unit according to embodiments of the present disclosure.\n \nFIG.', '3\n is a graph of expected and actual power delivery according to embodiments.\n \nFIG.', '4\n is a flowchart of a method for operating a plurality of gensets and one or more storage units with a controller according to embodiments of the present disclosure.\n \nFIG.', '5\n is another flowchart for of a method of operating genset(s), controllers, and loads to improve efficiency according to embodiments of the present disclosure.\n \nFIG.', '6\n is another flowchart diagram of a method for operating one or more gensets to provide power to a load with increased efficiency and reduced idling time according to embodiments of the present disclosure.\n \nFIG.', '7\n is a graph of expected efficiency performance of a genset or associated systems against actual efficiency performance to identify potential system health issues according to embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'Below is a detailed description according to various embodiments of the present disclosure.', 'FIG.', '1\n is a graph \n100\n of power and time according to embodiments of the present disclosure.', 'Power is on the vertical axis and is represented by gensets 1-3 and a fourth genset which can be periodically interchanged with a storage unit.', 'The power delivery capabilities of each of gensets 1-4 is shown at \n110\n, \n112\n, \n114\n, and \n116\n.', 'The total demand for power at the first instance of time on the graph \n100\n will require the power of gensets 1 and 2 and some portion of genset 3.', 'The load on the gensets that requires this power is tasks 1-5 which together amount to slightly less than what is provided by gensets 1-3.', 'The difference, or headroom \n118\n between the required power and available power is shown by the arrow.', 'From time-to-time the power demands change.', 'At the second instance of time shown task 1 has been reduced by 30%, tasks 2-4 continue unchanged, and task 5 has been suspended altogether.', 'The headroom \n120\n is therefore larger and the total power demand is less than the power provided by gensets 1 and 2.', 'Accordingly, genset 3 can be powered down during this time.', 'At the third instance of time tasks 1-4 are the same as they were at the second instance of time but task 5 has been resumed with an additional 20% required, and a new task 6 has been initiated.', 'The total power demand is therefore greater than what is provided by gensets 1-3 and genset 4, or power from a storage unit, is required.', 'The numbers and relative positions of the tasks and gensets shown in \nFIG.', '1\n can vary greatly.', 'The tasks can be anything on an oil rig such as drawworks, a top drive, or any of hundreds of possible tasks that require power during a rig operation.', 'There may be any number of gensets and they are not necessarily in a preferred order.', 'In some embodiments the gensets can be rotated to distribute load more evenly to avoid wear on one genset over another.', 'The time for a task is also variable and can be short such as a few seconds, or long such as days or months of use.', 'It is to be appreciated that the number of tasks and possible combinations of tasks can be immense.\n \nFIG.', '2\n shows a relationship between genset \n130\n, load \n132\n, and storage \n134\n according to embodiments of the present disclosure.', 'Recall the relationship between headroom and available power shown in \nFIG. \n1\n as well.', 'The genset \n130\n provides power to the load \n132\n.', 'The genset \n130\n can also be configured to provide power to a storage unit \n134\n which can consist of a battery, a capacitor, or any other suitable power storage unit.', 'Excess power from the genset \n130\n can be diverted to the storage unit and stored for later use.', 'In some embodiments the storage unit \n134\n can supply the power required during a certain time when demand for power exceeds the available power provided by a number of gensets.', 'There is a fuel cost associated with starting a genset, and if a power demand can be met by tapping into stored power it could result in large efficiency gains.', 'The gensets and their available power can be considered in discrete intervals, and this effect is of even more importance because the efficiency of the gensets is highest near the maximum operating capacity.', 'On the other hand, slowing down an oil rig operation because there is insufficient power available is costly.', 'There is a desirable balance between reducing idle time and providing as near to exactly the power required.', 'A controller \n136\n can be operatively coupled to the genset \n130\n, the load \n132\n, and the storage \n134\n by a series of sensors and telemetry equipment.', 'The controller can be configured to monitor the required power and the current demands for power.', 'A database \n138\n is coupled to the controller \n136\n.', 'The database \n138\n can be any suitable data storage component or memory capable of storing data as is known in the art.', 'The controller \n136\n stores data relating to the power demands of the various tasks that will comprise the load \n132\n.', 'The controller \n136\n can also monitor the operating states of the gensets and information about the gensets such as efficiency rate, fuel consumption, running time, available capacity, etc.', 'The controller \n136\n can calculate the headroom available at any given time.', 'The controller \n136\n can be a programmable logic controller (PLC) a computer such as a desktop or laptop computer, or can be any other suitable computational device including a mobile device such as a smartphone or a tablet.', 'The database \n138\n can be any type of storage medium such as a hard drive, solid state drive, or server.', 'The storage unit \n134\n can be any suitable type of energy storage unit with sufficient capabilities to meet the demands of the rig.', 'Some supercapacitors can store 1.1 MW/3.3 kWhr or more to provide up to 3.7 seconds of rig time.', 'Some batteries can provide 1 MW/450 kWhr to achieve 8.4 minutes of rig time.', 'Another type of storage is liquid air energy storage (LAES) which can provide 516 kWhr/10,000 liters to achieve 9.7 minutes or rig time.', 'These are some examples of the amount of storage available for use with the systems and methods of the present disclosure.', 'There can be multiples of these items in any combination to achieve even more available power quantities.', 'The database \n138\n can store a drill plan detailing upcoming tasks scheduled for the load \n132\n.', 'The drill plan can also be called a rig plan and can be a sequence of operations or tasks that are to be executed on the rig and an associated power requirement.', 'With this information available ahead of time, the controller \n136\n can be configured to monitor the current status of power and demands and calculate headroom, and it can also predict future demands.', 'For example, referring to \nFIG.', '1\n, during the first instance of time the drill plan may call for the suspension of task 5 at a certain time in the near future.', 'The controller \n136\n can initiate a shutdown of genset 3 at a precise time to achieve increased efficiency by reducing or eliminating time that genset 3 is running but not needed.', 'In some embodiments genset 3 can even be shutdown moments before task 5 is to be suspended.', 'The controller \n136\n and database \n138\n can know when to shut down genset 3 to achieve increased efficiency.', 'The database \n138\n can store information generated by the controller \n136\n obtained by monitoring tasks executed by the load \n132\n and the power actually used by the load \n132\n. \nFIG.', '3\n is a graph \n140\n of expected and actual power delivery according to embodiments.', 'In this embodiment the expected power is higher than the actual power at each stage in the process.', 'Of course the graph \n140\n may vary greatly depending on a given configuration.', 'This is empirical data describing individual tasks and the actual power required to execute the task.', 'The controller \n136\n can compare the expected power requirement for a given task to the actual, empirical data obtained by monitoring the task.', 'If the empirical data suggests it, the controller \n136\n can update the value associated with a given task in the database \n138\n.', 'In some embodiments the controller \n136\n can be programmed with a variance tolerance and if the difference between expected and empirical power is greater than the variance tolerance the controller \n136\n can take action either to issue an alarm or to update the values for the expected.', 'Trends may appear in the power consumption of a given task which can indicate system health may be deteriorating.', 'Over time and use gensets will become more inefficient and this expected wear and tear can be factored into the variance tolerance.', 'But if a certain task is consistently requiring more power, an alarm can be issued to alert an operator.', 'Fuel consumption can also be factored in to the calculus.', 'For example, in some embodiments the power delivered can be held constant to achieve the same power output to execute a given task, but more fuel was required.', 'This can also be an indicator of system health deterioration.', 'In other embodiments the fuel can be held constant and the decline in resulting power delivered can be observed.', 'When there is a deviation from expected power delivery, the controller \n136\n can be programmed to identify patterns in the tasks that may account for the deviation.', 'When a deviation is identified, the tasks running at the time of the deviation (or perhaps also beforehand) can be recorded to check for patterns if the same or similar deviation were to occur again.', 'Armed with this data from the drill plan, the controller \n136\n can operate the gensets \n130\n and the storage \n134\n together in concert to reduce or eliminate wasteful idling, while providing the load \n132\n with sufficient operating power without costly downtime.\n \nFIG.', '4\n is a flowchart of a method \n150\n for operating a plurality of gensets and one or more storage units with a controller according to embodiments of the present disclosure.', 'At \n152\n the method initiates either at the request of an operator or automatically in response to a signal, a predetermined time period, or the occurrence of some other operation or event at the rig.', 'The method \n150\n can be carried out locally by a controller or can be remotely operated over communication lines such as WIFI or the internet.', 'At \n154\n the method includes obtaining a predicted load data for an upcoming time period.', 'Such data can be part of a drill plan stored on a local database or accessed over long-range communication lines.', 'The data can include a list of tasks to be executed during the time and an associated power requirement for each.', 'The time period can be any time period long or short.', 'At \n156\n it is calculated how many gensets will be required to deliver the required power.', 'In some embodiments this is as simple as summing the power required by the tasks to be executed.', 'In other embodiments the tasks interrelate in such a way that the power requirements for two tasks together is different than it would be for either alone.', 'At \n158\n a query is executed to determine if there is a need for additional or fewer gensets than the number currently running.', 'If there is no such need, the method can return to \n154\n by obtaining the next upcoming time period and the associated load.', 'If there is a need for fewer gensets, the method can then determine at \n159\n whether or not there is capacity and/or need to charge a power storage unit.', 'If not, at \n160\n the genset is shut down.', 'Within the determination that there are fewer gensets required is the time and fuel cost associated with shutting down and starting up the genset.', 'While the exact numbers for such a decision will depend on the particulars of a given genset and task, the time period during which the genset will not be needed and the fuel and wear and tear cost of a shutdown/startup cycle are factored into the decision.', 'If there is a need and capacity in a storage unit at \n164\n headroom is calculated at \n164\n and at \n166\n the excess energy produced is diverted to the storage unit.', 'The method can continue by directing control back to \n154\n by obtaining the next time period for analysis, or the method can terminate at \n168\n.\n \nFIG.', '5\n is another flowchart for of a method \n170\n of operating genset(s), controllers, and loads to improve efficiency according to embodiments of the present disclosure.', 'At \n172\n the method is initiated.', 'At \n174\n a decision is made based on the drill plan data and the current load on the genset(s) whether or not a peak or trough is coming.', 'The determination can be based on a difference between the current power consumption and the expected upcoming power consumption.', 'If the difference A is greater than a threshold, larger indicates a peak, and smaller indicates a trough.', 'If neither is determined, the method can continue periodic checks.', 'When a peak is identified at \n176\n a calculation is made to determine a number of additional gensets that will be required to meet the demand.', 'In some embodiments this determination is made by summing the power requirements of all the expected tasks and comparing it against the power delivery as shown in \nFIG.', '1\n.', 'At \n178\n the method includes determining whether or not there are sufficient gensets available, which can include any storage units which may be tapped, to meet the demand.', 'At \n180\n if there are insufficient gensets and storage units available, an alarm is issued.', 'If there are sufficient gensets available at \n182\n they are initiated.', 'The method continues at \n184\n by repeating or terminating.', 'If a trough is identified at \n186\n a calculation is made to identify the number of gensets that can be shut off.', 'This determination can take into account the time for the expected trough and the cost of a shutdown/startup cycle.', 'At \n188\n a determination can be made of whether or not there is capacity and/or need in one or more storage units.', 'If not, the method continues at \n190\n by shutting down the genset(s).', 'If there is capacity and need in the storage unit, the energy is diverted to the storage unit at \n192\n.', 'The method then continues by repeating or terminating.', 'In some embodiments the method can continue in the absence of a command to terminate.', 'In other embodiments the method executes once per instance of receiving a new time period for analysis from the drill plan.', 'In some embodiments the method continues periodically without regard to the timing and information in the drill plan.\n \nFIG.', '6\n is another flowchart diagram of a method \n200\n for operating one or more gensets to provide power to a load with increased efficiency and reduced idling time according to embodiments of the present disclosure.', 'At \n202\n the method initiates.', 'At \n204\n a controller or other suitable computing apparatus identifies upcoming increases in load.', 'The information for the controller to make this identification comes from a drill plan that is stored in a database either locally or remotely.', 'The controller can compare the current load against the planned load.', 'At \n206\n the controller can determine whether or not the increased load will require initiating an additional genset above the number that are currently operating.', 'If not, the method can repeat or terminate at \n214\n.', 'If so, the controller can then at \n208\n look to see if there are available reductions in other loads that may allow the upcoming demand to be met without requiring the use of an additional genset.', 'If not, the method passes to repeat or terminate at \n214\n.', 'If there are other loads that may be reduced, at \n210\n the controller can query whether or not the reductions will provide sufficient energy to avoid starting another genset.', 'If not the method passes to repeat/terminate at \n214\n.', 'If there are sufficient loads that can be reduced, either by postponing, delaying, diminishing, or otherwise redistributing the load to avoid needing another genset, at \n212\n the controller initiates the reduction.', 'Afterward the method can repeat/terminate at \n214\n.', 'A reduction in load can come in many forms, including reducing intensity, delaying a task, redistributing a load from one piece of equipment to another, or by shutting down certain processes and tasks temporarily or indefinitely.', 'The cost of the reduction can also be factored in.', 'The cost of the reduction can be measured in terms of the energy required to startup, shut down, or redistribute loads, as well as the impact on the drill plan.', 'If a reduction will cause the entire rig to delay by, say, one hour than the efficiency gains achieved by the reduction are not worth the cost.', 'The controller can normalize these decisions by comparing a monetary value.', 'Idling the genset consumes fuel which has a price that can be measured and applied.', 'Also, the cost of a potential delay can also be expressed in terms of the cost it will incur.', 'Rig time is notoriously expensive, so if any proposed reduction increases rig time it is likely not worth doing.', 'The controller can execute these decisions with the help of input from an operator to arrange the parameters of the costs (both in terms of energy and money) associated with each.\n \nFIG.', '7\n is a graph of expected efficiency performance of a genset or associated systems against actual efficiency performance to identify potential system health issues according to embodiments of the present disclosure.', 'There are two plots: expected performance, and actual performance.', 'The two lines are offset by an offset \n220\n to more clearly illustrate the differences and similarities of the two plots.', 'All equipment will deteriorate at one rate or another.', 'Much of the equipment used with the present disclosure including the gensets and the machine and systems that make up the load has a known or expected deterioration rate.', 'This can be based on track record or empirical monitoring.', 'Actual deterioration can be measured and compared against the expected deterioration rate and if there is a deviation great enough, an alarm can be issued to alert an operator of potential system health issues.', 'For example, a dip at \n222\n shows a relatively sudden drop in efficiency performance that can be indicative of a problem.', 'In some embodiments operations can be halted if the deviation is sufficiently severe.', 'The actual performance plot in this case does improve and appear to return to a normal value, so in that case the system can conclude that there were transient conditions that have been resolved and there are no system health issues.', 'Later in the plot, however, the relative slope of the plots at \n224\n and \n226\n appear to be diverting.', 'This can be an indicator of a slower, steadier decline in efficiency.', 'In many embodiments there are more factors at play, such as perhaps a genset is being run outside of an optimal power band for reasons beyond the purview of a system health monitoring system such as this.', 'In these cases, perhaps there is a good reason for the decline.', 'In any case, however, the decline can be monitored and documented.', 'The vertical axis of the graph is labeled generically “efficiency parameter.”', 'In some embodiments this can be an amount of fuel required to perform a given task.', 'In other embodiments the amount of fuel is held constant and the performance (e.g. torque) can be monitored for a decline.', 'In still other embodiments a combination of fuel and performance can be used to plot the efficiency parameter against time.', 'However the efficiency is defined, the systems and methods of the present disclosure allow a novel, useful way to monitor system health, to provide sufficient power to meet the demands of the modern oil rig, and to avoid wasteful, costly, avoidable fuel expenditures associated with idling extra gensets.', 'In some embodiments the drill plan can be written using the available number of gensets as a constraint.', 'The systems and methods of the present disclosure can be used to set certain parameters and scheduling for a rig.', 'For example, a certain well can be desired to operate using only three gensets.', 'The scheduling from day one can be written in a way that optimizes the use of these gensets without requiring a fourth genset.', 'There is greater control and flexibility provided by the systems and methods of the present disclosure than were previously available.', 'The foregoing disclosure hereby enables a person of ordinary skill in the art to make and use the disclosed systems without undue experimentation.', 'Certain examples are given to for purposes of explanation and are not given in a limiting manner.']

['1.', 'A system for managing fuel expenditures at an oil rig, comprising:\na plurality of gensets, each genset comprising a prime mover and an alternator;\na load operatively coupled to one or more of the plurality of gensets, wherein the load is configured to: receive power from the one or more of the plurality of gensets; receive power from a power storage unit; and execute one or more tasks at the oil rig;\na power storage unit operatively coupled to one or more of the plurality of gensets and to the load, wherein the power storage unit is configured to: receive power from the one or more of the plurality of gensets coupled to the power storage unit; store the power; and deliver the stored power to the load;\na controller operatively coupled to the plurality of gensets the power storage unit, and the load, wherein the controller is configured to: monitor power consumption by the load; monitor a power capacity of the power storage unit; and monitor an operating status of the plurality of gensets; and\na database configured to store a drill plan detailing the one or more tasks including detailing expected power consumption and duration for the one or more tasks, wherein the controller is further configured to: calculate a total expected power consumption to execute at least one task of the one or more tasks during a first time period based on the stored drill plan; identify a number of gensets to provide power equal to the total expected power consumption to execute the at least one task during the first time period; and ensure the total expected power is provided to the load during the first time period by: when the number of gensets to provide the total expected power consumption is less than a number of active gensets: turning on one or more additional gensets at or before the first time period; instructing the power storage unit to deliver stored power to the load at the first time period; or a combination thereof; and when the number of gensets to provide the total expected power consumption is greater than the number of active gensets: shutting down one or more of the active gensets at or before the first time period; instructing one or more of the plurality of gensets to deliver excess power to the power storage unit at the first time period; or a combination thereof.', '2.', 'The system of claim 1, wherein the power storage unit is configured to receive regenerated power from the plurality of gensets.', '3.', 'The system of claim 1, wherein the power storage unit comprises at least one of a capacitor, a battery, a hydraulic energy storage unit, a pneumatic energy storage unit, or a flywheel.', '4.', 'The system of claim 1, wherein the controller is further configured to:\ncalculate a second total expected power consumption to execute at least one task of the one or more tasks during a second time period;\nidentify a number of gensets to provide the second total expected power to execute the at least one task during the second time period; and to\nensure the second total expected power during the second time period.', '5.', 'The system of claim 1, wherein the controller is further configured to, when the number of gensets to provide the total expected power consumption is less than the number of active gensets, prioritize instructing the power storage unit to deliver the stored power to the load over turning on the one or more additional gensets.', '6.', 'The system of claim 1, wherein the load comprises at least one of: a top drive, a drawworks, or a mud pump.', '7.', 'The system of claim 1, wherein the controller is further configured to:\ncalculate a difference between the total expected power consumption and an available power production capacity from the number of active gensets as headroom power; and\ninstruct one or more of the active gensets to deliver the headroom power to the power storage unit.', '8.', 'The system of claim 7, wherein the controller is further configured to verify there is available storage capacity in the power storage unit.', '9.', 'The system of claim 1, further comprising a system health monitoring component configured to monitor health of the system by:\nmeasuring a power consumption of a task of the one or more tasks executed by the load and powered by a genset of the plurality of gensets; and\ncomparing the power consumption of the task to the expected power consumption for the task in the drill plan.', '10.', 'The system of claim 1, wherein:\nthe controller being configured to monitor power consumption by the load includes the controller being configured to monitor power consumption of a task; and\nthe system further comprises a power prediction component configured to compare the power consumption of the task to the expected power consumption for the task in the drill plan; and update the drill plan based on the comparison between the monitored power consumption and the expected power consumption for the task.', '11.', 'The system of claim 10, wherein the drill plan is generated by predictive mathematical models, and wherein updating the drill plan comprises updating the predictive mathematical models.', '12.', 'The system of claim 1, further comprising a genset health monitoring component configured to monitor health of a genset of the plurality of gensets by:\nmeasuring power output of the genset;\naccessing the drill plan for an expected value of power output of the genset; and\ncomparing the power output of the genset to the expected value of power output of the genset.', '13.', 'A method for optimizing an operating parameter of gensets at an oil rig, the method comprising:\naccessing a rig plan including data describing times and power consumption loads associated with a plurality of tasks at the oil rig;\nfor a given time period, calculate a total expected power consumption during a first time period by summing the power consumption loads for one or more tasks of the plurality of tasks scheduled during the first time period in the rig plan;\ncalculating a number of gensets to provide power equal to the total expected power consumption for the tasks scheduled during the first time period and a predetermined quantity of headroom power in addition to the summed power consumption loads;\nensuring that the number of gensets are running at the first time;\ndiverting the headroom power to a power storage unit; and\naccessing the headroom power stored in the power storage unit when the power consumption for the tasks is greater than the total expected power consumption.\n\n\n\n\n\n\n14.', 'The system of claim 1, wherein the controller is further configured to, when the number of gensets to provide the total expected power consumption is greater than the number of active gensets, determine whether to reduce the load.', '15.', 'The system of claim 14, wherein the controller is further configured to:\ncalculate a cost associated with at least one of: a cost of increased rig operation time associated with reducing the load, a fuel cost of one or more idle gensets of the plurality of gensets, a fuel cost associated with shutting down and starting up one or more gensets of the plurality of gensets, an expected duration that the number of gensets to provide the total expected power is less than the number of active gensets, an expected duration that the number of gensets to provide the total expected power is greater than the number of active gensets, or a combination thereof; and\ndetermine, based on the calculated cost, whether to turn on turn on the one or more additional gensets at or before the first time period, instructing the power storage unit to deliver stored power to the load at the first time period, shut down the one or more of the active gensets at or before the first time period, or instruct the one or more of the gensets to deliver excess power to power storage unit at the first time period.', '16.', 'The method of claim 13, wherein the operating parameter comprises at least one of: fuel consumption, load, wear, maintenance, number of startup cycles, or number of shutdown cycles.', '17.', 'The method of claim 13, further comprising calculating a startup cost or a shutdown cost associated with a power cycle for a genset.', '18.', 'The method of claim 13, further comprising:\nmonitoring a power consumption associated with a specific task;\ncomparing the monitored power consumption to the power consumption load in the rig plan for the specific task; and\nissuing an alarm if the monitored power consumption associated with the specific task differs from the power consumption load in the rig plan for the specific task by an amount greater than a predetermined threshold.', '19.', 'The method of claim 13, further comprising:\naccessing the rig plan data for an upcoming time and an associated power consumption load for the upcoming time; and\ncomparing the power consumption loads for the given time and the upcoming time.', '20.', 'The method of claim 19, further comprising, if the power consumption loads for the given time and the upcoming time differ by more than the headroom power, starting up an additional genset.', '21.', 'The method of claim 19, further comprising, if the power consumption loads for the given time and the upcoming time differ by more than the headroom power, assessing whether or not there is sufficient power stored in the power storage unit to provide the power more than the headroom power.', '22.', 'A system for managing a plurality of gensets at an oil rig, the system comprising:\nthe plurality of gensets configured to consume fuel and deliver power;\na load configured to receive power from the plurality of gensets, the load defining a drilling operation at the oil rig, wherein power consumption and scheduling data for the load is described in a drill plan;\na power storage unit configured to: receive power from at least one of the plurality of gensets; store the power; and deliver the stored power to the load;\na computational unit configured to: monitor the plurality of gensets; monitor the load; access the drill plan; determine, based on the drill plan, a total expected power consumption during a first time period during the drilling operation; monitor the power storage unit for capacity and availability of power; ensure the total expected power consumption is provided to the load during the first time period by: when a number of gensets to provide the total expected power consumption is greater than a number of active gensets: shutting down one or more of the active gensets at or before the first time period; diverting excess power to the power storage unit during the first time period; or a combination thereof; and when the number of gensets to provide the total expected power consumption is less than the number of active gensets: turning on one or more additional gensets at or before the first time period; accessing power stored in the power storage unit during the first time period; or a combination thereof.', '23.', 'The system of claim 22, wherein the plurality of gensets comprise diesel engines capable of providing at least one megawatt of power.', '24.', 'The system of claim 22, wherein the computation unit is configured to, when the number of gensets to provide the total expected power consumption is less than the number of active gensets, prioritize accessing power stored in the power storage unit over turning on the one or more additional gensets.', '25.', 'The system of claim 22, further comprising a system health monitoring component configured to:\nmonitor actual power consumed for specific tasks in the load;\ncompare the actual power consumed to corresponding data in the drill plan; and\nnotify an operator when the actual power consumed differs from the corresponding data in the drill plan by more than a predetermined tolerance value.']

['FIG.', '1 is a graph of power and time according to embodiments of the present disclosure.', '; FIG.', '2 shows a relationship between genset, load, and storage unit according to embodiments of the present disclosure.;', 'FIG. 3 is a graph of expected and actual power delivery according to embodiments.; FIG. 4 is a flowchart of a method for operating a plurality of gensets and one or more storage units with a controller according to embodiments of the present disclosure.', '; FIG. 5 is another flowchart for of a method of operating genset(s), controllers, and loads to improve efficiency according to embodiments of the present disclosure.; FIG.', '6 is another flowchart diagram of a method for operating one or more gensets to provide power to a load with increased efficiency and reduced idling time according to embodiments of the present disclosure.; FIG. 7 is a graph of expected efficiency performance of a genset or associated systems against actual efficiency performance to identify potential system health issues according to embodiments of the present disclosure.; FIG.', '2 shows a relationship between genset 130, load 132, and storage 134 according to embodiments of the present disclosure.', 'Recall the relationship between headroom and available power shown in FIG.', '1 as well.', 'The genset 130 provides power to the load 132.', 'The genset 130 can also be configured to provide power to a storage unit 134 which can consist of a battery, a capacitor, or any other suitable power storage unit.', 'Excess power from the genset 130 can be diverted to the storage unit and stored for later use.', 'In some embodiments the storage unit 134 can supply the power required during a certain time when demand for power exceeds the available power provided by a number of gensets.', 'There is a fuel cost associated with starting a genset, and if a power demand can be met by tapping into stored power it could result in large efficiency gains.', 'The gensets and their available power can be considered in discrete intervals, and this effect is of even more importance because the efficiency of the gensets is highest near the maximum operating capacity.', 'On the other hand, slowing down an oil rig operation because there is insufficient power available is costly.', 'There is a desirable balance between reducing idle time and providing as near to exactly the power required.; FIG.', '4 is a flowchart of a method 150 for operating a plurality of gensets and one or more storage units with a controller according to embodiments of the present disclosure.', 'At 152 the method initiates either at the request of an operator or automatically in response to a signal, a predetermined time period, or the occurrence of some other operation or event at the rig.', 'The method 150 can be carried out locally by a controller or can be remotely operated over communication lines such as WIFI or the internet.', 'At 154 the method includes obtaining a predicted load data for an upcoming time period.', 'Such data can be part of a drill plan stored on a local database or accessed over long-range communication lines.', 'The data can include a list of tasks to be executed during the time and an associated power requirement for each.', 'The time period can be any time period long or short.', 'At 156 it is calculated how many gensets will be required to deliver the required power.', 'In some embodiments this is as simple as summing the power required by the tasks to be executed.', 'In other embodiments the tasks interrelate in such a way that the power requirements for two tasks together is different than it would be for either alone.', '; FIG. 5 is another flowchart for of a method 170 of operating genset(s), controllers, and loads to improve efficiency according to embodiments of the present disclosure.', 'At 172 the method is initiated.', 'At 174 a decision is made based on the drill plan data and the current load on the genset(s) whether or not a peak or trough is coming.', 'The determination can be based on a difference between the current power consumption and the expected upcoming power consumption.', 'If the difference A is greater than a threshold, larger indicates a peak, and smaller indicates a trough.', 'If neither is determined, the method can continue periodic checks.', 'When a peak is identified at 176 a calculation is made to determine a number of additional gensets that will be required to meet the demand.', 'In some embodiments this determination is made by summing the power requirements of all the expected tasks and comparing it against the power delivery as shown in FIG.', '1.', 'At 178 the method includes determining whether or not there are sufficient gensets available, which can include any storage units which may be tapped, to meet the demand.', 'At 180 if there are insufficient gensets and storage units available, an alarm is issued.', 'If there are sufficient gensets available at 182 they are initiated.', 'The method continues at 184 by repeating or terminating.; FIG.', '6 is another flowchart diagram of a method 200 for operating one or more gensets to provide power to a load with increased efficiency and reduced idling time according to embodiments of the present disclosure.', 'At 202 the method initiates.', 'At 204 a controller or other suitable computing apparatus identifies upcoming increases in load.', 'The information for the controller to make this identification comes from a drill plan that is stored in a database either locally or remotely.', 'The controller can compare the current load against the planned load.', 'At 206 the controller can determine whether or not the increased load will require initiating an additional genset above the number that are currently operating.', 'If not, the method can repeat or terminate at 214.', 'If so, the controller can then at 208 look to see if there are available reductions in other loads that may allow the upcoming demand to be met without requiring the use of an additional genset.', 'If not, the method passes to repeat or terminate at 214.', 'If there are other loads that may be reduced, at 210 the controller can query whether or not the reductions will provide sufficient energy to avoid starting another genset.', 'If not the method passes to repeat/terminate at 214.', 'If there are sufficient loads that can be reduced, either by postponing, delaying, diminishing, or otherwise redistributing the load to avoid needing another genset, at 212 the controller initiates the reduction.', 'Afterward the method can repeat/terminate at 214.; FIG.', '7 is a graph of expected efficiency performance of a genset or associated systems against actual efficiency performance to identify potential system health issues according to embodiments of the present disclosure.', 'There are two plots: expected performance, and actual performance.', 'The two lines are offset by an offset 220 to more clearly illustrate the differences and similarities of the two plots.', 'All equipment will deteriorate at one rate or another.', 'Much of the equipment used with the present disclosure including the gensets and the machine and systems that make up the load has a known or expected deterioration rate.', 'This can be based on track record or empirical monitoring.', 'Actual deterioration can be measured and compared against the expected deterioration rate and if there is a deviation great enough, an alarm can be issued to alert an operator of potential system health issues.', 'For example, a dip at 222 shows a relatively sudden drop in efficiency performance that can be indicative of a problem.', 'In some embodiments operations can be halted if the deviation is sufficiently severe.', 'The actual performance plot in this case does improve and appear to return to a normal value, so in that case the system can conclude that there were transient conditions that have been resolved and there are no system health issues.', 'Later in the plot, however, the relative slope of the plots at 224 and 226 appear to be diverting.', 'This can be an indicator of a slower, steadier decline in efficiency.', 'In many embodiments there are more factors at play, such as perhaps a genset is being run outside of an optimal power band for reasons beyond the purview of a system health monitoring system such as this.', 'In these cases, perhaps there is a good reason for the decline.', 'In any case, however, the decline can be monitored and documented.']

US11905785

Pressure control systems and methods

Oct 15, 2020

Vikas Rakhunde

SCHLUMBERGER TECHNOLOGY CORPORATION

Search Report and Written Opinion of International Patent Application No. PCT/US2020/055692 dated Jan. 29, 2021; 9 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2020/055692 dated Apr. 28, 2022, 6 pages.

4285408; August 25, 1981; Franks, Jr.; 4466487; August 21, 1984; Taylor, Jr.; 4550789; November 5, 1985; Crow; 6634427; October 21, 2003; Turner; 7493949; February 24, 2009; Baird; 8955619; February 17, 2015; Tilton; 10316594; June 11, 2019; Shearer; 20010050185; December 13, 2001; Calder et al.; 20150068769; March 12, 2015; Xiao et al.; 20190234166; August 1, 2019; Strachan

Foreign Citations not found.

['A system an annular sleeve configured to be positioned in an annular space between a first annular component and a second annular component of a drilling system.', 'The annular sleeve includes a radially-inner annular surface and a radially-outer annular surface.', 'The annular sleeve also includes a first annular seal element coupled to the radially-inner annular surface and configured to seal against the first annular component, a second annular seal element coupled to the radially-outer annular surface and configured to seal against the second annular component, and one or more axially-extending passageways extending from a first end to a second end of the annular sleeve.', 'The annular sleeve is configured to direct a fluid flow through the one or more axially-extending passageways across the annular sleeve.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application is a National Stage Entry of International Application No. PCT/US2020/055692, filed Oct. 15, 2020, which claims priority to and the benefit of U.S. Provisional Application No. 62/915,042, entitled “PRESSURE CONTROL SYSTEMS AND METHODS,” filed Oct. 15, 2019, which is hereby incorporated by reference in its entirety for all purposes.', 'BACKGROUND\n \nThis section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present disclosure, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'Natural resources, such as oil and gas, are used as fuel to power vehicles, heat homes, and generate electricity, in addition to various other uses.', 'Once a desired resource is discovered below the surface of the earth, drilling and production systems are often employed to access and extract the resource.', 'These systems may be located onshore or offshore depending on the location of the desired resource.', 'Further, such systems may include a wide variety of components, such as various casings, fluid conduits, tools, and the like, that facilitate extraction of the resource from a well during drilling or extraction operations.', 'In some typical systems, a drill string may extend through a wellhead assembly mounted to the well and may be used to form (e.g., drill) the well.', 'The well may be lined with casing, which may generally stabilize the well and/or isolate fluids within the wellbore from surrounding subterranean formations.', 'During drilling operations, drilling mud may be directed into the well through the drill string and may exit the wellbore via an annular space between the drill string and the casing.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious features, aspects, and advantages of the present disclosure will become better understood when the following detailed description is read with reference to the accompanying figures in which like characters represent like parts throughout the figures, wherein:\n \nFIG.', '1\n is a schematic diagram of an offshore system, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\n is a cross-sectional side view of an annular sleeve that may be used in the offshore system of \nFIG.', '1\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '3\n is a top view of a flange of the annular sleeve of \nFIG.', '2\n; and\n \nFIG.', '4\n is a cross-sectional side view of an annular sleeve having a rotating seal carrier that may be used in the offshore system of \nFIG.', '1\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '5\n is schematic diagram of another offshore system in which an annular sleeve is coupled to a stack assembly, in accordance with an embodiment of the present disclosure;\n \nFIG.', '6\n is a flow diagram of a method of operating a drilling and production system having an annular sleeve, in accordance with an embodiment of the present disclosure; and\n \nFIG.', '7\n is a side view of another offshore system that includes a casing feeder device and in which an annular sleeve is coupled to a stack assembly, in accordance with an embodiment of the present disclosure.', 'DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS\n \nOne or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only exemplary of the present disclosure.', 'Additionally, in an effort to provide a concise description of these exemplary embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'The present embodiments are generally directed to systems and methods that facilitate drilling operations.', 'Certain embodiments include an annular sleeve (e.g., isolation sleeve) configured to be positioned within an annular space defined between two components of a drilling and production system, such as an annular space between a drill string and a casing.', 'The annular sleeve may include a radially-inner wall (e.g., inner annular wall) and a radially-outer wall (e.g., outer annular wall).', 'The radially-inner wall may be configured to seal against the drill string (e.g., via an annular seal), and the radially-outer wall may be configured to seal against the casing (e.g., via an annular seal).', 'One or more passageways (e.g., axially-extending passageways, channels, or flow paths) extend from a first end to a second end of the annular sleeve.', 'Thus, fluid from the wellbore may be directed into the one or more passageways and may flow through the annular sleeve via the one or more passageways.', 'At the first end of the annular sleeve, the one or more passageways may be coupled to fluid conduits, which are in turn coupled to a fluid processing system, for example.', 'The annular sleeve may be utilized in any of a variety of drilling and production systems.', 'For example, in certain embodiments, the annular sleeve may be utilized within an offshore drilling and production system that is configured to assemble the casing (e.g., to form one or more casing components or a casing material into a solid tubular structure) at a subsea location and to install the casing within the wellbore during the drilling process (e.g., as the drill string drills the well).', 'In some such cases, the second end of the annular sleeve is positioned within an assembled portion of the casing (e.g., a solid tubular portion of the casing), and the first end of the annular sleeve extends from and is positioned above (e.g., along an axial axis)', 'the assembled portion of the casing.', 'Additionally or alternatively, in certain embodiments, the annular sleeve may be utilized within a drilling and production system (e.g., riser-less drilling system) that does not include a riser extending from a drilling rig at a sea surface toward the wellhead assembly to support and to circumferentially surround the drill string.', 'The annular sleeve disclosed herein may facilitate fluid flow out of the wellbore and/or may facilitate pressure control within the wellbore during various drilling operations, such as subsea casing assembly, casing installation, and/or riser-less drilling operations, and may enable certain steps of the well completion process to be carried out simultaneously and/or reduce the time associated with completing the well, for example.', 'In some embodiments, the annular sleeve may be utilized during maintenance operations.', 'While certain examples provided herein include offshore drilling and production systems that are configured to assemble casing at a subsea location, it should be understood that the annular sleeve may be adapted for use within any of a variety of offshore or onshore drilling and production systems, including drilling and production systems that use pre-formed casing sections (e.g., pre-formed into a tubular structure at the sea surface).', 'In some such embodiments, the second end of the annular sleeve may be positioned within the casing, and the first end of the annular sleeve extends from and is positioned above (e.g., along an axial axis)', 'the casing to facilitate fluid flow from the wellbore to a fluid processing system.', 'Furthermore, while certain examples provided herein include riser-less drilling and production systems, it should be understood that the annular sleeve may be adapted for use within drilling and production systems that include risers.', 'Indeed, the annular sleeve may be adapted for use within an annular space between the drill string and the riser or within any of a variety of annular spaces within drilling and production systems, such as between a wireline or any tubular and the casing, to isolate and/or to direct fluid flow during drilling operations, maintenance operations, or the like, for example.', 'With the foregoing in mind, \nFIG.', '1\n is an embodiment of a portion of an offshore system \n10\n configured to extract oil, natural gas, or other natural resources from a subsea mineral reservoir \n12\n below a sea floor \n14\n.', 'As shown, a wellhead assembly \n16\n may be positioned at an interface between a wellbore \n18\n and the sea floor \n14\n, and a stack assembly \n20\n having various components, such as one or more annular blowout preventers (BOP) \n21\n and one or more ram BOPS \n23\n, to control pressure during drilling operations may be positioned adjacent to the wellhead assembly \n16\n.', 'As shown, a drill string \n22\n (e.g., tubular string, production tubing string, drill pipe) extends from a location above the sea floor \n14\n (e.g., from a platform or drilling rig located at a sea surface) and into the wellbore \n18\n.', 'A tool \n24\n (e.g., drill bit) is positioned at one end of the drill string \n22\n to form (e.g., drill) the wellbore \n18\n.', 'In certain embodiments, the drill string \n22\n and the tool \n24\n may rotate together to facilitate formation of the wellbore \n18\n.', 'However, in some embodiments, the drill string \n22\n may not rotate, but rather, the drill string \n22\n may be pushed downward into the wellbore \n18\n as the tool \n24\n rotates relative to the drill string \n22\n to form the wellbore \n18\n.', 'In some embodiments, the drill string \n22\n may extend to the platform or drilling rig located at the sea surface, and vertical movement and/or rotation of the drill string \n22\n and/or the tool \n24\n may be controlled at the platform or drilling rig.', 'In certain embodiments, the drill string \n22\n may not extend to the platform or drilling rig located at the sea surface, but rather may terminate at a subsea location.', 'In some such cases, vertical movement and/or rotation of the drill string \n22\n and/or the tool \n24\n may be controlled at a subsea location (e.g., via a subsea electronic control system, a remotely operated vehicle', '[ROV], an autonomously operated vehicle [AOV], or any combination thereof).', 'In the illustrated embodiment, the offshore system \n10\n is a riser-less system and does not include a riser that circumferentially surrounds the drill string \n22\n below the platform or drilling rig at the sea surface.', 'Thus, fluid from the wellbore \n18\n does not travel to the platform or drilling rig at the sea surface via an annular space between the drill string \n22\n and a riser, as in certain other drilling and production systems.', 'As shown, a casing \n26\n (e.g., annular casing) is installed within the wellbore \n18\n to stabilize the wellbore \n18\n and/or to isolate the wellbore \n18\n from the surrounding subterranean formations.', 'In certain embodiments, the casing \n26\n may be assembled (e.g., formed into a solid tubular structure from one or more casing components or material) at a subsea location.', 'For example, the illustrated embodiment includes a casing assembly device \n30\n that is configured to assemble the casing \n26\n on-site at the sea floor \n14\n.', 'Accordingly, the casing assembly device \n30\n also may be referred to as an on-site or subsea casing assembly device \n30\n.', 'The casing assembly device \n30\n may be configured to assemble the casing \n26\n via any suitable technique on-site at the sea floor \n14\n.', 'For example, the casing assembly device \n30\n may include a support structure, a power source (e.g., electrical power source, fuel, etc.), a heat source (e.g., laser), a drive system, a control system (e.g., electronic controller), a monitoring system (e.g., monitor with one or more sensors), and/or other elements.', 'In some embodiments, the casing assembly device \n30\n may be configured to shape, weld, and/or fuse one or more annular or non-annular casing components or materials into a solid tubular structure (e.g., the casing \n26\n) that is configured to be inserted into the wellbore \n18\n to stabilize the wellbore \n18\n and/or to isolate the wellbore \n18\n from surrounding subterranean formations.', 'In some embodiments, the casing assembly device \n30\n, or another device within the offshore system \n10\n, may drive (e.g., using the drive system) the casing \n26\n into the wellbore \n18\n as the casing \n26\n is assembled and/or as the wellbore \n18\n is drilled.', 'Thus, in some embodiments, the casing \n26\n may increase in length (e.g., via assembly of additional casing \n26\n at the casing assembly device \n30\n) and the assembled casing \n26\n may be driven into the wellbore \n18\n as the wellbore \n18\n is drilled to enable the casing \n26\n to line the wellbore \n18\n.', 'In certain embodiments, the assembled casing \n26\n may be a continuous tubular structure extending between the wellbore \n18\n (e.g., a bottom of the wellbore \n18\n) and the casing assembly device \n30\n.', 'During drilling operations, drilling mud is pumped through the drill string \n22\n into the wellbore \n18\n to drive cuttings out of the wellbore \n18\n.', 'The drilling mud, cuttings, and/or other material may exit the wellbore \n18\n via an annular space \n32\n (e.g., annulus) between the drill string \n22\n and the casing \n26\n.', 'In the illustrated embodiment, an annular sleeve \n34\n (e.g., isolation sleeve) is positioned within the annular space \n32\n.', 'In some embodiments, the annular sleeve \n34\n may be coupled to and supported by the support structure of the casing assembly device \n30\n and/or the annular sleeve \n34\n may extend axially through the casing assembly device \n30\n such that one end of the annular sleeve is positioned axially below the casing assembly device \n30\n and one end of the annular sleeve \n34\n is positioned axially above the casing assembly device \n30\n.', 'As discussed in more detail below, the annular sleeve \n34\n may seal against the drill string \n22\n and the casing \n26\n, and one or more passageways (e.g., axially-extending passageways, channels, or flow paths) extend through the annular sleeve \n34\n to facilitate fluid flow from the wellbore \n18\n into fluid conduits \n36\n, which may in turn extend to a fluid processing system \n38\n (e.g., shale shaker, chemical treatment system, filter, mud pit, pump, conveyor, etc.) positioned at a subsea location (e.g., coupled to a subsea platform supported by the sea floor \n14\n) or a surface location (e.g., on a platform or drilling rig at a sea surface).', 'The annular sleeve \n34\n may isolate the fluid flow from the casing assembly device \n30\n, thereby protecting and/or sealing the casing assembly device \n30\n from the fluid.', 'In certain embodiments, the annular sleeve \n34\n may enable the fluid to flow to the fluid processing system \n38\n and/or block escape of the fluid into the casing assembly device \n30\n and/or the environment.', 'When the wellbore \n18\n reaches the subsea mineral reservoir \n12\n, oil, natural gas, or other natural resources may flow from the subsea mineral reservoir \n12\n through the annular space \n32\n.', 'In some embodiments, the annular sleeve \n34\n may be configured to remain in place after the wellbore \n18\n reaches the subsea mineral reservoir \n12\n, after the casing \n26\n is fully assembled and installed, and/or during extraction operations, and the annular sleeve \n34\n may facilitate flow of the natural resources toward a suitable fluid processing system, such as the fluid processing system \n38\n, and/or may facilitate pressure control within the wellbore \n18\n.', 'In some embodiments, the annular sleeve \n34\n is configured to be removed from the annular space \n32\n after the wellbore \n18\n reaches the subsea mineral reservoir \n12\n, after the casing \n26\n is fully assembled and installed, during extraction operations, and/or after completion of maintenance operations, for example.', 'To facilitate discussion, the offshore system \n10\n and the components therein may be described with reference to an axial axis or direction \n40\n, a radial axis or direction \n42\n, and a circumferential axis or direction \n44\n.', 'In certain embodiments, the offshore system \n10\n is configured for managed pressure drilling operations in which the offshore system \n10\n includes components to regulate the wellbore pressure by controlling the flow of mud through the drill string \n22\n and the return of fluid through the annular space \n32\n and the annular sleeve \n34\n.', 'As noted above, it should be understood that the disclosed annular sleeve \n34\n may be incorporated within any of a variety of offshore or onshore drilling and production systems.', 'For example, the annular sleeve \n34\n may be utilized in drilling and production systems that are configured for conventional drilling operations that maintain hydrostatic pressure within the wellbore \n18\n.', 'Furthermore, the annular sleeve \n34\n may be adapted for use within drilling and production systems that utilize pre-formed casing sections, within drilling and production systems that utilize risers, and/or within other annular spaces in drilling and production systems, such as between a wireline or any tubular and the casing, to isolate and/or to direct fluid flow during drilling operations, maintenance operations, or the like, for example.\n \nFIG.', '2\n is a cross-sectional side view of an embodiment of the annular sleeve \n34\n.', 'As shown, the annular sleeve \n34\n extends between a first end \n46\n (e.g., proximal end) and a second end \n48\n (e.g., distal end), and includes a flange \n50\n (e.g., annular flange or proximal portion) coupled to a body \n52\n (e.g., annular body or distal portion) via fasteners \n54\n (e.g., threaded fasteners, such as bolts).', 'During drilling operations, at least the second end \n48\n of the annular sleeve \n34\n is positioned within the casing \n26\n (e.g., the assembled portion of the casing \n26\n having a solid tubular structure).', 'The body \n52\n of the annular sleeve \n34\n includes a radially-inner wall \n56\n (e.g., inner annular wall) and a radially-outer wall \n58\n (e.g., outer annular wall).', 'As shown, passageways \n60\n (e.g., axially-extending passageways, channels, or flow paths) extend through the body \n52\n of the annular sleeve \n34\n and are in fluid communication with the annular space \n32\n and the wellbore \n18\n.', 'In the illustrated embodiment, the flange \n50\n also includes a radially-inner wall \n62\n (e.g., annular wall) and a radially-outer wall \n64\n (e.g., annular wall).', 'As shown, passageways \n66\n (e.g., axially-extending passageways, channels, or flow paths) extend through the flange \n50\n of the annular sleeve \n34\n and are in fluid communication with the passageways \n60\n of the body \n52\n of the annular sleeve \n34\n.', 'The passageways \n60\n and the passageways \n68\n may be circumferentially spaced about the annular sleeve \n34\n.', 'In certain embodiments, the number of passageways \n60\n may be equivalent to the number of passageways \n66\n, and each passageway \n60\n may align with a respective one of the passageways \n66\n to enable fluid flow through the annular sleeve \n34\n.', 'In some embodiments, the annular sleeve \n34\n may include a first number of passageways \n60\n and a second number of passageways \n66\n, and the first number may be different (e.g., greater than or less than) the second number.', 'In some such cases, one or more connecting passageways \n68\n (e.g., radially-extending and/or circumferentially-extending passageways) may be formed in at least one of the flange \n50\n or the body \n52\n to couple some or all of the passageways \n60\n in the body \n52\n to some or all of the passageways \n66\n in the flange \n50\n.', 'For example, in the embodiment shown in \nFIGS. \n2\n and \n3\n, two passageways \n60\n are formed in the body \n52\n, four passageways \n66\n are formed in the flange \n50\n, and four connecting passageways \n68\n are formed in a bottom surface \n67\n (e.g., axially-facing surface) of the flange \n50\n.', 'The connecting passageways \n68\n extend circumferentially about the flange \n50\n and form a generally annular fluid flow path that fluidly couples the two passageways \n60\n within the body \n52\n to the four passageways \n66\n within the flange \n50\n.', 'As shown, one or more seals \n65\n (e.g., annular seals or gaskets) may be provided between the flange \n50\n and the body \n52\n to block fluid from escaping from the passageways \n60\n, \n66\n, \n68\n of the annular sleeve \n34\n at the interface between the flange \n50\n and the body \n52\n.', 'FIG.', '3\n illustrates a top view of an embodiment of the flange \n50\n of the annular sleeve \n34\n having the passageways \n66\n formed in the flange \n50\n and the passageways \n68\n extending circumferentially about the flange \n50\n between the passageways \n66\n.', 'The illustrated embodiment includes two passageways \n60\n positioned at diametrically opposed locations of the body \n52\n of the annular sleeve \n34\n and four passageways \n66\n evenly spaced about the flange \n50\n of the annular sleeve.', 'However, it should be understood that any suitable number (e.g., 1, 2, 3, 4, 5, 6, 7, 8, or more) passageways \n60\n may be provided at discrete locations about the circumference of the body \n52\n of the annular sleeve \n34\n, and any suitable number (e.g., 1, 2, 3, 4, 5, 6, 7, 8, or more) passageways \n66\n may be provided at discrete locations about the circumference of the flange \n50\n of the annular sleeve \n34\n.', 'Furthermore, the passageways \n60\n, \n66\n may have any suitable cross-sectional shape (e.g., circular) and/or may extend in the circumferential direction \n44\n about some or all of the body \n52\n or the flange \n50\n, respectively, of the annular sleeve \n34\n.', 'For example, in some embodiments, one or both of the passageways \n60\n, \n68\n may be an annular passageway.', 'In the illustrated embodiment, the radially-inner wall \n56\n of the body \n52\n of the annular sleeve \n34\n is configured to seal against the drill string \n22\n via an inner seal \n70\n (e.g., annular seal or drill string seal), and the radially-outer wall \n58\n of the body \n52\n of the annular sleeve \n34\n is configured to seal against the casing \n26\n via an outer seal \n72\n (e.g., annular seal or casing seal).', 'As shown, the inner seal \n70\n is supported within a cavity \n74\n (e.g., annular cavity) formed in the radially-inner wall \n56\n of the body \n52\n of the annular sleeve \n34\n, and the outer seal \n72\n is supported within a cavity \n78\n (e.g., annular cavity) formed in the radially-outer wall \n58\n of the body \n52\n of the annular sleeve \n34\n.', 'Thus, fluid from the annular space \n32\n is blocked from flowing between the radially-inner wall \n56\n and the drill string \n22\n and between the radially-outer wall \n58\n and the casing \n26\n, and the fluid from the annular space \n32\n is directed into the passageways \n60\n of the body \n52\n of the annular sleeve \n34\n.', 'In some embodiments, the drill string \n22\n and/or the casing \n26\n may move relative to the annular sleeve \n34\n without breaking the fluid seal provided by the inner seal \n70\n and/or the outer seal \n72\n, respectively.', 'For example, the inner seal \n70\n may be configured to maintain the seal between the drill string \n22\n and the annular sleeve \n34\n while the drill string \n22\n moves in the axial direction \n40\n, and/or the outer seal \n72\n may be configured to maintain the seal between the casing \n26\n and the annular sleeve \n34\n while the casing \n26\n moves in the axial direction \n40\n, such as during drilling operations and/or during casing assembly.', 'As shown, the inner seal \n70\n includes a first portion \n82\n that is supported within the cavity \n74\n and a second portion \n84\n (e.g., axially-extending portion) that extends from the first portion \n82\n and along the drill string \n22\n.', 'Similarly, in the illustrated embodiment, the outer seal \n72\n includes a first portion \n86\n that is supported within the cavity \n78\n and a second portion \n88\n (e.g., axially-extending portion) that extends from the first portion \n86\n and along the casing \n26\n.', 'In some embodiments, the inner seal \n70\n may be undersized (e.g., an inner diameter of the inner seal \n70\n may be 1, 2, 3, 4, 5, 10, 15, 20, 25, or more percent less than an outer diameter of the drill string \n22\n prior to placement of the drill string \n22\n through the inner seal \n70\n).', 'Similarly, in some embodiments, the outer seal \n72\n may be oversized (e.g., an outer diameter of the outer seal \n72\n may be 1, 2, 3, 4, 5, 10, 15, 20, 25, or more percent greater than an inner diameter of the casing \n26\n prior to placement of the outer seal \n72\n within the casing \n26\n).', 'The inner seal \n70\n and the outer seal \n72\n may be formed from any suitable materials, such as elastomer, rubber, metal, or any combination thereof.', 'At the first end \n46\n of the annular sleeve \n34\n, the passageways \n66\n may be fluidly coupled to the fluid conduits \n36\n, such as via respective stabs \n90\n (e.g., annular fluid-conveying stabs or axial stab connectors).', 'In the illustrated embodiment, each stab \n90\n is supported within a respective housing \n92\n (e.g., annular housing or locking dog) that includes a locking groove \n94\n that enables the housing \n92\n to couple (e.g., lock) to the annular sleeve \n34\n.', 'In some embodiments, one or more seals \n96\n (e.g., annular seals) may be provided between each housing \n92\n and the flange \n50\n of the annular sleeve \n34\n.', 'In certain embodiments, the flange \n50\n may include one or more latching grooves \n98\n (e.g., circumferentially-extending grooves or annular grooves) in the radially-outer wall \n64\n to enable the annular sleeve \n34\n to be coupled to (e.g., engaged by) a support structure, such as the support structure of a casing assembly device, a stack assembly, a frame or a platform supported or positioned on the sea floor \n14\n, for example.', 'Thus, the one or more latching grooves \n98\n may restrict movement of the annular sleeve \n34\n (e.g., vertical movement), such as in response to changes in wellbore pressure and/or friction due to movement of the drill string \n22\n and/or the casing \n26\n, and/or may maintain the annular sleeve \n34\n in a generally fixed positioned relative to the sea floor \n14\n and the wellbore \n18\n, for example.', 'The embodiment of the annular sleeve \n34\n shown in \nFIGS.', '2\n and \n3\n is provided as an example is not intended to be limiting.', 'It should be understood that the annular sleeve \n34\n may include various other configurations or features.', 'For example, in some embodiments, one or more of the stabs \n90\n and the fluid conduits \n36\n may extend radially from the annular sleeve \n34\n.', 'In some embodiments, the flange \n50\n and the body \n52\n may be fused (e.g., welded) together, and in some embodiments, the annular sleeve \n34\n is a one-piece structure extending from the first end \n46\n to the second end \n48\n (e.g., the flange \n50\n and the body \n52\n are integrally formed with one another).', 'FIG.', '4\n is a cross-sectional side view of another embodiment of the annular sleeve \n34\n having a rotating seal carrier \n100\n (e.g., annular seal-supporting structure).', 'As noted above with respect to \nFIG.', '1\n, in some systems \n10\n, the drill string \n22\n may rotate with the tool \n24\n to form the wellbore \n18\n, for example.', 'In certain embodiments, the rotating seal carrier \n100\n may enable rotation of the drill string \n22\n relative to the body \n52\n of the annular sleeve \n34\n without breaking the fluid seal provided by the inner seal \n70\n.', 'As shown, a cavity \n102\n (e.g., annular cavity) is formed in the radially-inner wall \n56\n of the body \n52\n of the annular sleeve \n34\n to support the rotating seal carrier \n100\n.', 'The rotating seal carrier \n100\n may rotate within the cavity \n102\n relative to the body \n52\n of the annular sleeve \n34\n.', 'For example, in the illustrated embodiment, one or more bearings \n104\n (e.g., roller bearings) are provided in the cavity \n102\n between the body \n52\n of the annular sleeve \n34\n and the rotating seal carrier \n100\n to enable the rotating seal carrier \n100\n to rotate relative to the body \n52\n of the annular sleeve \n34\n.', 'In particular, as shown, the multiple bearings \n104\n are provided in the cavity \n102\n between opposed axially-facing surfaces \n105\n (e.g., annular surfaces) of the body \n52\n of the annular sleeve \n34\n and the rotating seal carrier \n100\n, and between opposed tapered surfaces \n108\n (e.g., annular surfaces) of the body \n52\n of the annular sleeve \n34\n and the rotating seal carrier \n100\n.', 'The opposed tapered surfaces \n108\n may be tapered in opposite directions along the axial axis \n40\n to facilitate retention of the rotating seal carrier \n100\n within the cavity \n102\n and to restrict (e.g., block or limit) movement of the rotating seal carrier \n100\n in the axial direction \n40\n relative to the body \n52\n of the annular sleeve \n34\n (e.g., in response to changes in wellbore pressure and/or during movement of the drill string \n22\n).', 'In the illustrated embodiment, a radially-inner wall \n110\n (e.g., annular wall) of the rotating seal carrier \n100\n is configured to seal against the drill string \n22\n via an inner seal \n112\n (e.g., annular seal or drill string seal), which is supported within a cavity \n114\n (e.g., annular cavity) formed in the radially-inner wall \n110\n of the rotating seal carrier \n100\n.', 'Thus, fluid from the annular space \n32\n is blocked from flowing between the radially-inner wall \n110\n of the rotating seal carrier \n100\n and the drill string \n22\n.', 'As shown, a carrier seal \n106\n (e.g., annular seal) is provided between the radially-inner wall \n56\n of the body \n52\n and a radially-outer wall \n116\n (e.g., annular wall) of the rotating seal carrier \n100\n.', 'The inner seal \n112\n and/or the carrier seal \n106\n may have any of the characteristics of the inner seal \n70\n described above with respect to \nFIGS.', '2\n and \n3\n.\n \nFIG.', '5\n is schematic diagram of a portion of another offshore system \n130\n in which the annular sleeve \n34\n is coupled to a stack assembly \n132\n (e.g., BOP stack assembly, subsea isolation device, etc.), in accordance with an embodiment of the present disclosure.', 'The stack assembly \n132\n may include at least one annular BOP \n133\n positioned axially above one or more ram BOPs \n135\n that are configured to selectively seal and/or block fluid flow through an annular space \n137\n within the stack assembly \n132\n.', 'In the illustrated offshore system \n130\n, the wellhead assembly \n16\n is positioned at the interface between the wellbore \n18\n and the sea floor \n14\n, and the stack assembly \n20\n is positioned adjacent to the wellhead assembly \n16\n.', 'The drill string \n22\n extends from a location above the sea floor \n14\n into the wellbore \n18\n.', 'The tool \n24\n is positioned at one end of the drill string \n22\n to form the wellbore \n18\n.', 'In some embodiments, the offshore system \n130\n may be a riser-less system that does not include a riser that circumferentially surrounds the drill string \n22\n below the platform or drilling rig at the sea surface.', 'As shown, the casing \n26\n is installed within the wellbore \n18\n, and the annular sleeve \n34\n is positioned within the annular space \n32\n between the drill string \n22\n and the casing \n26\n.', 'In the illustrated embodiment, the annular sleeve \n34\n is mechanically supported (e.g., suspended) by and coupled to the stack assembly \n132\n.', 'In some embodiments, the annular sleeve \n34\n may be coupled to a frame of the stack assembly \n132\n via a key-slot interface \n134\n.', 'For example, in some embodiments, a key \n136\n (e.g., protrusion or latch) of the frame of the stack assembly \n132\n may engage the latching groove \n98\n (e.g., slot) of the annular sleeve \n34\n to support the annular sleeve \n34\n and to restrict movement (e.g., in the axial direction \n40\n) of the annular sleeve \n34\n relative to the stack assembly \n132\n.', 'The passageways \n60\n, \n66\n of the annular sleeve \n34\n may be fluidly coupled to the annular space \n137\n and/or to one or more fluid conduits \n138\n within the stack assembly \n132\n, such as a choke and kill line and/or a primary line, which are in turn coupled to a suitable fluid processing device, such as the fluid processing system \n38\n, positioned at a subsea location or on a platform or drilling rig at the sea surface.', 'Thus, in the illustrated offshore system \n130\n, at least when the annular BOP \n133\n and/or the ram BOPs \n135\n seal the annular space \n137\n of the stack assembly \n132\n, fluid from the wellbore \n18\n may flow through the annular space \n32\n, through the annular sleeve \n34\n, and into the fluid conduits \n138\n extending from the stack assembly \n132\n.', 'The illustrated offshore system \n130\n may facilitate fluid flow out of the wellbore \n18\n and/or may facilitate pressure control within the wellbore \n18\n during various drilling and/or maintenance operations.', 'In the illustrated embodiment, the offshore system \n130\n includes the casing assembly device \n30\n to assemble the casing \n26\n on-site at the subsea location, and the stack assembly \n132\n is positioned axially above (e.g., relative to the wellbore \n18\n) the casing assembly device \n30\n.', 'As shown, the second end \n48\n of the annular sleeve \n34\n is positioned within the assembled portion of the casing \n26\n axially below the casing assembly device \n30\n and the first end \n46\n of the annular sleeve \n34\n is coupled to the stack assembly \n132\n.', 'As noted above, it should be understood that the disclosed annular sleeve \n34\n may be incorporated within any of a variety of offshore or onshore drilling and production systems.', 'Thus, the offshore system \n130\n having the annular sleeve \n34\n may be configured for managed pressure drilling or conventional drilling operations that maintain hydrostatic pressure within the wellbore \n18\n.', 'Furthermore, the offshore system \n130\n having the annular sleeve \n34\n may be configured to utilize pre-formed casing sections and/or risers, and/or the annular sleeve \n34\n may be utilized within other annular spaces of the offshore system \n130\n to isolate and/or to direct fluid flow during drilling operations, maintenance operations, or the like, for example.', 'FIG.', '6\n is a flow diagram of a method \n150\n of using the annular sleeve \n34\n within a drilling and production system, such as the offshore systems \n10\n, \n130\n.', 'The method \n150\n includes various steps represented by blocks.', 'To facilitate discussion, the steps of the method \n150\n are described with reference to the annular space \n32\n between the drill string \n22\n and the casing \n26\n; however, it should be understood that the steps of the method \n150\n may be adapted to various annular spaces within a wide variety of drilling and productions systems.', 'Although the flow diagram illustrates the steps in a certain sequence, it should be understood that the steps may be performed in any suitable order, certain steps may be carried out simultaneously, and/or certain steps may be omitted, where appropriate.', 'Certain steps of the method \n150\n may be performed an operator via an electronic control system (e.g., having a processor and a memory device) and/or by an ROV or AOV.', 'Additionally or alternatively, certain steps of the method \n150\n may be performed as an automated procedures (e.g., by an electronic controller).', 'In some embodiments, the method \n150\n may include positioning the annular sleeve \n34\n in the annular space \n32\n between the drill string \n22\n and the casing \n26\n, in step \n152\n.', 'The radially-inner wall \n56\n of the annular sleeve \n34\n may seal against the drill string \n22\n and the radially-outer wall \n58\n of the annular sleeve \n34\n may seal against the casing \n26\n when the annular sleeve \n34\n is positioned within the annular space \n32\n.', 'The annular sleeve \n34\n may extend axially across the casing assembly device \n30\n and/or may be coupled to the casing assembly device \n30\n or to the stack assembly \n132\n of the offshore system \n10\n, \n130\n when the annular sleeve \n34\n is positioned within the annular space \n32\n.', 'It should be understood that the annular sleeve \n34\n may be positioned within the annular space \n32\n via any of a variety of processes.', 'For example, in some embodiments, the annular sleeve \n34\n may be positioned at a subsea location about the drill string \n22\n, and the casing \n26\n may be subsequently formed about the annular sleeve \n34\n and the drill string \n22\n to define the annular space \n32\n within which the annular sleeve \n34\n is positioned.', 'Furthermore, in some embodiments, the annular sleeve \n34\n may be positioned at a subsea location, and the drill string \n22\n may be subsequently inserted through the annular sleeve \n34\n and the casing \n26\n may be subsequently formed about the annular sleeve \n34\n and the drill string \n22\n to define the annular space \n32\n within which the annular sleeve \n34\n is positioned.', 'The method \n150\n may include assembling the casing \n26\n about the drill string \n22\n and/or lowering the casing \n26\n into the wellbore \n18\n, in step \n154\n.', 'In some embodiments, the casing \n26\n may be assembled and/or lowered as the tool \n24\n coupled to the drill string \n22\n drills the wellbore \n18\n.', 'In some embodiments, the casing \n26\n may be assembled on-site at the sea floor \n14\n using the casing assembly device \n30\n.', 'The method \n150\n may include directing a fluid flow from the wellbore \n18\n, through the annular space \n32\n, and through one or more passageways \n60\n, \n66\n extending axially across the annular sleeve \n34\n to the fluid processing system \n38\n positioned at a subsea location or at a surface location, in step \n156\n.', 'The casing \n26\n may be assembled and/or lowered into the wellbore \n18\n (e.g., the casing \n26\n may move in the axial direction \n40\n relative to the annular sleeve \n34\n) as the fluid flows through the one or more passageways \n60\n, \n66\n extending axially across the annular sleeve \n34\n.', 'Additionally or alternatively, the drill string \n22\n may move in the axial direction \n40\n and/or rotate relative to the annular sleeve \n34\n (e.g., to drill the wellbore \n18\n) as the fluid flows through the one or more passageways \n60\n, \n66\n extending axially across the annular sleeve \n34\n.', 'The disclosed method \n150\n may facilitate fluid flow out of the wellbore \n18\n and/or may facilitate pressure control within the wellbore \n18\n during various drilling and/or maintenance operations.', 'The disclosed method \n150\n may also facilitate assembly and/or installation of the casing \n26\n on-site at a subsea location (e.g., using the casing assembly device \n30\n), and in some embodiments, may facilitate assembly and/or installation of the casing \n26\n on-site at a subsea location as the wellbore \n18\n is drilled (e.g., via the drill string \n22\n and the tool \n24\n).', 'FIG.', '7\n is a side view of another offshore system \n140\n that includes a casing feeder device \n142\n and in which the annular sleeve \n34\n is coupled to the stack assembly \n132\n, in accordance with an embodiment of the present disclosure.', 'A portion of the offshore system \n140\n within line \n143\n is removed to provide a cross-sectional view of interior components of the annular sleeve \n34\n.', 'The stack assembly \n132\n may include at least one annular BOP \n133\n positioned axially above one or more ram BOPs \n135\n that are configured to selectively seal and/or block fluid flow through an annular space within the stack assembly \n132\n.', 'In the illustrated offshore system \n140\n, the wellhead assembly \n16\n is positioned at the interface between the wellbore \n18\n and the sea floor \n14\n, and the stack assembly \n20\n is positioned adjacent to the wellhead assembly \n16\n.', 'The drill string \n22\n extends from a location above the sea floor \n14\n into the wellbore \n18\n.', 'The tool \n24\n is positioned at one end of the drill string \n22\n to form the wellbore \n18\n.', 'In some embodiments, the offshore system \n140\n may be a riser-less system that does not include a riser that circumferentially surrounds the drill string \n22\n below the platform or drilling rig at the sea surface.', 'As shown, the casing \n26\n is installed within the wellbore \n18\n, and the annular sleeve \n34\n is positioned within the annular space \n32\n between the drill string \n22\n and the casing \n26\n.', 'In the illustrated embodiment, the annular sleeve \n34\n is mechanically supported (e.g., suspended) by and coupled to the stack assembly \n132\n (e.g., via a key-slot interface).', 'The passageways \n60\n, \n66\n of the annular sleeve \n34\n may be fluidly coupled to the annular space within the stack assembly \n132\n and/or to one or more fluid conduits \n138\n within the stack assembly \n132\n, such as a choke and kill line and/or a primary line, which are in turn coupled to a suitable fluid processing device, such as the fluid processing system \n38\n, positioned at a subsea location or on a platform or drilling rig at the sea surface.', 'Thus, in the illustrated offshore system \n140\n, at least when the annular BOP \n133\n and/or the ram BOPs \n135\n seal the annular space of the stack assembly \n132\n, fluid from the wellbore \n18\n may flow through the annular space \n32\n, through the annular sleeve \n34\n, and into the fluid conduits \n138\n extending from the stack assembly \n132\n.', 'The illustrated offshore system \n140\n may facilitate fluid flow out of the wellbore \n18\n and/or may facilitate pressure control within the wellbore \n18\n during various drilling and/or maintenance operations.', 'In the illustrated embodiment, the offshore system \n140\n includes the casing assembly device \n30\n to assemble the casing \n26\n on-site at the subsea location, and the stack assembly \n132\n is positioned axially above (e.g., relative to the wellbore \n18\n) the casing assembly device \n30\n.', 'As shown, casing material \n144\n (e.g., sheets, wires, or other non-annular pieces of material; annular pieces of material) may be provided to the casing assembly device \n30\n to enable the casing assembly device \n30\n to assemble the casing \n26\n (e.g., annular casing).', 'However, it should be appreciated that the casing material \n144\n may be stored within the casing assembly device \n30\n or provided to the casing assembly device \n30\n in any other suitable manner.', 'As shown, the offshore system \n140\n also includes a casing feeder device \n142\n, which may operate to drive the casing \n26\n into the wellbore \n18\n after formation of the casing \n26\n at the casing assembly device \n30\n.', 'The casing feeder device \n142\n may be a separate device (e.g., in a separate housing), or the casing feeder device \n142\n may be incorporated into the casing assembly device \n30\n (e.g., the casing assembly device \n30\n may include components that operate to form the casing \n26\n and drive the casing \n26\n into the wellbore \n18\n).', 'As noted above, it should be understood that the disclosed annular sleeve \n34\n may be incorporated within any of a variety of offshore or onshore drilling and production systems.', 'Thus, the offshore system \n140\n having the annular sleeve \n34\n may be configured for managed pressure drilling or conventional drilling operations that maintain hydrostatic pressure within the wellbore \n18\n.', 'Furthermore, the offshore system \n140\n having the annular sleeve \n34\n may be configured to utilize pre-formed casing sections (e.g., annular sections) and/or risers, and/or the annular sleeve \n34\n may be utilized within other annular spaces of the offshore system \n140\n to isolate and/or to direct fluid flow during drilling operations, maintenance operations, or the like, for example.', 'While the disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein.', 'However, it should be understood that the disclosure is not intended to be limited to the particular forms disclosed.', 'Rather, the disclosure is to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the disclosure as defined by the following appended claims.', 'Furthermore, any of the features shown or described with reference to \nFIGS. \n1\n-\n7\n may be substituted for one another and/or combined in any of a variety of ways.', 'The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical.', 'Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ”', 'or “step for [perform]ing [a function] . . .', '”, it is intended that such elements are to be interpreted under 35 U.S.C. 112(f).', 'However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. 112(f).']

['1.', 'A system, comprising:\nan annular sleeve configured to be positioned in an annular space between a first annular component and a second annular component of a drilling system, wherein the annular sleeve comprises: a radially-inner annular surface; a radially-outer annular surface; a first annular seal element coupled to the radially-inner annular surface and configured to seal against the first annular component; a second annular seal element coupled to the radially-outer annular surface and configured to seal against the second annular component; one or more axially-extending passageways extending from a first end to a second end of the annular sleeve; and a stab positioned at the first end of the annular sleeve to fluidly couple the one or more axially-extending passageways to a fluid processing system; wherein the annular sleeve is configured to maintain the first annular seal element against the first annular component and to maintain the second annular seal element against the second annular component while at least one of the first annular component or the second annular component moves in an axial direction relative to the annular sleeve to thereby direct a fluid flow through the one or more axially-extending passageways across the annular sleeve.', '2.', 'The system of claim 1, wherein the annular sleeve is configured to be positioned in the annular space such that the first end of the annular sleeve extends above the second annular component along an axial axis and the second end of the annular sleeve is within the second annular component along the axial axis.', '3.', 'The system of claim 1, wherein the first annular component comprises a drill string.', '4.', 'The system of claim 3, wherein the second annular component comprises a casing.', '5.', 'The system of claim 3, wherein the drill string is configured to rotate to drill a wellbore, and the annular sleeve is configured to maintain the first annular seal element against the drill string and the second annular seal element against the second annular component while the drill string rotates relative to at least a body of the annular sleeve to direct the fluid flow through the one or more axially-extending passageways across the annular sleeve.', '6.', 'The system of claim 5, wherein the annular sleeve comprises a rotating seal carrier rotatably coupled to the body of the annular sleeve to enable the drill string to rotate relative to at least the body of the annular sleeve.', '7.', 'The system of claim 1, comprising an assembly device configured to assemble the second annular component about the first annular component as the fluid flow passes through the one or more axially-extending passageways of the annular sleeve.', '8.', 'The system of claim 7, wherein the annular sleeve extends through the assembly device such that the first end of the annular sleeve is positioned above the assembly device along an axial axis and the second end of the annular sleeve is positioned below the assembly device along the axial axis and within the second annular component.', '9.', 'The system of claim 8, comprising a blowout preventer stack assembly, wherein the first end of the annular sleeve is coupled to the blowout preventer stack assembly.\n\n\n\n\n\n\n10.', 'The system of claim 1, wherein the system comprises a riser-less drilling system.', '11.', 'A system, comprising:\na drill string configured to support a tool to drill a wellbore;\na casing configured to be inserted into the wellbore to support the wellbore;\na casing assembly device configured to assemble the casing about the drill string on-site at a subsea location; and\nan annular sleeve comprising one or more axially-extending passageways extending from a first end and a second end of the annular sleeve, wherein the second end of the annular sleeve is configured to be positioned within an annular space between the drill string and the casing, the first end of the annular sleeve is configured to be positioned axially above the casing, and the annular sleeve is configured to divert a flow of fluid from the wellbore into the one or more axially-extending passageways of the annular sleeve and to transfer the flow of fluid to a fluid processing system as the casing is assembled and inserted into the wellbore, and wherein at least one of the drill string or the casing is configured to move in an axial direction relative to the annular sleeve while the flow of fluid is diverted into the one or more axially-extending passageways.', '12.', 'The system of claim 11, wherein the casing assembly device is configured to assemble the casing as the tool drills the wellbore.', '13.', 'The system of claim 11, wherein the system comprises a riser-less drilling system.', '14.', 'The system of claim 11, wherein the tool is configured to rotate relative to the drill string to drill the wellbore.', '15.', 'The system of claim 11, comprising a blowout preventer stack assembly, wherein the first end of the annular sleeve is coupled to the blowout preventer stack assembly.\n\n\n\n\n\n\n16.', 'The system of claim 11, wherein the annular sleeve comprises a rotating seal carrier that enables the annular sleeve to divert the flow of fluid from the wellbore into the one or more axially-extending passageways of the annular sleeve and to transfer the flow of fluid to the fluid processing system as the drill string rotates with the tool to drill the wellbore.', '17.', 'The system of claim 11, wherein the system further comprises a stab positioned at the first end of the annular sleeve to fluidly couple the one or more axially-extending passageways to the fluid processing system.', '18.', 'A method, comprising:\nassembling a tubular structure about a drill string as a tool at a distal end of the drill string drills a wellbore;\npositioning an annular sleeve in an annular space between an assembled portion of the tubular structure and the drill string;\ndirecting a fluid flow from the wellbore through one or more axially-extending passageways formed in the annular sleeve to a location axially above the assembled portion of the tubular structure; and\nrotating the drill string relative to at least a portion of the annular sleeve while directing the fluid flow through the one or more passageways.', '19.', 'The method of claim 18, comprising sealing a radially-inner annular wall of the annular sleeve against the drill string and sealing a radially-outer annular wall of the annular sleeve against the tubular structure.', '20.', 'The method of claim 18, comprising moving at least one of the drill string or the tubular structure in an axial direction relative to the annular sleeve while directing the fluid flow through the one or more passageways.']

['FIG.', '1 is a schematic diagram of an offshore system, in accordance with an embodiment of the present disclosure;; FIG.', '2 is a cross-sectional side view of an annular sleeve that may be used in the offshore system of FIG.', '1, in accordance with an embodiment of the present disclosure;; FIG.', '3 is a top view of a flange of the annular sleeve of FIG.', '2; and; FIG. 4 is a cross-sectional side view of an annular sleeve having a rotating seal carrier that may be used in the offshore system of FIG.', '1, in accordance with an embodiment of the present disclosure;; FIG. 5 is schematic diagram of another offshore system in which an annular sleeve is coupled to a stack assembly, in accordance with an embodiment of the present disclosure;; FIG.', '6 is a flow diagram of a method of operating a drilling and production system having an annular sleeve, in accordance with an embodiment of the present disclosure; and; FIG. 7 is a side view of another offshore system that includes a casing feeder device and in which an annular sleeve is coupled to a stack assembly, in accordance with an embodiment of the present disclosure.; FIG.', '2 is a cross-sectional side view of an embodiment of the annular sleeve 34.', 'As shown, the annular sleeve 34 extends between a first end 46 (e.g., proximal end) and a second end 48 (e.g., distal end), and includes a flange 50 (e.g., annular flange or proximal portion) coupled to a body 52 (e.g., annular body or distal portion) via fasteners 54 (e.g., threaded fasteners, such as bolts).', 'During drilling operations, at least the second end 48 of the annular sleeve 34 is positioned within the casing 26 (e.g., the assembled portion of the casing 26 having a solid tubular structure).', 'The body 52 of the annular sleeve 34 includes a radially-inner wall 56 (e.g., inner annular wall) and a radially-outer wall 58 (e.g., outer annular wall).', 'As shown, passageways 60 (e.g., axially-extending passageways, channels, or flow paths) extend through the body 52 of the annular sleeve 34 and are in fluid communication with the annular space 32 and the wellbore 18.; FIG.', '4 is a cross-sectional side view of another embodiment of the annular sleeve 34 having a rotating seal carrier 100 (e.g., annular seal-supporting structure).', 'As noted above with respect to FIG.', '1, in some systems 10, the drill string 22 may rotate with the tool 24 to form the wellbore 18, for example.', 'In certain embodiments, the rotating seal carrier 100 may enable rotation of the drill string 22 relative to the body 52 of the annular sleeve 34 without breaking the fluid seal provided by the inner seal 70.; FIG.', '5 is schematic diagram of a portion of another offshore system 130 in which the annular sleeve 34 is coupled to a stack assembly 132 (e.g., BOP stack assembly, subsea isolation device, etc.), in accordance with an embodiment of the present disclosure.', 'The stack assembly 132 may include at least one annular BOP 133 positioned axially above one or more ram BOPs 135 that are configured to selectively seal and/or block fluid flow through an annular space 137 within the stack assembly 132.', 'In the illustrated offshore system 130, the wellhead assembly 16 is positioned at the interface between the wellbore 18 and the sea floor 14, and the stack assembly 20 is positioned adjacent to the wellhead assembly 16.', 'The drill string 22 extends from a location above the sea floor 14 into the wellbore 18.', 'The tool 24 is positioned at one end of the drill string 22 to form the wellbore 18.', 'In some embodiments, the offshore system 130 may be a riser-less system that does not include a riser that circumferentially surrounds the drill string 22 below the platform or drilling rig at the sea surface.', 'As shown, the casing 26 is installed within the wellbore 18, and the annular sleeve 34 is positioned within the annular space 32 between the drill string 22 and the casing 26.; FIG.', '6 is a flow diagram of a method 150 of using the annular sleeve 34 within a drilling and production system, such as the offshore systems 10, 130.', 'The method 150 includes various steps represented by blocks.', 'To facilitate discussion, the steps of the method 150 are described with reference to the annular space 32 between the drill string 22 and the casing 26; however, it should be understood that the steps of the method 150 may be adapted to various annular spaces within a wide variety of drilling and productions systems.', 'Although the flow diagram illustrates the steps in a certain sequence, it should be understood that the steps may be performed in any suitable order, certain steps may be carried out simultaneously, and/or certain steps may be omitted, where appropriate.', 'Certain steps of the method 150 may be performed an operator via an electronic control system (e.g., having a processor and a memory device) and/or by an ROV or AOV.', 'Additionally or alternatively, certain steps of the method 150 may be performed as an automated procedures (e.g., by an electronic controller).', '; FIG. 7 is a side view of another offshore system 140 that includes a casing feeder device 142 and in which the annular sleeve 34 is coupled to the stack assembly 132, in accordance with an embodiment of the present disclosure.', 'A portion of the offshore system 140 within line 143 is removed to provide a cross-sectional view of interior components of the annular sleeve 34.', 'The stack assembly 132 may include at least one annular BOP 133 positioned axially above one or more ram BOPs 135 that are configured to selectively seal and/or block fluid flow through an annular space within the stack assembly 132.', 'In the illustrated offshore system 140, the wellhead assembly 16 is positioned at the interface between the wellbore 18 and the sea floor 14, and the stack assembly 20 is positioned adjacent to the wellhead assembly 16.', 'The drill string 22 extends from a location above the sea floor 14 into the wellbore 18.', 'The tool 24 is positioned at one end of the drill string 22 to form the wellbore 18.', 'In some embodiments, the offshore system 140 may be a riser-less system that does not include a riser that circumferentially surrounds the drill string 22 below the platform or drilling rig at the sea surface.', 'As shown, the casing 26 is installed within the wellbore 18, and the annular sleeve 34 is positioned within the annular space 32 between the drill string 22 and the casing 26.']

US11920414

Downhole turbine for managed pressure drilling

Aug 15, 2022

Stephen D. McGuire

SCHLUMBERGER TECHNOLOGY CORPORATION

NPL References not found.

11454095; September 27, 2022; Gajic; 20030066650; April 10, 2003; Fontana; 20060245945; November 2, 2006; Wilson; 20150098794; April 9, 2015; Baski; 20170284219; October 5, 2017; Hunter; 20180038177; February 8, 2018; Leuchtenberg; 20210348508; November 11, 2021; Greci

Foreign Citations not found.

['A mud turbine apparatus includes a rotor including an inner ring configured to be positioned around a drill pipe, an outer ring that is positioned around and spaced apart from the inner ring, a plurality of magnets coupled to the outer ring, and a plurality of blades coupled to and extending between the inner ring and the outer ring.', 'The apparatus also includes a stator including a housing configured to fit into an annulus between the drill pipe and a surrounding tubular, and to receive the outer ring at least partially therein, and a plurality of coils that communicate with the magnets, such that in a first mode of operation, the rotor rotates to assist fluid flow therethrough and decrease drilling fluid pressure in the annulus, and in a second mode of operation, the rotation of the rotor impedes fluid flow therethrough and increases drilling fluid pressure in the annulus.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application claims the benefit of U.S. Provisional Patent Application No. 63/235,869, entitled “DOWNHOLE TURBINE FOR MANAGED PRESSURE DRILLING,” filed Aug. 23, 2021, the disclosure of which is hereby incorporated herein by reference.', 'BACKGROUND\n \nWhen drilling a wellbore, the pressure in the well is controlled to prevent ingress of fluids from the surrounding formation, and also to prevent migration of drilling mud into the formation.', 'Traditionally, this has been accomplished by varying the density of the drilling fluid, which consequently varies the weight of the mud in the column formed by the well and, in offshore contexts, the riser, and thus the pressure in the well.', 'More recently, managed pressure drilling has been employed, in which the drilling wellhead is not exposed to atmospheric pressure, but rather is sealed.', 'A rotating control device (RCD) is provided, which grips the exterior of the drill pipe as it extends therethrough.', 'Further, valves, chokes, mud-gas separators, etc., may be provided so as to adjust the pressure circulating in the well, e.g., without changing the density of the drilling mud.', 'One challenge encountered is that the RCD, generally an annular rubber element, may wear down during use, e.g., as drill pipe collars are passed through the RCD.', 'Thus, the RCD may be replaced relatively frequently, e.g., after 100 hours of use.', 'This can lead to non-productive rig time.', 'Further, in offshore contexts, knowledge of the pressure in the well is useful, because problems, such as methane bubbling out of the mud, may be initiated in the riser, or even below, but may not be apparent to operators until the bubbles reach the surface.', 'Thus, mitigation efforts often occur as a reaction to an on-going problem, rather than in advance thereof so as to avoid it.', 'SUMMARY\n \nAn apparatus is disclosed that includes a rotor including an inner ring configured to be positioned around a drill pipe, an outer ring that is positioned around and spaced apart from the inner ring, a plurality of magnets coupled to the outer ring, and a plurality of blades coupled to and extending between the inner ring and the outer ring.', 'The apparatus also includes a stator including a housing configured to fit into an annulus between the drill pipe and a surrounding tubular, and to receive the outer ring at least partially therein, and a plurality of coils that communicate with the plurality of magnets, such that in a first mode of operation, the rotor rotates to assist fluid flow therethrough and decrease drilling fluid pressure in the annulus, and in a second mode of operation, the rotation of the rotor impedes fluid flow therethrough and increases drilling fluid pressure in the annulus.', 'A method is also disclosed.', 'The method includes pumping a drilling fluid through a drill string and into an annulus, adjusting a pressure of the drilling fluid in the annulus by adjusting a rotational speed of a turbine in the annulus, measuring one or more properties of the drilling fluid in the annulus using a magneto hydrodynamic circuit of the mud turbine, and refining the pressure of the drilling fluid in the annulus using the magneto hydrodynamic circuit.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments of the present teachings and together with the description, serve to explain the principles of the present teachings.', 'In the figures:\n \nFIG.', '1\nA\n illustrates a side, schematic view of a wellbore system that includes a mud turbine, according to an embodiment.\n \nFIG.', '1\nB\n illustrates a top view of the mud turbine in the wellbore system, according to an embodiment.\n \nFIG.', '1\nC\n illustrates a side view of the mud turbine receiving a drill pipe collar therethrough, according to an embodiment.\n \nFIG.', '2\n illustrates a perspective view of a rotor of the mud turbine, according to an embodiment.\n \nFIG.', '3\n illustrates a perspective view of the mud turbine, including the rotor and a stator, according to an embodiment.\n \nFIG.', '4\n illustrates a side, cross-sectional view of the mud turbine, according to an embodiment.\n \nFIG.', '5\n illustrates a flowchart of a method for controlling pressure of a drilling fluid in an annulus of a well, according to an embodiment.', 'DETAILED DESCRIPTION\n \nReference will now be made in detail to specific embodiments illustrated in the accompanying drawings and figures.', 'In the following detailed description, numerous specific details are set forth in order to provide a thorough understanding of the embodiments described herein.', 'However, it will be apparent to one of ordinary skill in the art that embodiments may be practiced without these specific details.', 'In other instances, well-known methods, procedures, components, circuits, and networks have not been described in detail so as not to unnecessarily obscure aspects of the embodiments.', 'It will also be understood that, although the terms first, second, etc. may be used herein to describe various elements, these elements should not be limited by these terms.', 'These terms are only used to distinguish one element from another.', 'For example, a first object could be termed a second object or step, and, similarly, a second object could be termed a first object or step, without departing from the scope of the present disclosure.', 'The terminology used in the description of the techniques herein is for the purpose of describing particular embodiments only and is not intended to be limiting.', 'As used in the description of the techniques herein and the appended claims, the singular forms “a,” “an” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise.', 'It will also be understood that the term “and/or” as used herein refers to and encompasses any and all possible combinations of one or more of the associated listed items.', 'It will be further understood that the terms “includes,” “including,” “comprises” and/or “comprising,” when used in this specification, specify the presence of stated features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.', 'Further, as used herein, the term “if” may be construed to mean “when” or “upon” or “in response to determining” or “in response to detecting,” depending on the context.', 'FIG.', '1\nA\n illustrates a side, schematic view of a wellbore system \n100\n, according to an embodiment.', 'The wellbore system \n100\n may include a drill string \n102\n that extends downwards (or otherwise downhole), e.g., through a riser \n104\n and into a wellbore wall \n106\n (e.g., open hole, cased, etc.) that extends through a formation.', 'An annulus \n108\n may be defined radially between the drill string \n102\n and the wellbore wall \n106\n.', 'The wellbore system \n100\n may further include a mud turbine \n110\n.', 'The mud turbine \n110\n may be positioned around the drill string \n102\n, e.g., in the annulus \n108\n, as shown in \nFIG.', '1\nB\n.', 'Further, the mud turbine \n110\n may be sized to permit drill pipe collars \n112\n (or any other upset, shoulder, tool, etc.) to extend through the interior diameter of the mud turbine \n110\n, as shown in \nFIG.', '1\nC\n.', 'The mud turbine \n110\n may be configured to adjust or otherwise control pressure in the annulus \n108\n, and thus in the well, by adjusting a rotational speed of a rotor thereof and/or by adjusting a magneto hydrodynamic circuit thereof during mud flow, e.g., as part of managed pressure drilling.', 'In some embodiments, this may permit a rotating control device at the wellhead to be omitted, although annular seals may still be employed.', 'In some embodiments, the mud turbine \n110\n could be used along with a rotating control device.\n \nFIG.', '2\n illustrates a perspective view of a rotor \n200\n of the mud turbine \n110\n.', 'As shown, the rotor \n200\n includes an inner ring \n202\n, which may be sized and configured to receive the drill string \n102\n (\nFIG.', '1\nA\n) therethrough.', 'Further, the rotor \n200\n may include an outer ring \n204\n positioned around and spaced radially outward from the inner ring \n202\n.', 'A plurality of blades \n206\n may be connected to the inner and outer rings \n202\n, \n204\n and may extend therebetween and be connected thereto.', 'Further, the blades \n206\n may be oriented/pitched at an angle configured to promote or impede fluid flow in one or both axial directions, e.g., depending on the rotational speed of the rotor \n200\n relative to the fluid flow rate.', 'The outer ring \n204\n may, for example, include a plurality of permanent magnets \n208\n coupled thereto, for example, received into slots formed in the outer diameter surface of the outer ring \n204\n.', 'The number of permanent magnets \n208\n employed may vary between implementations.', 'As will be appreciated by one of skill in the art, the greater number of magnets may imply a greater number of poles, which may permit for the rotational speed of the rotor \n200\n to be relatively low.', 'For example, 10, 20, 30, 40, 50, or more magnets \n208\n may be employed.', 'This may permit designs that avoid use of a gear reduction device, while still permitting the rotor \n200\n to rotate the blades \n206\n at relatively slow speeds, e.g., on the order of 60 revolutions per minute, although many other speeds are contemplated.\n \nFIG.', '3\n illustrates a perspective view of the mud turbine \n110\n, showing the rotor \n200\n received within a stator \n300\n. \nFIG.', '4\n illustrates a side, cross-sectional view of the mud turbine \n110\n, according to an embodiment.', 'Referring to \nFIGS.', '3\n and \n4\n, the stator \n300\n may have a housing or “shell” that extends around the outside of the rotor \n200\n.', 'The stator \n300\n may be coupled to or form part of the wellbore wall \n106\n, or may otherwise be prevented from movement relative thereto.', 'In a specific embodiment, as shown, the stator \n300\n may include two ring-shaped portions \n302\n, \n304\n, which are connected together at their middle at a flange connection \n306\n.', 'Further, the ring-shaped portions \n302\n, \n304\n may leave a channel open therethough, which permits fluid flow across the blades \n206\n of the rotor \n200\n.', 'Further, the stator \n300\n may include a plurality of coils therein, which form electromagnets that interact with the magnets \n208\n (\nFIG.', '2\n) of the rotor \n200\n when energized.', 'Accordingly, the stator \n300\n may be connected to a power source, e.g., a variable frequency drive, such that the power source drives the rotor \n200\n to rotate relative to the stator \n300\n.', 'In other embodiments, other types of electrical components may be employed to vary the power in the coils, such as inverters, IGBT transistors, etc.', 'In at least some embodiments, the mud turbine \n110\n may include a magneto hydrodynamic circuit.', 'For example, the inner and outer rings \n202\n, \n204\n of the rotor \n200\n may be coupled to a DC power source, such that one of the inner and outer rings \n202\n, \n204\n serves as an anode wall and the other serves as a cathode wall.', 'The blades \n206\n may be formed as electric insulators, and thus a magnetic field may be generated by application of the DC source to the inner and outer rings \n202\n, \n204\n.', 'Lorentz forces are thus generated in the mud turbine \n110\n and may be incident upon the fluid flowing through the rotor \n200\n.', 'The polarity of the DC power may be switched, such that the DC power source is capable of selectively assisting or impeding fluid flow through the mud turbine \n110\n.', 'Additionally, the current provided by the DC power source may be modulated, so as to provide a range of forces to assist and/or impede fluid flow through the mud turbine \n110\n.', 'FIG.', '5\n illustrates a flowchart of a method \n500\n for controlling a pressure of a drilling fluid in an annulus \n108\n of a well using a mud turbine \n110\n, according to an embodiment.', 'In this embodiment, the method \n500\n may include pumping drilling fluid (mud) from the surface, through a drill string \n102\n and back to the surface at least partially via an annulus \n108\n formed between the drill string \n102\n and the wellbore wall \n106\n, as at \n502\n.', 'A subsea riser \n104\n may also extend between the surface and the wellbore wall \n106\n, as discussed above.', 'The method \n500\n may further include adjusting a pressure of the drilling fluid in the annulus \n108\n by adjusting a rotational speed of the turbine \n110\n in the annulus \n108\n, as at \n504\n.', 'For example, a variable frequency drive may be coupled to coils of the mud turbine \n110\n, such that the power is controllable so as to vary the rotational speed of the rotor \n200\n of the mud turbine \n110\n.', 'Since the rotor \n200\n includes the blades \n202\n, the result may be that the rotor \n200\n increases pressure in the annulus \n108\n by rotating slower than the drilling fluid flow, such that a pressure builds up below the blades \n208\n as the fluid travels up the annulus \n108\n.', 'For example, a load may be applied to the rotor \n200\n, such that the mud turbine \n110\n acts as a generator, producing a resistance to fluid flow that increases pressure in the drilling fluid.', 'The rotor \n200\n may further be powered to rotate so as to decrease or increase the pressure in the drilling fluid below the blades \n208\n.', 'Accordingly, rotational speed of the mud turbine \n110\n may be employed to control the pressure of the fluid in the annulus \n108\n and thus in contact with the wellbore wall \n106\n.', 'In other words, in some embodiments, for example, the mud turbine \n110\n may include at least a first mode of operation and a second mode of operation.', 'In the first mode of operation, the blades \n208\n may be powered to rotate via the VFD or otherwise configured not to impede, or may even be configured to assist fluid flow, therethrough.', 'Thus, in the first mode, the operation of the mud turbine \n110\n may induce relatively little, no, or even negative pressure increases in the drilling fluid in the annulus \n108\n below the mud turbine \n110\n.', 'In a second mode of operation, the mud turbine \n110\n may act as a generator, such that a controlled load produced by the coils and the magnets \n208\n is overcome by the energy of the fluid to rotate the rotor \n200\n.', 'Accordingly, in the second mode, the mud turbine \n110\n may increase pressure in the drilling fluid in the annulus \n108\n below the mud turbine \n110\n.', 'The method \n500\n may also include sensing fluid characteristics using the mud turbine \n110\n, as at \n506\n.', 'For example, the mud turbine \n110\n may provide the magneto hydrodynamic (MHD) circuit discussed above.', 'The MHD circuit may, in some cases, provide measurements of conductivity/resistivity of the fluid.', 'For example, at low pressures, gas may bubble out of solution in the drilling fluid.', 'The bubbles of gas may have a higher electrical resistance than the drilling fluid.', 'Thus, the MHD circuit, which includes the fluid as it flows through the turbine \n110\n, may be able to sense when the pressure is too low, e.g., gas bubbles are forming.', 'Thus, rather than recognizing such a condition when the bubbles reach the surface, above the riser \n104\n, the method \n500\n may permit an early detection of such conditions and permit for proactive remediation measures (e.g., modulating control valves, changing pressure by changing the speed of the mud turbine \n110\n, etc.).', 'In at least some embodiments, a further adjustment to fluid pressure is also provided via the MHD circuit, as at \n508\n.', 'Thus, while bulk changes in pressure in the drilling fluid may be generated by changing rotational speed, relatively small or “trim” changes may be produced by changing the current provided to the MHD circuit, e.g., to assist fluid flow more or less, or oppose fluid flow.', 'For example, the MHD circuit may provide relatively low or zero inertia for such changes, allowing for rapid implementation and variation, relative to the higher inertia (but greater range of operating pressures) in the rotor \n200\n/stator \n300\n combination.', 'In some embodiments, a rotary control device or subsea annular can be closed when a prolonged period of zero circulation of drilling fluid is expected.', 'This may allow for trapping a desired pressure, without continued operation of the mud turbine \n110\n, which may avoid heating the drilling fluid.', 'Further, it will be appreciated that, although a single stage mud turbine \n110\n is discussed above, any number of two or more stages (e.g., rotor/stators) may be employed.', 'The foregoing description, for purpose of explanation, has been described with reference to specific embodiments.', 'However, the illustrative discussions above are not intended to be exhaustive or to limit the disclosure to the precise forms disclosed.', 'Many modifications and variations are possible in view of the above teachings.', 'Moreover, the order in which the elements of the methods described herein are illustrate and described may be re-arranged, and/or two or more elements may occur simultaneously.', 'The embodiments were chosen and described in order to explain at least some of the principals of the disclosure and their practical applications, to thereby enable others skilled in the art to utilize the disclosed methods and systems and various embodiments with various modifications as are suited to the particular use contemplated.']

['1.', 'An apparatus, comprising:\na rotor including: an inner ring configured to be positioned around a drill pipe; an outer ring that is positioned around and spaced apart from the inner ring; a plurality of magnets coupled to the outer ring; and a plurality of blades coupled to and extending between the inner ring and the outer ring; and\na stator including: a housing configured to fit into an annulus between the drill pipe and a surrounding tubular, and to receive the outer ring at least partially therein; and a plurality of coils that communicate with the plurality of magnets, such that in a first mode of operation, the rotor rotates the plurality of blades independently from the drill pipe to assist a fluid flow therethrough and decrease a drilling fluid pressure in the annulus, and in a second mode of operation, the rotor rotates the plurality of blades independently from the drill pipe to impede the fluid flow therethrough and increase the drilling fluid pressure in the annulus, wherein the fluid flow is in a common direction through the rotor between the plurality of blades in the first and second modes of operation; and\nwherein the apparatus is configured to adjust a rotational speed of the rotor between the first and second modes of operation based on at least one property of the fluid flow, wherein the at least one property comprises a resistivity or a conductivity of the fluid flow.', '2.', 'The apparatus of claim 1, comprising a magneto hydrodynamic circuit configured to sense the resistivity or the conductivity of the fluid flow.', '3.', 'The apparatus of claim 2, wherein the magneto hydrodynamic circuit is configured to sense the resistivity or the conductivity of the fluid flow passing through the rotor, and to communicate data representing the resistivity or the conductivity to a controller.', '4.', 'The apparatus of claim 2, wherein the magneto hydrodynamic circuit comprises one of the inner and outer rings as an anode ring and another of the inner and outer rings as a cathode ring, and a magnetic field is generated by application of a power source to the anode and cathode rings.', '5.', 'The apparatus of claim 4, wherein the power source is configured to modulate a current to vary an electromagnetic force incident upon the fluid flow through the rotor, and the electromagnetic force is variable between a first electromagnetic force to assist the fluid flow and a second electromagnetic force to impede the fluid flow.', '6.', 'The apparatus of claim 1, wherein the plurality of blades are oriented at an angle configured to assist or impede the fluid flow depending on the rotational speed of the rotor.', '7.', 'The apparatus of claim 1, comprising a magneto hydrodynamic circuit configured to adjust an electromagnetic force on the fluid flow, wherein the magneto hydrodynamic circuit is configured to vary the electromagnetic force between a first electromagnetic force to assist the fluid flow and a second electromagnetic force to impede the fluid flow.', '8.', 'The apparatus of claim 7, wherein the magneto hydrodynamic circuit is formed into the inner and outer rings of the rotor.', '9.', 'A method, comprising:\npumping drilling fluid from a surface, through a drill string, into an annulus formed between the drill string and a wellbore, and back to the surface;\nmeasuring at least one property of the drilling fluid, wherein the at least one property comprises a resistivity or a conductivity of the drilling fluid;\nadjusting, based on the at least one property, a pressure of the drilling fluid in the annulus by adjusting a rotational speed of a turbine having a plurality of blades extending at least partially radially through the annulus, wherein adjusting the pressure comprises: decreasing the pressure in a first mode of operation by rotating the turbine independently from the drill string to assist a flow of the drilling fluid through the turbine; and increasing the pressure in a second mode of operation by rotating the turbine independently from the drill string to impede the flow of the drilling fluid through the turbine, wherein the flow of the drilling fluid is in a common direction through the turbine in the first and second modes of operation; and\nadjusting, based on the at least one property, the pressure of the drilling fluid in the annulus by adjusting an electromagnetic force on the flow of the drilling fluid through the turbine via a magneto hydrodynamic circuit, wherein the magneto hydrodynamic circuit is configured to switch between a first electromagnetic force to assist the flow of the drilling fluid through the turbine and a second electromagnetic force to impede the flow of the drilling fluid through the turbine.', '10.', 'The method of claim 9, wherein increasing the pressure comprises reducing the rotational speed of the turbine to impede the flow of the drilling fluid in the second mode of operation.', '11.', 'The method of claim 9, wherein decreasing the pressure comprises increasing the rotational speed of the turbine to assist the flow of the drilling fluid in the first mode of operation.', '12.', 'The method of claim 9, wherein measuring the at least one property comprises sensing the at least one property with the magneto hydrodynamic circuit of the turbine, the magneto hydrodynamic circuit comprising an anode ring and a cathode ring coupled to a power source, and the plurality of blades couple to and extend between the anode ring and the cathode ring.', '13.', 'The method of claim 12, wherein the at least one property comprises the resistivity.', '14.', 'The method of claim 12, wherein the at least one property comprises the conductivity.', '15.', 'The method of claim 9, wherein measuring the at least one property comprises measuring the resistivity or the conductivity to sense bubbles in the drilling fluid.', '16.', 'The method of claim 9, wherein the magneto hydrodynamic circuit is configured to switch between the first and second electromagnetic forces by changing a polarity of a power source of the magneto hydrodynamic circuit.', '17.', 'A method, comprising:\npumping a drilling fluid from a surface, through a drill string, into an annulus formed between the drill string and a wellbore, and back to the surface;\nadjusting a pressure of the drilling fluid in the annulus by adjusting a rotational speed of a mud turbine in the annulus, wherein the mud turbine is configured to rotate independently from the drill string;\nmeasuring one or more properties of the drilling fluid in the annulus using a magneto hydrodynamic circuit of the mud turbine, wherein the one or more properties comprises a resistivity or a conductivity of the drilling fluid, and the magneto hydrodynamic circuit is partially formed by the drilling fluid in the mud turbine; and\nrefining the pressure of the drilling fluid in the annulus using the magneto hydrodynamic circuit to apply an electromagnetic force on the drilling fluid in the mud turbine, wherein the magneto hydrodynamic circuit is configured to vary the electromagnetic force to selectively assist a flow of the drilling fluid through the mud turbine and impede the flow of the drilling fluid through the mud turbine.', '18.', 'The method of claim 17, wherein adjusting the pressure comprises:\ndecreasing the pressure in a first mode of operation by rotating the mud turbine independently from the drill string to assist the flow of the drilling fluid through the mud turbine; and\nincreasing the pressure in a second mode of operation by rotating the turbine independently from the drill string to impede the flow of the drilling fluid through the mud turbine, wherein the flow of the drilling fluid is in a common direction through the mud turbine in the first and second modes of operation.', '19.', 'The method of claim 17, wherein measuring one or more properties comprises measuring the resistivity or the conductivity to sense bubbles in the drilling fluid.', '20.', 'The method of claim 17, wherein refining the pressure comprises changing a polarity of a power source of the magneto hydrodynamic circuit to vary the electromagnetic force between a first electromagnetic force to assist the flow of the drilling fluid and a second electromagnetic force to impede the flow of the drilling fluid.']

['FIG.', '1A illustrates a side, schematic view of a wellbore system that includes a mud turbine, according to an embodiment.;', 'FIG.', '1B illustrates a top view of the mud turbine in the wellbore system, according to an embodiment.;', 'FIG.', '1C illustrates a side view of the mud turbine receiving a drill pipe collar therethrough, according to an embodiment.; FIG.', '2 illustrates a perspective view of a rotor of the mud turbine, according to an embodiment.; FIG.', '3 illustrates a perspective view of the mud turbine, including the rotor and a stator, according to an embodiment.; FIG.', '4 illustrates a side, cross-sectional view of the mud turbine, according to an embodiment.; FIG.', '5 illustrates a flowchart of a method for controlling pressure of a drilling fluid in an annulus of a well, according to an embodiment.;', 'FIG.', '1A illustrates a side, schematic view of a wellbore system 100, according to an embodiment.', 'The wellbore system 100 may include a drill string 102 that extends downwards (or otherwise downhole), e.g., through a riser 104 and into a wellbore wall 106 (e.g., open hole, cased, etc.) that extends through a formation.', 'An annulus 108 may be defined radially between the drill string 102 and the wellbore wall 106.; FIG.', '2 illustrates a perspective view of a rotor 200 of the mud turbine 110.', 'As shown, the rotor 200 includes an inner ring 202, which may be sized and configured to receive the drill string 102 (FIG.', '1A)', 'therethrough.', 'Further, the rotor 200 may include an outer ring 204 positioned around and spaced radially outward from the inner ring 202.', 'A plurality of blades 206 may be connected to the inner and outer rings 202, 204 and may extend therebetween and be connected thereto.', 'Further, the blades 206 may be oriented/pitched at an angle configured to promote or impede fluid flow in one or both axial directions, e.g., depending on the rotational speed of the rotor 200 relative to the fluid flow rate.; FIG.', '3 illustrates a perspective view of the mud turbine 110, showing the rotor 200 received within a stator 300.', 'FIG.', '4 illustrates a side, cross-sectional view of the mud turbine 110, according to an embodiment.', 'Referring to FIGS.', '3 and 4, the stator 300 may have a housing or “shell” that extends around the outside of the rotor 200.', 'The stator 300 may be coupled to or form part of the wellbore wall 106, or may otherwise be prevented from movement relative thereto.', 'In a specific embodiment, as shown, the stator 300 may include two ring-shaped portions 302, 304, which are connected together at their middle at a flange connection 306.', 'Further, the ring-shaped portions 302, 304 may leave a channel open therethough, which permits fluid flow across the blades 206 of the rotor 200.; FIG.', '5 illustrates a flowchart of a method 500 for controlling a pressure of a drilling fluid in an annulus 108 of a well using a mud turbine 110, according to an embodiment.', 'In this embodiment, the method 500 may include pumping drilling fluid (mud) from the surface, through a drill string 102 and back to the surface at least partially via an annulus 108 formed between the drill string 102 and the wellbore wall 106, as at 502.', 'A subsea riser 104 may also extend between the surface and the wellbore wall 106, as discussed above.']

US11661843

Method and system for determining a lithology of a subterranean formation

Sep 30, 2020

Sophie Androvandi, Maurice Ringer, Karim Bondabou

SCHLUMBERGER TECHNOLOGY CORPORATION

Search and Examination Report R. 62 EPC issued in European Patent Application No. 20200818.1 dated Mar. 12, 2021, 4 pages.

9581723; February 28, 2017; Hurley et al.; 20090055097; February 26, 2009; Kowalik et al.; 20170260855; September 14, 2017; Yang et al.

2010043951; April 2010; WO; 2015070022; May 2015; WO

['A method is provided for determining a lithology of a subterranean formation into which a wellbore has been drilled.', 'The method includes receiving a set of measurement logs including one or more measurement logs, each representing a measured characteristic of the wellbore plotted according to depth.', 'The method also includes segmenting the wellbore into regions based on identified change of trend in one or more of the measurement logs of the set, and sub-segmenting at least one region into zones based on detection of appearance or disappearance of a rock type in the cuttings percentage log, The method also includes determining, in each zone, a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one of the additional measurement logs.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThis application claims priority to and the benefit of EP Application No 19306331.0, titled “Method and System for determining a Lithology of a subterranean Formation,” filed Oct. 11, 2019, the entire disclosure of which is hereby incorporated herein by reference.', 'The disclosure relates to a method and system for determining a lithology of a subterranean formation.', 'When drilling a wellbore, it is critical to know as soon as possible as many information regarding the wellbore and the surrounding formation in order to make educated decisions during the drilling of the wellbore and to evaluate the potential of the formation.', 'In this context, mud logging services are generally used at the well site in order to gather information on the wellbore and formation.', 'Mud logging services comprise in particular sensing of drilling parameters at the surface (such as weight on bit, torque on bit, etc.) as well as measurements of the material coming out of the well, in particular analysis of the cuttings and drilling fluid coming out of the wellbore.', 'Such services may be complemented by downhole measurements obtained directly by the tool in the formation and transmitted at the surface via telemetry.', 'All these measurements enable to perform set up an interpreted lithology representing the lengths; locations and rock type of the layers in the formation, ie the sequence of the layers drilled.', 'Currently, the interpreted lithology is created by combining multiple measurements made by the mud logger while drilling, in particular, the percentage of rock type (lithology) measured in the drilled cuttings that come to surface, and the data from downhole LWD tools that is transmitted to surface, such as gamma-ray count measurement.', 'The creation of the interpreted Lithology is today a manual process that is inconsistent between different mud loggers and is long and tedious.', 'SUMMARY', 'The disclosure relates to a first method for determining a lithology of a subterranean formation into which a wellbore has been drilled.', 'The method comprises receiving a set of measurement logs comprising one or more measurement logs, each representing a measured characteristic of the wellbore plotted according to depth.', 'The measured characteristic include at least cuttings percentage and one or more additional measured characteristics.', 'The method also includes segmenting the wellbore into regions based on identified change of trend in one or more of the measurement logs of the set, and sub-segmenting at least one region into zones based on detection of appearance or disappearance of a rock type in the cuttings percentage log, The method also includes determining, in each zone, a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one of the additional measurement logs.', 'A plurality of exemplary embodiments of such method are disclosed in the specification and claims.', 'The disclosure also relates to a second method for determining a lithology of a subterranean formation into which a wellbore has been drilled.', 'The method comprises receiving a set of measurement logs comprising one or more measurement logs, each representing a measured characteristic of the wellbore plotted according to depth.', 'The measured characteristics include at least cuttings percentage and one or more additional measured characteristics.', 'The method also includes segmenting the wellbore into regions based on identified change of trend in at least one of the measurement log of the set and automatically generating a lithology log containing a sequence of layers, each identified by the location in depth, the length and the rock type in at least one region.', 'Automatically generating a lithology log may include sub-segmenting at least one region into zones based on detection of appearance or disappearance of a rock type in the cuttings percentage log and determining, in each zone, a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one of the additional measurement logs.', 'In such case, the plurality of exemplary embodiments described in relationship with the first method are also application to the second method.', 'The disclosure also relates to a system for determining a lithology of a subterranean formation into which a wellbore has been drilled.', 'The system comprises a processing system having one or more processors configured to receive a set of measurement logs comprising one or more measurement logs.', 'Each log represents a measured characteristic of the wellbore plotted according to depth, and the measured characteristics include at least cuttings percentage and one or more additional measured characteristics.', 'The processing system is also configured to segment the wellbore into regions based on identified change of trend in at least one of the measurement log of the set and generate a lithology log containing a sequence of layers, each identified by the location in depth, the length and the rock type in at least one region.', 'The above-mentioned systems and methods enable to generate a consistent and accurate deliverable that is not influenced by operator bias or background and is available in real-time or near real-time at the well site for immediate decision making regarding the drilling operations.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings in which:\n \nFIG.', '1\n is a schematic drawing of a well site installation including a system according to an embodiment of the disclosure,\n \nFIG.', '2\n is a flowchart of a method according to an embodiment of the disclosure;\n \nFIG.', '3\n shows measurement logs segmented at an operation of the method according to an embodiment of the disclosure;\n \nFIG.', '4\n is a plot showing a sub-segmentation of a region of the wellbore based on a cuttings percentage log as per the method according to an embodiment of the disclosure;\n \nFIG.', '5\n is a flowchart of an operation of the method according to an embodiment of the disclosure,\n \nFIG.', '6\n is a plot showing a measurement log and a representation of an operation according to an embodiment of the disclosure,\n \nFIG.', '7\n is a plot showing two measurement logs and a representation of an operation according to an embodiment of the disclosure,\n \nFIG.', '8\n shows a representation of an interpreted lithology log obtained by the method according to the disclosure and a compared to an interpreted lithology obtained by an operator based on the same measurement logs\n \n \nDETAILED DESCRIPTION\n \nOne or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, some features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions may be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would still be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.’', 'In all the following, the terms of “upstream” and “downstream” are understood relatively to the normal direction of circulation of a fluid in a conduit.', 'FIG.', '1\n is a schematic drawing of an installation according to an embodiment of the disclosure.\n \nFIG.', '1\n is a schematic view of at least a portion of an example implementation of a rotary drilling rig system \n5\n.', 'Downhole measurements can be conducted by instruments disposed in a drill collar \n20\n.', 'Such measurements may be stored in memory apparatus of the downhole instruments, or may be telemetered to the surface via conventional measuring-while-drilling (MWD) telemetering apparatus and techniques.', 'For that purpose, an MWD tool sub, schematically illustrated as a tool \n29\n, may receive signals from instruments of the collar \n20\n, and may transmit them via a mud path \n8\n of a drill string \n6\n for receipt, e.g., ultimately via a pressure sensor \n14\n in a stand pipe \n15\n and/or to other surface instrumentation \n7\n.', 'The drilling rig system \n5\n may include a motor \n2\n that may turn a kelly \n3\n through the use of a rotary table \n4\n.', 'The drill string \n6\n may include sections of drill pipe connected end-to-end to the kelly \n3\n and may be turned thereby.', 'For example, a plurality of drill collars and/or tools \n20\n, \n26\n, \n28\n, and \n29\n may be attached to the drilling string \n6\n.', 'Such collars and tools may collectively form a bottom hole assembly (BHA) \n50\n extending from the drill string \n6\n to a drilling bit \n30\n.', 'As the drill string \n6\n and the BHA \n50\n turn, the drill bit \n30\n can bore a wellbore \n9\n.', 'An annulus \n10\n is thus defined between the outside of the drill string \n6\n (including the BHA \n50\n) and the wellbore \n9\n through one or more subterranean geological formations \n32\n.', 'A pump \n11\n may pump drilling fluid (drilling “mud”) from a source, e.g., from a mud pit \n13\n, via a stand pipe \n15\n, a revolving injector head \n17\n, and the mud path \n8\n of the kelly \n3\n and the drill string \n6\n to the drill bit \n30\n.', 'The mud may lubricate the drill bit \n30\n and may carry wellbore cuttings upward to the surface via the annulus \n10\n.', 'If desired, the mud may be returned, e.g., to the mud pit \n13\n or to an appropriate mud regeneration site, where it may be separated from cuttings and the like, degassed, and returned for application again to the drill string \n6\n.', 'Separating the cuttings from the mud is performed via shale shakers \n52\n.', 'Once the mud and the cuttings have been separated, they may be collected and analyzed.', 'Cuttings samples \n54\n may be collected manually and analyzed in a mud logging cabin (not represented) with one or more instruments (such as microscope, X-ray fluorescence (XRF), X-Ray Diffraction (XRD), and the like).', 'Alternatively, the cuttings sample may be collected and analyzed automatically at the well site.', 'Regarding the mud (or drilling fluid), it is generally sampled at the outlet of the shakers by a sampling device \n56\n and directed to an extractor \n58\n that extracts gas from the mud.', 'The gas is then directed to an analyzer \n60\n (such as Thermal Conductivity Detector (TCD), Flame Ionization Detector (FID) or mass spectrometer) in order to detect the content of one or more gas, optionally with the interposition of a gas chromatograph.', 'The downhole tool (collar) \n20\n may be any type of downhole tool taking measurement, such as an ultrasonic tool, an electromagnetic or resistivity tool, a sampling tool.', 'For example, the ultrasonic tool \n20\n may include at least one or more sensors \n45\n, \n46\n, e.g., such as for measuring characteristics of the wellbore \n9\n and/or fluid, including pressure, standoff, composition, etc. therein during drilling operations.', 'Such measurements may be conducted while the wellbore \n9\n is being drilled and/or with the drill string \n6\n and the BHA \n50\n in the wellbore \n9\n while the drill bit \n30\n, the BHA \n50\n, and the drill string \n6\n are not rotating.', 'Such measurements may be conducted while the drill string \n6\n, the BHA \n50\n, and the drill bit \n30\n are being tripped to and from the bottom of the wellbore \n9\n.', 'The measurements (or data based at least partially thereon) may be transmitted to the surface via the MWD telemetry tool \n29\n and the internal mud passage \n8\n of the drill string \n6\n (or the annulus \n10\n), or they may be recorded and stored downhole and for retrieval at the surface after the drill string \n6\n and BHA \n50\n have been removed from the wellbore \n9\n.', 'The sensors \n45\n, \n46\n may be mounted on stabilizer fins \n27\n of the downhole tool \n20\n, as depicted in \nFIG.', '1\n, or may be mounted in a cylindrical wall \n23\n of the downhole tool \n20\n.', 'An electronics module \n22\n may contain electronic circuits, microprocessors, memories, and/or the like, operable to control, and/or to receive, process, and/or store data from the sensors \n45\n, \n46\n, which may be mounted on a sleeve, an inner tube, and/or other section \n21\n secured around or within the collar of the ultrasonic tool \n20\n.', 'The section \n21\n and other components of the BHA \n50\n may include a path \n40\n by which drilling mud may pass through the interior passage \n8\n of the drill string \n6\n to the drill bit \n30\n.', 'A portion of the drilling rig system \n5\n, such as surface instrumentation \n7\n, may include other sensors for measurement parameters at the surface, such as flow, pressure, weight on bit, torque on bit, etc. and verify that the system works properly.', 'As an example, a sensor \n11\n′ may be connected to the pump \n11\n to count the number of strokes of the pump, a sensor \n3\n′ may be present at the Kelly or motor to assess the rotations per minute (RPM) or in the weight and torque on bit.', 'The surface instrumentation \n7\n may also include data processing system \n8\n that can encompass one or more, or portions thereof, of the following: control devices and electronics in one or more modules of the BHA \n50\n (such as a downhole controller), a remote computer system (not shown), communication equipment, and other equipment.', 'The data processing system may include one or more computer systems or devices and/or may be a distributed computer system.', 'For example, collected data or information may be stored, distributed, communicated to a human wellsite operator, and/or processed locally or remotely.', 'The data processing system may, individually or in combination with other system components, is also linked to all or part of the sensors, downhole or at the surface, to process the measurements and may perform the methods and/or processes described below, or portions thereof.', 'For example, such data processing system may include processor capability for collecting data obtained from the sensors at the surface or downhole.', 'Methods and/or processes within the scope of the present disclosure may be implemented by one or more computer programs that run in a processor located, e.g., in one or more modules of the BHA \n50\n and/or surface equipment of the drilling rig system \n5\n.', 'Such programs may utilize data received from the BHA \n50\n via mud-pulse telemetry and/or other telemetry means, and/or may transmit control signals to operative elements of the BHA \n50\n.', 'The programs may be stored on a tangible, non-transitory, computer-usable storage medium associated with the one or more processors of the BHA \n50\n and/or surface equipment, such as surface instrumentation \n7\n, of the drilling rig system \n5\n, or may be stored on an external, tangible, non-transitory, computer-usable storage medium electronically coupled to such processor(s).', 'The storage medium may be one or more known or future-developed storage media, such as a magnetic disk, an optically readable disk, flash memory, or a readable device of another kind, including a remote storage device coupled over a communication link, among other examples.', 'A method \n100\n for determining lithology of the formation is described in reference with \nFIGS.', '2\n-\n8\n.', 'The method first comprises receiving (block \n102\n) a set of measurement logs comprising one or more measurement log.', 'Each of the measurement log represents a measured characteristic of the wellbore plotted according to depth as can be seen on \nFIG.', '3\n.', 'The measurements log of the set comprise a cuttings percentage, obtained from the sampling of cuttings extracted from the wellbore at the surface, and one or more additional measurements, taken at the surface or downhole.', 'Such additional measurement log may be directly sensed at the wellsite (for instance, weight on bit, torque on bit, total gas in mud obtained from the gas analyzer or gamma-ray count obtained from the downhole tool) or computed from a combination of sensed parameters (for instance, a formation strength).', 'The method may therefore also comprise computing one of more of the measurements that are not directly obtained from sensed parameters.', 'Concerning the formation strength, for instance, it may generally be computed from the weight on bit, rate of penetration and revolution per minutes of the drill bit.', 'One or more measurement logs of the set are then segmented (block \n104\n) based on change of trend in the log.', 'We can see examples of measured characteristics being total gas in mud \n105\nA, gamma-ray count \n105\nB, cuttings percentage \n105\nC and formation strength \n105\nD. In each log, there are many variations of the measurement from which the general trends \n106\n are extracted.', 'The points \n107\n situated at the change or inflexion of a trend is considered as a “change point” and its depth is considered as an extremity of a region.', 'Therefore, the measurement log is segmented into regions based on the trend analysis.', 'The trend analysis and “change point” determination may be obtained by using a “Change Point’ algorithm.', 'This algorithm allows a detection of the edges.', 'It is based on Bayesian approach but the kind of approach is not limited other approaches for segmenting the log may be used.', 'The “Change Point” algorithm is disclosed in more details in patent application WO2010/043951.', 'The trend analysis may be run on one log, such as rate of penetration, total drilled gas, gamma ray from MWD, and any LWD measurements such as resistivity when available.', 'For more robustness, the trend analysis may also be performed on a plurality of measurement logs \n105\nA-\n105\nD as represented on \nFIG.', '3\n.', 'In this case, all “change points” may not be selected and some conditions may be apply, such as selecting a first “change point” depth in a first log as an extremity of a region if at least another log show a “change point’ in a predetermined depth interval around the first “change point’ depth.', 'In this case, the other “change point” in the depth interval may be deleted.', 'Alternatively, a measurement log may be associated to a confidence in view of the type of measurement and of the way the measurement was performed and the measurement with highest confidence may be chosen as reference measurement and its ‘change point’ may be used for determining the regions.', 'The method then comprises generating an interpreted lithology log (block \n110\n) in at least one region of the wellbore.', 'Therefore, the interpreted lithology may be obtained in a consistent way, in real-time.', 'In particular, the method may be configured to automatically generate the interpreted lithology log.', 'By “automatically”, it is meant that the operations performed as part of block \n110\n are performed without direct human control.', 'A human may set parameters or validate the results of the automatic generation but does not need to intervene so that the operations described herebelow are performed.', 'The generation comprises sub segmenting (block \n112\n) the region into zones based on rock type appearance and disappearance in the cuttings percentage log as represented on \nFIG.', '4\n, showing a region of the cuttings percentage log \n114\n.', 'The boundary of the zone corresponds to the depth of the rock type appearance or disappearance.', 'In other words a zone ends and a new zone starts when a new type of cuttings appears on the cuttings percentage log or disappears from the cuttings percentage log.', 'For instance, as can be seen on \nFIG.', '4\n, there is only a first rock type (here, clay-s) in a upper portion of the log \n114\n.', 'This portion forms a first zone \n116\n that ends at depth \n113\n when a second type of rock type (here limestone) appears in the cuttings percentage log.', 'The second zone \n118\n starts at \n113\n and ends at depth \n115\n when a third rock type (such as dolomite) appears, starting a third zone \n119\n.', 'The third zone \n118\n ends at \n117\n when the third rock type disappears from the log.', 'Then, in each zone, the method includes determining (block \n120\n) the location, length and rock type of one or more layers based on total rock type percentage in the zone and at least one additional measured characteristic (i.e. measurement).', 'This operation is represented in more details in \nFIG.', '5\n.', 'First, the operation \n120\n comprises computing (block \n122\n) the total percentage of each rock type in a zone.', 'This may be performed for instance by computing the area between two curves on the measurement log, that is representative of the measurement.', 'For instance in zone \n114\n, the percentage of the first rock type would be 100% while the percentage of second and third rock type would be 0%.', 'In zone \n116\n, the total percentage of second rock type would be defined by the area \n122\n and the total percentage of first rock type by the area \n124\n, both divided by the total area of the zone.', 'The method then comprises determining (block \n124\n) the aggregated length of the layers having a predetermined rock type.', 'In the following the “length” of a layer is defined as the difference between the depths it extends.', 'For instance the length of the zone \n118\n is the difference between depth \n113\n and depth \n115\n.', 'The “aggregated length” of the layers is the sum of their respective length.', 'Determining the aggregated length of the layers includes determining a length corresponding to a percentage of the zone length equal to the total percentage of the predetermined rock type in the zone, ie multiplying the length of the zone by the total percentage for the rock type.', 'The aggregated length is used to preserve the distribution of cuttings percentage.', 'For example, if a zone has a length of 50 m, and there 20% of clay in the zone, the aggregated length of the clay layers, whether in one or several layers, is 10 m.', 'The method also comprises determining (block \n126\n) a location of one or more layers having the predetermined rock type.', 'This includes determining a set of depths in the zone for which the values of one of the additional measurement are closest to an extremum of the measurement in the zone.', 'The set of depths is determined so that its aggregated length matches the aggregated length of the layers.', 'The additional measurement may be any additional measurement that is considered relevant.', 'For instance, for clay or shale, the selected additional measured characteristic may be gamma-ray count, for limestone, the selected additional measured characteristic may be formation strength and for sandstone, the selected additional measured characteristic may be total gas in mud.', 'For these three additional measured characteristics, the location of the layers is detected based on a set of depths closest to a maximum of the log.', 'The disclosure is however not limited to this set of additional measured characteristics and any other relevant additional measured characteristic may be selected.', 'Further, the minimum of the corresponding log of such characteristic may also be selected for attributing the location of the layers.', 'FIG.', '6\n shows this operation in more detail. \nFIG.', '6\n shows a measurement log \n130\n having an additional measured characteristic \n132\n as a function of depth \n134\n and enables to identify a first predetermined rock type.', 'For instance, as represented on \nFIG.', '6\n, this operation includes identifying a key value \n136\n for which the depth intervals (ie set of depths) of data points having values superior to the key value corresponds to the aggregated length of the layers.', 'This may be performed by flagging local maxima \n138\n-\n144\n and calculating the depth interval of the data points having values superior to all local maxima except for one (see interval \n146\n on \nFIG.', '6\n).', 'It corresponds to a location of a first layer.', 'This depth interval may be compared with the aggregated length of the layers of the predetermined rock type computed.', 'If the interval is shorter than the aggregated length that has been computed, the location of a second layer will be set around the second highest maximum \n138\n and the sum of the depth intervals having data points having values superior to all local maxima except for two may be calculated (intervals \n148\nA, \n148\nB).', 'If the interval is shorter than the aggregated length of the layers of the predetermined rock type that has been computed, the operation is renewed with the third local maxima.', 'If the sum of depth intervals is longer than the aggregated length, the key value \n136\n may be search between the second and third highest maxima \n138\n and \n140\n, for instance using squeezing techniques.', 'The set of depths is defined as all depths having values being superior to the key value, in particular on \nFIG.', '6\n, intervals \n148\nA, \n148\nB.\n \nPreferably, as several rock type are present in the formation, once the locations of the layers of the predetermined rock type, designated first predetermined rock type, have been determined, the location of the layers of an another rock type, ie second rock type, are determined.', 'Therefore, the method includes defining (block \n150\n) an updated zone so that the updated zone comprises the length of the initial zone except for the set of depths that has been selected as the location of the first rock type.', 'The updated zone is shown on \nFIG.', '6\n as \n152\n.', 'The method is then reset with a second predetermined rock type and the updated zone, ie the aggregated length of the layers having second rock type is determined, and a second set of depths corresponding to the location of these layers is determined.', 'The second set of depths may be determined based on the same additional measurement that has been used for the first predetermined rock type, or based on a different additional measurement.', 'As can be seen on \nFIG.', '7\n, showing two additional measurements \n130\n, \n160\n plotted on the same chart as a function of depth \n162\n, the first additional measurement already represented on \nFIG.', '6\n that enabled to determine the locations of layers of the first predetermined rock type and a second additional measurement enabling to determine the second rock type, the same operation of determining the location of the layers by determining the set of depths closest to an extremum is performed again but in the updated zone \n152\n, discarding the data points that are in the depth intervals \n148\nA, \n148\nB.', 'In this scenario, there is only one layer of the second predetermined rock type at the depth interval \n154\n.', 'These operations \n124\n, \n126\n, \n150\n may be performed iteratively until no measurement is available to identify a particular rock type.', 'It can be adaptative depending on the number and type of measurement available in the well and some parameters relative to the well, for instance its geometry or the region in which it is disposed.', 'When no measurement is available anymore, an operator may be consulted to complete the interpreted lithology log or the location of the remaining layers may be determined based on the remaining locations.', 'A sequence that could be used for determining the locations of layers may be the following: \n \n \n \nThe first predetermined rock type is clay and shale and the locations of the layers having this rock type is determined based on gamma-ray measurement maxima,\n \nThe second predetermined rock type is limestone and the locations of the layers having this rock type is determined based on formation strength measurement maxima,\n \nThe third predetermined rock type is sandstone and the locations of the layers having this rock type is determined based on total gas in mud measurement maxima.', 'As previously indicated, this sequence is an exemplary one and other sequences may be used within the scope of the disclosure.', 'The method then comprises generating (block \n170\n) the interpreted lithology log based on the location, length and rock type of the layers, corresponding to plot the location of the layers as a function of depth.', 'Such a log \n180\n is represented on \nFIG.', '8\n \nThe method as per the disclosure has been tested with the above-mentioned on a well site.', 'The figure shows cuttings percentage \n172\n, Formation strength \n174\n, rate of penetration (ROP) \n176\n, total gas (TG) \n177\n, mechanical specific energy (MSE) \n178\n, gamma-ray (GR) \n179\n, all parameters that may be used in the determination of the interpretation lithology log.', 'The figure shows as well an interpreted lithology log \n180\n obtained by the above-mentioned method and compared with the interpreted lithology as established by the operator on site \n182\n as well as mineralogy obtained by downhole tool \n184\n.', 'The mineralogy shows (quartz, feldspath, mica) at \n185\n, the carbonate at \n189\n and clay at \n187\n.', 'The results \n180\n obtained by the method are more coherent and compact than the results from the operators \n182\n, as can be seen from comparison with LWD mineralogy.', 'For instance, in zone \n186\n, a dolomite zone is visible in the log \n180\n and this zone is perfectly aligned with the carbonate zone in the log \n184\n.', 'Similarly in zone \n188\n, the log \n180\n shows a zone of dolomite that is in agreement with what is shown on log \n184\n.', 'In zone \n190\n, the LWD log \n184\n shows a zone of clay that matches with the clay zone that is obtained with the above-mentioned method.', 'We can see that both interpreted lithology logs are very similar.', 'The method according to the disclosure enabling to obtain the interpreted lithology early on, in real-time or near real-time, enables to have more information regarding the formation and to take more educated drilling decisions as soon as possible.', 'The disclosure relates to a first method for determining a lithology of a subterranean formation into which a wellbore has been drilled.', 'The method comprises receiving a set of measurement logs comprising one or more measurement logs, each representing a measured characteristic of the wellbore plotted according to depth.', 'The measured characteristic include at least cuttings percentage and one or more additional measured characteristics.', 'The method also includes segmenting the wellbore into regions based on identified change of trend in one or more of the measurement logs of the set, and sub-segmenting at least one region into zones based on detection of appearance or disappearance of a rock type in the cuttings percentage log, The method also includes determining, in each zone, a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one of the additional measurement logs.', 'A plurality of exemplary embodiments of such method are disclosed in the specification and claims.', 'In an embodiment, the additional measured characteristics comprise one or more of a gamma-ray count, a rate of penetration, a total gas in mud, a formation strength, a weight on bit, or a resistivity.', 'In particular, when the additional measured characteristics comprise the formation strength, the method comprises computing the formation strength from the weight on bit, revolutions per minute and rate of penetration\n \nIn an embodiment, determining the length of one or more layers having a predetermined rock type in the zone includes determining an aggregated length of layers having the predetermined rock type, wherein the aggregated length corresponds to percentage of the zone length equal to the total percentage of the predetermined rock type in the zone.', 'In particular, determining a location of one or more layers having the predetermined rock type include determining a set of depths in the zone, the set of depths being defined so that the corresponding values for at least one of the additional measured characteristics are closest to an extremum of the additional measured characteristic in the zone, wherein the set of depths is determined so that its aggregated length matches the aggregated length of the layers having the predetermined rock type\n \nIn the above-mentioned embodiment, the method may include determining the aggregated length of layers for each rock type, determining the location of the one or more layers having a first predetermined rock type in the zone, creating an updated zone consisting of the zone excluding the set of depths corresponding to the first predetermined rock type and determining the location of the one or more layers having a second predetermined rock type in the updated zone.', 'In particular, determining the location of the one or more layers having the first predetermined rock type in the zone may be based on a first additional measured characteristic and determining the location of the one or more layers having the second predetermined rock type in the updated zone is based on a second additional measured characteristic.', 'In a particular embodiment, determining the location of one or more layers having the predetermined rock type may include selecting the set of depths according to one or more of the following: \n \n \n \nThe additional measured characteristics including gamma-ray count, the set of depths having gamma-ray count values closest to a maximum is selected when the predetermined rock type is clay and shale,\n \nThe additional measured characteristics including a formation strength, the set of depths having formation strength values closest to a maximum is selected when the predetermined rock type is limestone,\n \nThe additional measured characteristics including a formation total gas in mud, the set of depths having total gas in mud values closest to a maximum when the predetermined rock type is sandstone.', 'In an embodiment, if a first predetermined rock type is clay and shale, the method may determine a first set of depths in the zone having gamma-ray count values closest to a maximum.', 'If a second predetermined rock type is limestone, the method may determine a second set of depths having formation strength values closest to a maximum in a first updated zone consisting of the zone excluding the first set of depths.', 'If a third predetermined rock type is sandstone, the method may determine a third set of depths in a second updated zone consisting of the first updated zone excluding the second set of depths.', 'In an embodiment, segmenting the measurements log includes identifying change points in the measurement log, wherein at least a change point depth is defined as a boundary of a region.', 'In such case, segmenting the measurements may include identifying first change points in a first measurement log and second change points in a second measurement log and selecting a depth of a first change point as a boundary of a region if a second change point is identified in a predetermined depth interval around said depth.', 'In an embodiment, the method includes generating a lithology log based on the location, length and rock type of the one or more layers', 'The disclosure also relates to a second method for determining a lithology of a subterranean formation into which a wellbore has been drilled.', 'The method comprises receiving a set of measurement logs comprising one or more measurement logs, each representing a measured characteristic of the wellbore plotted according to depth.', 'The measured characteristics include at least cuttings percentage and one or more additional measured characteristics.', 'The method also includes segmenting the wellbore into regions based on identified change of trend in at least one of the measurement log of the set and generating a lithology log containing a sequence of layers, each identified by the location in depth, the length and the rock type in at least one region.', 'The generation of the lithology log is preferably made automatically, ie without direct human control.', 'Generating a lithology log may include sub-segmenting at least one region into zones based on detection of appearance or disappearance of a rock type in the cuttings percentage log and determining, in each zone, a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one of the additional measurement logs.', 'In such case, the plurality of exemplary embodiments described in relationship with the first method are also application to the second method.', 'The disclosure also relates to a system for determining a lithology of a subterranean formation into which a wellbore has been drilled.', 'The system comprises a processing system having one or more processors configured to receive a set of measurement logs comprising one or more measurement logs.', 'Each log represents a measured characteristic of the wellbore plotted according to depth, and the measured characteristics include at least cuttings percentage and one or more additional measured characteristics.', 'The processing system is also configured to segment the wellbore into regions based on identified change of trend in at least one of the measurement log of the set and generate a lithology log containing a sequence of layers, each identified by the location in depth, the length and the rock type in at least one region.', 'The processing system may be configured to generate automatically the lithology log, ie without direct human control.', 'The system may comprise at least one of a cuttings sample analysis device for analyzing cuttings exiting the wellbore and at least one of a gas sample analysis device for analyzing gas extracted from the drilling fluid exiting the wellbore, wherein one of the additional measured characteristic is total gas in mud; a downhole tool for taking one or more downhole measurement, wherein one of the additional measured characteristic is gamma-ray count or resistivity; and a sensor situated at the well site, at the surface, to measure one or more of the parameters relative to a drilling installation of the wellbore, wherein one of the additional measured characteristic is weight on bit, torque on bit, rate of penetration, rotation per minute or formation strength.', 'Further, the processing system may be configured to sub-segment at least one region into zones based on detection of appearance or disappearance of a rock type in the cuttings percentage log, and, in each zone, determine a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one of the additional measurement logs.']

['1.', 'A method for determining a lithology of a subterranean formation into which a wellbore has been drilled, comprising:\nreceiving a set of measurement logs comprising a plurality of measurement logs, each measurement log representing a measured characteristic of the wellbore plotted according to depth, wherein the measured characteristics of the set of measurement logs include cuttings percentage and one or more additional measured characteristics,\nsegmenting the wellbore into regions based on an identified change of trend in at least one of the measurement logs of the set, wherein segmenting the wellbore includes identifying first change points in a first measurement log and second change points in a second measurement log and selecting a depth of a first change point as a boundary of a region if a second change point is identified in a predetermined depth interval around the depth of the first charge point,\nsub-segmenting at least one region into zones based on a detection of appearance or disappearance of a rock type in the cuttings percentage log, and\nin each zone, determining a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one additional measurement log.', '2.', 'The method of claim 1, wherein the additional measured characteristics comprise one or more of a gamma-ray count, a rate of penetration, a total gas in mud, a formation strength, a weight on bit, or a resistivity.', '3.', 'The method of claim 2, wherein the additional measured characteristics comprise the formation strength, wherein the method further comprises computing the formation strength from the weight on bit, revolutions per minute and rate of penetration.', '4.', 'The method of claim 1, wherein determining the length of the one or more layers includes determining an aggregated length of layers having a predetermined rock type, wherein the aggregated length corresponds to a percentage of the zone length equal to a total percentage of the predetermined rock type in the zone.', '5.', 'The method of claim 4, wherein determining the length of the one or more layers further includes determining a location of one or more layers having the predetermined rock type, wherein determining the location includes determining a set of depths in the zone, the set of depths being defined so that the corresponding values for at least one of the additional measured characteristics are closest to an extremum of the additional measured characteristic in the zone, wherein the set of depths is determined so that its aggregated length matches the aggregated length of the layers having the predetermined rock type.', '6.', 'The method of claim 5, wherein determining the location of the one or more layers having the predetermined rock type further includes selecting the set of depths according to one or more of the following:\nthe additional measured characteristics including gamma-ray count, the set of depths having gamma-ray count values closest to a maximum is selected when the predetermined rock type is clay and shale,\nthe additional measured characteristics including a formation strength, the set of depths having formation strength values closest to a maximum is selected when the predetermined rock type is limestone, and\nthe additional measured characteristics including a formation total gas in mud, the set of depths having total gas in mud values closest to a maximum when the predetermined rock type is sandstone.', '7.', 'The method of claim 4, wherein the predetermined rock type is a first predetermined rock type, and wherein determining the length of the one or more layers further includes creating an updated zone consisting of the zone excluding the set of depths corresponding to the first predetermined rock type and determining the location of the one or more layers having a second predetermined rock type in the updated zone.', '8.', 'The method of claim 7, wherein determining the location of the one or more layers having the first predetermined rock type in the zone is based on a first additional measured characteristic and determining the location of the one or more layers having the second predetermined rock type in the updated zone is based on a second additional measured characteristic.', '9.', 'The method of claim 7, wherein the first predetermined rock type is clay and/or shale and the method further includes determining a first set of depths having gamma-ray count values closest to a maximum in the zone associated to the first predetermined rock type; and wherein the second predetermined rock type is limestone, and the method further includes determining a second set of depths having formation strength values closest to a maximum in a first updated zone consisting of the zone excluding the first set of depths.', '10.', 'The method of claim 9, wherein a third predetermined rock type is sandstone and the method further includes determining a third set of depths in a second updated zone consisting of the first updated zone excluding the second set of depths.', '11.', 'The method of claim 1, further comprising generating a lithology log based on the location, length and rock type of the one or more layers.', '12.', 'A method for determining a lithology of a subterranean formation into which a wellbore has been drilled, comprising:\nreceiving a set of measurement logs comprising a plurality of measurement logs, each measurement log representing a measured characteristic of the wellbore plotted according to depth, wherein the measured characteristics of the set of measurement logs include cuttings percentage and one or more additional measured characteristics,\nsegmenting the wellbore into regions based on an identified change of trend in at least one of the measurement logs of the set,\nsub-segmenting at least one region into zones based on a detection of appearance or disappearance of a rock type in the cuttings percentage log, and\nin each zone, determining a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one additional measurement log,\nwherein determining the length of the one or more layers includes: determining an aggregated length of layers having a predetermined rock type, wherein the aggregated length corresponds to a percentage of the zone length equal to a total percentage of the predetermined rock type in the zone; and determining a location of one or more layers having the predetermined rock type, wherein determining the location of the one or more layers having the predetermined rock type includes determining a set of depths in the zone, the set of depths being defined so that the corresponding values for at least one of the additional measured characteristics are closest to an extremum of the additional measured characteristic in the zone, wherein the set of depths is determined so that its aggregated length matches the aggregated length of the layers having the predetermined rock type.', '13.', 'The method of claim 12, wherein determining the location of the one or more layers having the predetermined rock type further includes selecting the set of depths according to one or more of the following:\nthe additional measured characteristics including gamma-ray count, the set of depths having gamma-ray count values closest to a maximum is selected when the predetermined rock type is clay and shale,\nthe additional measured characteristics including a formation strength, the set of depths having formation strength values closest to a maximum is selected when the predetermined rock type is limestone, and\nthe additional measured characteristics including a formation total gas in mud, the set of depths having total gas in mud values closest to a maximum when the predetermined rock type is sandstone.', '14.', 'A method for determining a lithology of a subterranean formation into which a wellbore has been drilled, comprising:\nreceiving a set of measurement logs comprising a plurality of measurement logs, each measurement log representing a measured characteristic of the wellbore plotted according to depth, wherein the measured characteristics of the set of measurement logs include cuttings percentage and one or more additional measured characteristics,\nsegmenting the wellbore into regions based on an identified change of trend in at least one of the measurement logs of the set,\nsub-segmenting at least one region into zones based on a detection of appearance or disappearance of a rock type in the cuttings percentage log, and\nin each zone, determining a location, length and rock type of one or more layers based on a total percentage of each rock type in the zone in the cuttings percentage log and at least one additional measurement log,\nwherein determining the length of the one or more layers includes determining an aggregated length of layers having a predetermined rock type, wherein the aggregated length corresponds to a percentage of the zone length equal to a total percentage of the predetermined rock type in the zone, and\nwherein the predetermined rock type is a first predetermined rock type, and wherein determining the length of the one or more layers further includes creating an updated zone consisting of the zone excluding the set of depths corresponding to the first predetermined rock type and determining the location of the one or more layers having a second predetermined rock type in the updated zone.', '15.', 'The method of claim 14, wherein determining the location of the one or more layers having the first predetermined rock type in the zone is based on a first additional measured characteristic and determining the location of the one or more layers having the second predetermined rock type in the updated zone is based on a second additional measured characteristic.', '16.', 'The method of claim 14, wherein the first predetermined rock type is clay and/or shale and the method further includes determining a first set of depths having gamma-ray count values closest to a maximum in the zone associated to the first predetermined rock type; and wherein the second predetermined rock type is limestone, and the method further includes determining a second set of depths having formation strength values closest to a maximum in a first updated zone consisting of the zone excluding the first set of depths.', '17.', 'The method of claim 16, wherein a third predetermined rock type is sandstone and the method further includes determining a third set of depths in a second updated zone consisting of the first updated zone excluding the second set of depths.', '18.', 'The method of claim 14, wherein the additional measured characteristics comprise one or more of a gamma-ray count, a rate of penetration, a total gas in mud, a formation strength, a weight on bit, or a resistivity.', '19.', 'The method of claim 14, wherein the additional measured characteristics comprise the formation strength, wherein the method further comprises computing the formation strength from the weight on bit, revolutions per minute and rate of penetration.', '20.', 'The method of claim 14, further comprising generating a lithology log based on the location, length and rock type of the one or more layers.']

['FIG.', '1 is a schematic drawing of a well site installation including a system according to an embodiment of the disclosure,; FIG.', '2 is a flowchart of a method according to an embodiment of the disclosure;; FIG.', '3 shows measurement logs segmented at an operation of the method according to an embodiment of the disclosure;; FIG.', '4 is a plot showing a sub-segmentation of a region of the wellbore based on a cuttings percentage log as per the method according to an embodiment of the disclosure;; FIG.', '5 is a flowchart of an operation of the method according to an embodiment of the disclosure,; FIG.', '6 is a plot showing a measurement log and a representation of an operation according to an embodiment of the disclosure,; FIG. 7 is a plot showing two measurement logs and a representation of an operation according to an embodiment of the disclosure,; FIG.', '8 shows a representation of an interpreted lithology log obtained by the method according to the disclosure and a compared to an interpreted lithology obtained by an operator based on the same measurement logs; FIG.', '1 is a schematic drawing of an installation according to an embodiment of the disclosure.', '; FIG. 1 is a schematic view of at least a portion of an example implementation of a rotary drilling rig system 5.', 'Downhole measurements can be conducted by instruments disposed in a drill collar 20.', 'Such measurements may be stored in memory apparatus of the downhole instruments, or may be telemetered to the surface via conventional measuring-while-drilling (MWD) telemetering apparatus and techniques.', 'For that purpose, an MWD tool sub, schematically illustrated as a tool 29, may receive signals from instruments of the collar 20, and may transmit them via a mud path 8 of a drill string 6 for receipt, e.g., ultimately via a pressure sensor 14 in a stand pipe 15 and/or to other surface instrumentation 7.; FIG.', '6 shows this operation in more detail.', 'FIG.', '6 shows a measurement log 130 having an additional measured characteristic 132 as a function of depth 134 and enables to identify a first predetermined rock type.', 'For instance, as represented on FIG. 6, this operation includes identifying a key value 136 for which the depth intervals (ie set of depths) of data points having values superior to the key value corresponds to the aggregated length of the layers.', 'This may be performed by flagging local maxima 138-144 and calculating the depth interval of the data points having values superior to all local maxima except for one (see interval 146 on FIG. 6).', 'It corresponds to a location of a first layer.', 'This depth interval may be compared with the aggregated length of the layers of the predetermined rock type computed.', 'If the interval is shorter than the aggregated length that has been computed, the location of a second layer will be set around the second highest maximum 138 and the sum of the depth intervals having data points having values superior to all local maxima except for two may be calculated (intervals 148A, 148B).', 'If the interval is shorter than the aggregated length of the layers of the predetermined rock type that has been computed, the operation is renewed with the third local maxima.', 'If the sum of depth intervals is longer than the aggregated length, the key value 136 may be search between the second and third highest maxima 138 and 140, for instance using squeezing techniques.', 'The set of depths is defined as all depths having values being superior to the key value, in particular on FIG.', '6, intervals 148A, 148B.']

US11933776

Pressure meter testing apparatus and method

Dec 6, 2021

Jean E. Elkhoury, Thomas Berard, Emilie Peyret, Romain Prioul, Vincenzo De Gennaro

Schlumberger Technology Corporation

Liu, (2005) Numerical Study of Reservoir Geomechanical Pressuremeter Testing under Anistropic In-situ Stresses, Univ. Alberta PMT tool, MSc. Thesis, Univ. Alberta 2015, (180 pages).; International Search Report and Written Opinion of PCT Application No. PCT/US2021/059615 dated Apr. 20, 2022, 10 pages.; International Preliminary Report on Patentability issued in the PCT Application No. PCT/US2021/059615 dated Jun. 29, 2023, 7 pages.

4423625; January 3, 1984; Bostic, III; 5353637; October 11, 1994; Plumb; 5784333; July 21, 1998; Tang; 6092416; July 25, 2000; Halford; 20040237640; December 2, 2004; Meister et al.; 20090164128; June 25, 2009; Tchakarov et al.; 20100051347; March 4, 2010; Tchakarov; 20100206548; August 19, 2010; Pisio; 20120150515; June 14, 2012; Hariharan; 20150136388; May 21, 2015; Fehr; 20170204726; July 20, 2017; Lecampion et al.; 20180334903; November 22, 2018; Lehr; 20180355715; December 13, 2018; Cour; 20210172315; June 10, 2021; Alruwaili; 20210262343; August 26, 2021; Dupont et al.

2547865; August 2018; EP; 2020206303; October 2020; WO

['Embodiments provide a pressure meter testing apparatus and method that allows operations/engineers the ability to determine in-situ stiffness values of geological stratum.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThis Application claims priority to U.S. Provisional Patent Application Ser.', 'No. 63/128,575, filed Dec. 21, 2020, entitled: “Pressure Meter Testing Apparatus and Method”, and International Application PCT/US2021/059615, filed Nov. 17, 2021 which are incorporated herein in their entirety.', 'FIELD OF THE DISCLOSURE\n \nAspects of the disclosure relate to testing of geological stratum.', 'More specifically, aspects of the disclosure relate to a pressure meter testing method and apparatus using packers installed within a wellbore.', 'BACKGROUND\n \nAscertaining geological stiffness is a difficult process for engineers.', 'Current practices require extensive laboratory work that can increase the costs of a wellbore dramatically.', 'Some wellbores, for example, wellbores that may have a marginal rate of economic return, may not be pursued at all, if stiffness values for the geological stratum are questionable.', 'Conventionally, testing of in-situ stiffness values in field geological stratum is not accomplished on a wide scale in the industry.', 'The reasons for this are complex and are the result of drawbacks to current technologies used by oil field service companies.', 'Typically, in the oil and gas industry, elastic properties are measured in situ with sonic logging tools (WL or LWD) that yield “dynamic” stiffnesses (also called moduli) from elastic-wave velocity and density.', '“Static” stiffnesses (or moduli) are obtained from laboratory stress-strain experiments and are not measured in situ.', 'A difference between “dynamic” and “static” stiffnesses comes from the difference on deformation (strain) amplitude.', 'Generally, for geomechanics application, “static” elastic values are what is needed for computational and application purposes.', 'The conventional practice is to measure dynamic and static stiffness on core samples in the lab after the well has been drilled and build a dynamic-static correlation so that the dynamic sonic stiffness log can be transformed (or “corrected”) to a static stiffness log for applications.', 'One of the drawbacks for such conventional methods is that the lab measurements on core samples is expensive and may take weeks to months to accomplish.', 'During that time, the cores become unconfined when taken out of the hole.', 'At this point, the results are not necessarily representative of downhole conditions even if they are measured in a load cell under confinement.', 'Conventionally, there are no methods to measure static elastic properties downhole, with the definition of elastic stiffness defined as: \n \nElastic stiffness=elastic modulus=elastic constant (units of Pascal)\n \nElastic compliance is the inverse of elastic stiffness \n As will be understood by those of skill in the art, the different “stiffness” terms are loosely defined in mechanics wherein, for elasticity, stiffness is in units of Pascals.', 'One significant drawback to conventional apparatus is that such apparatus cannot be used effectively to determine the stiffness of a geological stratum.', 'The inability to measure such parameters results in engineers making an “educated guess” as to this parameter.', 'Such guesses/estimations must be made in a conservative fashion as failure to accurately represent such values can detrimentally affect the overall production of hydrocarbon bearing stratum.', 'For attempts at obtaining such values directly from field conditions, Engineers cannot accurately provide a surface test bed assembly that can be used in various field locations.', 'Small modifications to a testing apparatus can impact resulting stiffness values on a large scale, therefore oil field service companies do not perform such tests as controls for such complicated testing are not present.', 'Past attempts at obtaining stiffness values involve inflating an apparatus underground and trying to map a geological response to the inflation.', 'Such prior attempts are very rudimentary and there is an established need to provide an apparatus and testing method that is more rigorous than the prior attempts.', 'Despite field induced complications as well as the potential for various test beds described above, there is a need to obtain sought after geological stiffness values.', 'There is a further need to provide an apparatus as well as methods that are easy to perform for field personnel such that stiffness values may be accurately derived.', 'There is a further need to provide apparatus and methods that do not have the drawbacks discussed above and wherein engineers can accurately ascertain stiffness values of the geological stratum adjacent to the wellbore.', 'There is a still further need to reduce economic costs associated with operations and apparatus.', 'There is a still further need to ascertain stiffness values, as defined and disclosed above as well as through later definition, for a geological stratum regardless of the type and number of packers, pump and associated stiffness of testing apparatus used.', 'SUMMARY\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized below, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted that the drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments without specific recitation.', 'Accordingly, the following summary provides just a few aspects of the description and should not be used to limit the described embodiments to a single concept.', 'In one non-limiting example embodiment, an arrangement is disclosed.', 'The arrangement may comprise a packer system and a fluid delivery system connected to the packer system.', 'The arrangement may also comprise at least one sensor system connected to the packer system and the fluid delivery system, wherein the at least one sensor system is configured to measure at least one of a pressure, a volume of fluid delivered to the packer system and a pressure experienced by the packer system.', 'The arrangement may also comprise at least one computing system configured to obtained data related to the at least one of the pressure, the volume of fluid delivered to the packer system, and the pressure experienced by the packer system and calculate a geological stiffness factor.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.\n \nFIG.', '1\n is a drill rig performing a hydrocarbon recovery operation in one aspect of the disclosure.\n \nFIG.', '2\n is a cross-section of a wireline operation of the wellbore established in \nFIG.', '1\n conducting wireline formation tests on a formation.', 'FIG.', '3\n is a method of performing a test on a geological stratum in accordance with one example embodiment of the disclosure.\n \nFIG.', '4\n is a method of performing the PMT calibration portion of the test on the geological stratum of \nFIG.', '3\n.', 'FIG.', '5\n is a method of performing the PMT measurement portion of the test on the geological stratum of \nFIG.', '3\n.', 'FIG.', '6\n is a graph of a full deflation, increasing pressure protocol that may be used with the method of performing the PMT calibration portion of \nFIG.', '4\n or PMT measurement portion of \nFIG.', '5\n.', 'FIG.', '7\n is a second graph of constant partial deflation protocol that may be used when performing the PMT calibration portion of \nFIG.', '4\n or PMT measurement portion of \nFIG.', '5\n.', 'FIG.', '8\n is a third graph of increasing pressure with cycles protocol that may be used when performing the PMT calibration portion of \nFIG.', '4\n or PMT measurement portion of \nFIG.', '5\n.', 'FIG.', '9\n is a graph of three stiffnesses as a function of pressure.\n \nFIG.', "10\n is a graph of elastic modulus, Young's and shear moduli, as a function of pressure.\n \nFIG.", '11\n is a computer apparatus used in performing a method described in \nFIG.', '3\n and controlling apparatus for the wireline operations of \nFIG.', '2\n.', 'FIG.', '12\n is a graph of pressure vs. volume pertaining to analysis performed by the method embodiment described.\n \nFIG.', '13\n is a graph of stiffness vs. volume pertaining to analysis performed by the method embodiment described.\n \nFIG.', '14\n is a graph of stiffness vs. pressure pertaining to analysis performed by the method embodiment described.', 'To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures (“FIGS”).', 'It is contemplated that elements disclosed in one embodiment may be beneficially utilized on other embodiments without specific recitation.', 'DETAILED DESCRIPTION', 'In the following, reference is made to embodiments of the disclosure.', 'It should be understood, however, that the disclosure is not limited to specific described embodiments.', 'Instead, any combination of the following features and elements, whether related to different embodiments or not, is contemplated to implement and practice the disclosure.', 'Furthermore, although embodiments of the disclosure may achieve advantages over other possible solutions and/or over the prior art, whether or not a particular advantage is achieved by a given embodiment is not limiting of the disclosure.', 'Thus, the following aspects, features, embodiments and advantages are merely illustrative and are not considered elements or limitations of the claims except where explicitly recited in a claim.', 'Likewise, reference to “the disclosure” shall not be construed as a generalization of inventive subject matter disclosed herein and should not be considered to be an element or limitation of the claims except where explicitly recited in a claim.', 'Although the terms first, second, third, etc., may be used herein to describe various elements, components, regions, layers and/or sections, these elements, components, regions, layers and/or sections should not be limited by these terms.', 'These terms may be only used to distinguish one element, component, region, layer or section from another region, layer or section.', 'Terms such as “first”, “second” and other numerical terms, when used herein, do not imply a sequence or order unless clearly indicated by the context.', 'Thus, a first element, component, region, layer or section discussed herein could be termed a second element, component, region, layer or section without departing from the teachings of the example embodiments.', 'When an element or layer is referred to as being “on,” “engaged to,” “connected to,” or “coupled to” another element or layer, it may be directly on, engaged, connected, coupled to the other element or layer, or interleaving elements or layers may be present.', 'In contrast, when an element is referred to as being “directly on,” “directly engaged to,” “directly connected to,” or “directly coupled to” another element or layer, there may be no interleaving elements or layers present.', 'Other words used to describe the relationship between elements should be interpreted in a like fashion.', 'As used herein, the term “and/or” includes any and all combinations of one or more of the associated listed terms.', 'Some embodiments will now be described with reference to the figures.', 'Like elements in the various figures will be referenced with like numbers for consistency.', 'In the following description, numerous details are set forth to provide an understanding of various embodiments and/or features.', 'It will be understood, however, by those skilled in the art, that some embodiments may be practiced without many of these details, and that numerous variations or modifications from the described embodiments are possible.', 'As used herein, the terms “above” and “below”, “up” and “down”, “upper” and “lower”, “upwardly” and “downwardly”, and other like terms indicating relative positions above or below a given point are used in this description to more clearly describe certain embodiments.', 'Embodiments for drilling of a wellbore will first be described.', 'Once the wellbore is established, wireline operations may be used, in embodiments, as described in \nFIG.', '2\n, to perform testing of geological stratum penetrated by the wellbore.', 'Such testing will include pressure meter testing to determine a stiffness value for a geological stratum in question.', 'Methods to perform operational activities can be controlled by a computer running predefined computer programs.', 'An example computer is described in relation to \nFIG.', '11\n.', 'This computer may also help operations personnel control various method steps in the process of determining a stiffness value, as recited in \nFIG. \n3\n.', 'Although described as being associated with wireline operations described in \nFIG.', '2\n, embodiments may be performed “while drilling”, as described in \nFIG.', '1\n with modification to drilling equipment.', 'As a result, the reader should not infer that measurements may only be obtained during wireline operations.', 'Referring to \nFIG.', '1\n, a drilling rig \n100\n is illustrated.', 'The purpose of the drilling rig \n100\n is to recover hydrocarbons located beneath the surface \n110\n.', 'Different stratum \n104\n may be encountered during the creation of a wellbore \n102\n.', 'In \nFIG.', '1\n, a single stratum \n104\n layer is provided.', 'As will be understood, multiple layers of stratum \n104\n may be encountered.', 'Operators, therefore, need to assess the composition of the stratum \n104\n in order to maximize penetration of a drill bit \n106\n that will be used in the drilling process.', 'The wellbore \n102\n is formed within the stratum \n104\n by a drill bit \n106\n.', 'In embodiments, the drill bit \n106\n is rotated such that contact between the drill bit \n106\n and the stratum \n104\n causes portions (“cuttings”) of the stratum \n104\n to be loosened at the bottom of the wellbore \n102\n.', 'Differing types of drill bits \n106\n may be used to penetrate different types of stratum \n104\n.', 'As the wellbore \n102\n penetrates further into the stratum \n104\n, operators may add portions of drill string pipe \n114\n to form a drill string \n112\n.', 'As illustrated in \nFIG.', '1\n, the drill string \n112\n may extend into the stratum \n104\n in a vertical orientation.', 'The drill bit \n106\n is larger in diameter than the drill string \n112\n such that when the drill bit \n106\n produces the hole for the wellbore \n102\n, an annular space \n116\n is created between the drill string \n112\n and the inside face of the wellbore \n102\n.', 'This annular space provides a pathway for removal of cuttings from the wellbore \n102\n.', 'The drilling fluids may be stored in a pit \n127\n located at the drill site.', 'The pit \n127\n may have a liner to prevent the drilling fluids from entering surface groundwater and/or contacting surface soils.', 'Drilling fluid from the pit \n127\n is pumped by a mud pump \n129\n that is connected to a swivel \n119\n.', 'The drill string \n112\n is suspended by a drive \n118\n from a derrick \n120\n.', 'In the illustrated embodiment, the drive \n118\n may be a unit that sits atop the drill string \n112\n and is known in the industry as a “top drive”.', 'Drilling fluid is provided to the drill string \n112\n through a swivel \n119\n suspended by the derrick \n120\n.', 'The drilling fluid exits the drill string \n112\n at the drill bit \n106\n and has several functions in the drilling process.', 'The drilling fluid is used to cool the drill bit \n106\n and remove the cuttings generated by the drill bit \n106\n.', 'The drilling fluid with the loosened cuttings enter the annular area outside of the drill string \n112\n and travel up the wellbore \n102\n to a shaker \n109\n.', 'The shaker \n109\n is configured to separate the cuttings from the drilling fluid.', 'The cuttings, after separation, may be analyzed by operators to determine if the stratum \n104\n currently being penetrated has hydrocarbons stored within the stratum \n104\n level that is currently being penetrated by the drill bit \n106\n.', 'The drilling fluid is then recirculated to the pit \n127\n through the recirculation line \n126\n.', 'As will be understood, different wellbores may have different constructions.', 'For example, certain portions of the wellbore may have open sections, and certain sections may be cased hole section.', 'Embodiments described herein may be used with different constructed wellbore embodiments and those discussed should not be considered limiting.', 'Wireline operations are performed after the creation of the wellbore \n102\n as described in \nFIG.', '1\n.', 'Wireline operations may be accomplished to obtain subsurface petrophysical and geophysical data related to the geological stratum \n104\n encountered by the wellbore \n102\n.', 'Referring to \nFIG.', '2\n, in these operations, a wireline truck \n350\n is provided.', 'The wireline truck \n350\n is provided with a spool \n352\n that houses a cable \n354\n.', 'The cable \n354\n may be a single strand or multiple strand cable unit.', 'The cable \n354\n is configured to allow sensors and equipment to be lowered into the wellbore \n102\n such that the sensors and equipment may conduct required surveys.', 'The lowering action may be accomplished by a motor \n356\n that is connected to the spool \n352\n.', 'Within the wireline truck \n350\n, an operator may activate and deactivate the motor \n356\n and control associated gearing to allow the spool \n352\n to unwind the cable \n354\n at a desired rate.', 'Sensors \n358\n may be provided to ascertain the amount of cable \n354\n that has been unspooled to allow the operator to identify the location of equipment suspended by the cable \n354\n.', 'Equipment supported by the cable \n354\n can be a single instrument package or multiple instrument packages.', 'In the case of multiple instrument packages, such instrument packages may be modular such that different types of packages may be added together according to the needs of the operator.', 'Different types of packages may include, but not be limited to: \n \n \n \nPacker systems\n \nPressure meter testing systems\n \nNuclear measurement systems\n \nOptical spectrometry systems\n \nPressure monitoring systems\n \nResistivity calculation systems\n \nSonic and ultrasonic tool systems\n \nBorehole seismic tool systems\n \nNuclear magnetic resonance tool systems\n \nPressure control systems\n \nTractor and motion enhancement systems\n \nPower Generation systems\n \nTelemetry and Data recordation systems\n \nComputing systems\n \n \n \n \n \nGenerally, the different modular systems described above may be added together, as needed, to form a logging tool \n360\n that may be called or known as a sonde.', 'The logging tool \n360\n is lowered into the wellbore \n102\n to a desired point in the geological stratum \n104\n and the appropriate system is actuated.', 'The wireline operator may take sensor readings at one point or may take multiple readings while changing the elevation of the logging tool \n360\n.', 'The resulting string of measurements may be called a “log”.', 'Wireline operations may also be used in remediation of a wellbore \n102\n in order to increase production of hydrocarbons.', 'Such operations, known as remediation or “workovers” may include augmenting existing wellbore \n102\n parameters.', 'In embodiments herein, measurements may be made during times where sensors and equipment are non-moving.', 'Such non-movement acquisition is defined as a “station” measurement as opposed to a “log” where data is acquired during movement of a tool.', 'In the instance of non-vertical wells, wireline operations may be augmented through the use of tractors that allow for the tools to reach more horizontally positioned portions of a wellbore.', 'Such horizontal portions of a wellbore may be found, for example, in wells involving fracking operations where a “pay zone” is deposited horizontally parallel to the ground surface.', 'To reach the near horizontal positions of such a wellbore, a tractor that grips the sides of the wellbore may be used to convey instrument packages to the desired position in the wellbore.', 'In the following description, description is provided related to measurements obtained during wireline operations generally performed, as described above.', 'As will be understood, various changes and alterations may be accomplished during the attainment of the desired measurements, and as such, methods described should not be considered limiting.', 'In embodiments, formation stiffness is desired to be calculated through use of a wirelines apparatus described in relation to \nFIG.', '2\n.', 'Such calculations are performed through use of a pressure meter testing apparatus described later.', 'Conventional apparatus and methods cannot accurately derive formation stiffness values in an economic manner.', 'For purposes of definition, stiffnesses in units of Pascal/m3.', 'This quantity is extracted from pressure-volume curve, that will be related to the shear modulus (or shear stiffness in Pascal) by multiplying the stiffness in Pa by a volume quantity in m3.', 'Three factors are provided herein to enable the use of pressure meter testing to obtain stiffness values for in-situ geological stratum.', 'The first factor relates to hardware.', 'Embodiments of the disclosure provide for specific hardware components that are used to accurately obtain stiffness values.', 'These hardware components include a single packer system or multiple packers that are lowered into the wellbore in order to isolate a section of formation for testing.', 'In one non-limiting embodiment, packers used in conjunction with pressure meter testing are relatively “stiff” compared to conventional packers.', 'The use of packers that are “stiff” provide for an increased overall stiffness of the test bed apparatus (defined as all of the components used to conduct the test), thereby resulting in more accurate geological stiffness measurement values.', 'It should be noted, however, that different types of packers may be used in conjunction with the remainder of the selected tools, and that stiffness values may be obtained from conventional or “non-stiff” packers.', 'Experimental testing has identified that increasing the overall stiffness of the test bed apparatus results in superior calculated values.', 'In embodiments, the packers used herein may be separate units from a sensor system that is used or the packers may have sensors as an integral part of the configuration.', 'A second factor provided herein relates to calibration of the test bed apparatus and wellbore undergoing testing.', 'In embodiments, calibration occurs for a cemented or “cased” steel wellbore.', 'As each field constructed wellbore can vary, knowledge of the actual thickness of the cementing project as well as the thickness and type of steel used in formation of the wellbore establishes a well-known assemblage of parameters that can be used in the third factor.', 'The third factor is interpretation of results obtained from the tested wellbore.', 'Using the “known” wellbore construction values obtained in the second factor, values obtained during the testing regime described later can provide for derivation of geological stiffness values based upon the known or calibrated wellbore construction.', 'Referring to \nFIG.', '3\n, a method \n300\n for performing a test on a geological stratum is illustrated.', 'The method \n300\n provides, at \n302\n, selecting a type and number of packers that will be used in the test bed apparatus.', 'In one example embodiment, two packers that have a greater stiffness compared to stiffness of conventional packers are chosen.', 'Other embodiments may use conventional packers if an especially stiff test bed apparatus is not needed.', 'At \n302\n, a single packer may be specified for use with a “dummy” or “can” packer that is essentially a packer that is not expandable.', 'The use of any number of packers should not be considered limiting.', 'As by further definition, a single packer installation has one expandable packer with no “dummy” or “can” packer.', 'Further referring to \nFIG.', '3\n, at \n304\n, a tool string is chosen to interface with the packer(s) selected at \n302\n.', 'The tool string may include, for example, a pump, fluid delivery systems, valving systems, safety systems, sensor systems and control systems.', 'As will be understood, different types of pumps may be selected, such as high volume-low pressure pumps, low volume-high pressure pumps, medium volume-medium pressure pumps and various combinations of the types described above.', 'Fluid delivery systems may include piping to deliver a fluid, such as water or other non-compressible fluid, down to the packer/double packer configuration.', 'The fluid can include, for example, tap water, filtered water, de-aired water, Glycerin, or other fluids.', 'The piping may be made of different types of materials.', 'Types of materials may include carbon steel or stainless steel, as non-limiting embodiments.', 'Different geometries of pipe may be selected, including thin-walled piping/tubing to extra-heavy walled pipe.', 'Selection of the different properties will allow for a relatively stiffer or weaker overall stiffness for the test bed apparatus.', 'As will be understood, having prior knowledge of a range of packer stiffness that is available as well as having prior information on the formation, a recommendation of a suitable packer may be performed based upon the field and equipment limitations.', 'Safety systems selected may allow for single or redundant/single failure proof designs to ensure proper testing actuation.', 'In embodiments, different displacement units may be specified for use with the remainder of the tool string.', 'After selection of the components of the tool string and packers in steps \n302\n and \n304\n, the tool string may be assembled at \n306\n and deployed into the wellbore.', 'At \n308\n, air is purged from the tool string assembled at \n306\n.', 'The purpose of purging the tool string of any air present allows for modulation of the fluids to the packers selected in step \n302\n to provide a true non-compressible status for the tool string.', 'At \n310\n, a test may be conducted with the tool string after purging of the air.', 'Testing performed at \n310\n may be conducted in two parts, namely a PMT calibration portion and a PMT measurement portion.', 'The PMT calibration portion is described in relation to \nFIG.', '4\n.', 'The PMT measurement portion is described in relation to \nFIG.', '5\n.', 'Referring to \nFIG.', '4\n, a calibration portion of the testing performed in \nFIG.', '3\n is illustrated.', 'The calibration portion provides a method \n400\n that involves, at \n402\n, placing the assembled testing apparatus assembled in \n306\n to a calibration testing position.', 'In embodiments, placement of the apparatus deep within the borehole provides results that are acceptable.', 'At \n404\n, a series of inflation and deflation cycles are performed within the wellbore.', 'Different inflation and deflation cycles may be used, with example alternatives described in \nFIGS.', '6\n, \n7\n and \n8\n.', 'During the series of inflation and deflation cycles, pressure is measured as a function of injected volume at all points in the inflation and deflation cycle.', 'At \n406\n, the pressure vs. volume data obtained at \n404\n are processed to obtain a value of stiffness as a function of pressure or deformation or volume.', 'In instances where the wellbore has a casing that is cemented in place and is well bonded, an effective casing stiffness can be inferred.', 'This effective casing stiffness can be used to infer tool stiffness (pump, flow line+packer).', 'As will be understood, various embodiments of the above may be accomplished.', 'These embodiments may measure volume injected and/or measure cavity deformation.', 'As will be further understood, embodiments described below relate to injected volumes and calculations based upon injected volumes, however, as will be understood by a person skilled in the art, cavity deformation may also be used.', 'In embodiments, effective casing stiffness is defined as M\nc \nand the measured stiffness in the casing as M\nmc \nfrom which the packer stiffness M\ns\n, the stiffness of the hydraulic system (pump+flowline+packer+fluid) is defined from the equation below:\n \n \n \n \n \n \n \n \n \nM\n \ns\n \n \n=\n \n \n \n \nM\n \nc\n \n \n\u2062\n \n \nM\n \n \nm\n \n\u2062\n \nc\n \n \n \n \n \n \nM\n \nc\n \n \n-\n \n \nM\n \n \nm\n \n\u2062\n \nc\n \n \n \n \n \n \n \n \n \nEQUATION\n \n\u2062\n \n \n \n1\n \n \n \n \n \n \n \n \nOnce M\ns \nhas been calculated according to equation 1, the formation stiffness may be inferred from a PMT test conducted in \nFIG.', '5\n.', 'In some instances, casing may not be used within a wellbore.', 'Aspects of the disclosure may also be used in this instance.', 'When casing is not present, calibration may occur in a very stiff portion of the formation where there is a known stiffness or where the stiffness can be correctly approximated.', 'In instances where a very stiff portion of the formation is not available, embodiments provide for performing calibration in a portion of the wellbore that is the stiffest and then refer this stiffness of all other formations in reference to the chosen point of stiffness (in relative terms).', 'Referring to \nFIG.', '5\n, pressure meter testing of the formation is described.', 'As provided above, after conducting a calibration test in relation to \nFIG.', '4\n, the pressure meter testing may be accomplished.', 'In this method \n500\n, the packer or series of packers may be moved to the target formation \n502\n.', 'At \n504\n, a series of inflation and deflation protocols may be accomplished.', 'Different protocols may be used, with non-limiting example protocols described in \nFIGS.', '6\n, \n7\n and \n8\n.', 'At \n506\n, during the series of inflation and deflation protocols, data on the pressures encountered and fluid volumes used are recorded.', 'The previously derived value M\ns \nof tool stiffness is recalled.', 'The measured pressure injected volumes in the formation are processed and produce a measured stiffness in the formation M\nm \naccording to the following equation.', 'Mm is defined as measured stiffness in formation and M\nR \nis the formation stiffness Using the values M\ns \nand M\nm \nthe formation stiffness M\nR \nmay be calculated from equation 2.\n \n \n \n \n \n \n \n \n \nM\n \nR\n \n \n=\n \n \n \n \nM\n \ns\n \n \n\u2062\n \n \nM\n \nm\n \n \n \n \n \nM\n \ns\n \n \n-\n \n \nM\n \nm', 'EQUATION\n \n\u2062\n \n \n \n2', 'In addition to the above, a static in-situ shear modulus G may be obtained from the value M\nR \nusing values of contact length L of a packer and borehole radius r\nb \nthrough the use of equation 3.', 'G=M\nR \nπ L r\nb\n2 \n\u2003\u2003EQUATION 3 \n \nThe static in-situ modulus G can be reported as a single value independent of pressure or a function of pressure which may be an indication of the specific mechanical properties of the target formation.', "Using the in-situ module G, the Young's modulus can be calculated from a known Poisson's ratio and vise-versa.", 'Processing of the data obtained from the field testing may be accomplished in the field, if desired.', 'The basic processing consists of calculating the change in pressure as a function of the change in injected volume.', 'That is the gradient of the pressure with respect of the injected volume.', 'This is the stiffness and has units of pressure per unit of volume.', 'In one example embodiment, reported values may be in values of Pa/m\n3\n.', 'In embodiments, smoothing filters may be used for calculated values to eliminate distortions in the data.', 'In one example embodiment, a moving average window may be used to eliminate noisy data.', 'The size of the window may be selected according to the amount of data and the noise level as example factors.', 'In other example embodiments, curve fitting may be used.', 'Example embodiments may include, but not be limited to: \n \n \n \nLocal gradient and moving average smoothing\n \nLocal polynomial fits of degree n (n=1, 2, 3, . . . )', 'and data range m\n \nSavizky-Golay finite impulse response (RIR) smoothing filters\n \nSmooth Spline\n \n \n \n \n \nAfter such fitting, the gradient (dP/dV) is performed on the fitted/smoother function.', 'This will provide a smoother result.', 'Volume and pressure corrections may also be performed.', 'In embodiments, the pressure (P) and injected volume (V) into the packer or packers may be accounted for in some embodiments.', 'As will be understood, correction of data due to volume and pressure may be accomplished in some embodiments and not accomplished in others.', 'For example, volume and pressure corrections may be insignificant to other sources of error, therefore volume and pressure corrections may be omitted.', 'In some examples, sources of error may be minimized and the volume and pressure corrections may be more significant with respect to overall error.', 'In these instances, volume and pressure corrections may be performed.', 'Pressure and volume corrections may include error developed from the influence of inflating the packer, as there may be some pressure that is spent on inflating the packer due to packer inherent stiffness, therefore the amount of pressure being exerted upon the formation may be less.', 'Such pressure and volume corrections may vary according to the size and type of packers used, as a non-limiting embodiment.', 'Referring to \nFIG.', '6\n, a sample inflation protocol is illustrated.', 'This protocol may be used in either calibration (\nFIG.', '4\n) or testing (\nFIG.', '5\n).', 'As illustrated, the graph provides a plot of pressure over time.', 'In the example embodiment, the graph provides pressure in pounds per square inch and the time axis provides time in minutes.', 'As illustrated, pressure in the first step is raised to a value of 1000 psi, with following steps increasing pressure up to 2000 psi, 3000 psi, 4000 psi and 5000 psi.', 'Deflation steps follow each of the inflation steps.', 'Deflation steps may occur incrementally longer in time as the pressure increases.', 'The protocol described in \nFIG.', '6\n provides a simple protocol that may be conducted in the field.', 'This protocol may be performed prior to any sleeve fracturing within the wellbore.', 'Furthermore, this protocol may provide a stiffness at lower pressure compared to other inflation protocols described below.\n \nFIG.', '7\n illustrates a second inflation protocol that may be used.', 'This inflation protocol, similar to that in \nFIG.', '6\n, may be used in either calibration or testing.', 'As illustrated, the graph provides a plot of pressure over time.', 'In the example embodiment, the graph provides pressure in pounds per square inch and the time axis provides time in minutes.', 'As illustrated, pressure in the first step is raised to a value of 2500 psi followed by a partial deflation to 1000 psi.', 'This is followed by a subsequent inflation to 3500 psi followed by a partial deflation 1000 psi.', 'Each subsequent inflation may increase to 4500 psi and 5500 psi with deflations back to 1000 psi.', 'Referring to \nFIG.', '8\n, a third inflation protocol is illustrated.', 'As with the protocols described in relation to \nFIG.', '6\n and \nFIG.', '7\n, the third inflation protocol may be used in relation to both calibration and testing.', 'As illustrated, the graph provides a plot of pressure over strain (actually pressure vs time and strain vs time are used for a pressure-strain plot).', 'In the example embodiment, the graph provides pressure in pounds per square inch and the time axis provides time in minutes.', 'As illustrated, pressure may be increased over time with the results recorded.', 'Referring to \nFIG.', '9\n, a graph of stiffness as a function of pressure is illustrated.', 'Three data sets are illustrated in the graph.', 'These data sets include, descending from the top of the graph, sample stiffness M\nR\n, packer stiffness M\ns \nand measured stiffness M\nm\n.', 'Tests were accomplished with de-aired water, however, other suitable fluids can be used, such as tap water, distilled water, Glycerin, or the like, used as the working fluid (pumped fluid).', 'Sample stiffness M\nR \nwere calculated using a length (L) of 1.82 inches and a length to diameter ratio L/D=2.43.', 'For \nFIG.', '9\n, packer properties used included steel pipe with an ID=0.762 inches and OD=0.999 inches.', 'For measured stiffness values, a LEXAN cylinder with an ID=0.755 inches and an OD=5.098 inches.', 'As can be seen from the plots, sample stiffness can vary somewhat over the range of pressures tested from 0 psi to approximately 2750 psi.', 'Packer stiffness values, after initial inflation occurring at approximately 500 psi, are relatively constant at 2.5×10\n13 \nPa/m\n3\n.', 'Such values are expected as, after inflation, packer stiffness should be constant or approximately constant in value over the pressure range.', 'Measured stiffness follows a similar pattern to that of packer stiffness, wherein after full inflation of the packer(s) at 500 psi, values are consistent over the range of pressure.', 'Aspects of the disclosure provided in \nFIG.', '9\n indicate that lower pressure values may be successfully used in field testing.', 'Such lower required field pressure values are significant as overstressing of the formation does not occur.', 'As testing may be conducted at lower pressures, valuable field time is saved performing such tests compared to higher pressure and longer interval tests.', 'Referring to \nFIG.', '10\n, a graph of elastic moduli vs. pressure is illustrated.', 'The elastic moduli are in units of Pa, while the pressure is in pounds per square inch.', 'Values for static elastic moduli are presented at the top of the graph, while value G represents static in-situ shear modulus, obtained from Eq 3 using measured M\nR \nand known L and r\nb\n.', "Young's modulus can be derived from known or assumed Poisson's ratio.", 'As can be seen, values of both E and G are consistent along the tested pressures from 150 to 2750 psi, indicating that lower pressure tests yield results similar to that of higher test pressures.', 'Referring to \nFIGS. \n12\n to \n14\n, differing graphs of laboratory data have been used to verify the accuracy of the methods described.', 'Aspects of the disclosure described above provide methods that may be performed to achieve a stated goal of determining geological stiffness values as well as controlling components described in the specification.', 'In some embodiments, the methods described may be performed by circuits and/or computers that are configured to perform such tasks.', 'In such embodiments, referring to \nFIG.', '11\n, a computing apparatus \n911\n used in the control of equipment of \nFIG.', '1\n and \nFIG.', '2\n is illustrated.', 'The computing apparatus \n911\n may also be configured to perform operations steps described in \nFIGS.', '3\n, \n4\n and \n5\n.', 'In \nFIG. \n11\n, a processor \n900\n is provided to perform computational analysis for instructions provided.', 'The instruction provided, code, may be written to achieve the desired goal and the processor \n900\n may access the instructions.', 'In other embodiments, the instructions may be provided directly to the processor \n900\n.', 'In other embodiments, other components may be substituted for generalized processors.', 'These specifically designed components, known as application specific integrated circuits (“ASICs”) are specially designed to perform the desired task.', "As such, the ASIC's generally have a smaller footprint than generalized computer processors.", "The ASIC's, when used in embodiments of the disclosure, may use field programmable gate array technology, that allows a user to make variations in computing, as necessary.", 'Thus, the methods described herein are not specifically held to a precise embodiment, rather alterations of the programming may be achieved through these configurations.', 'In embodiments, when equipped with a processor \n900\n, the processor \n900\n may have arithmetic logic unit (“ALU”) \n902\n, a floating point unit (“FPU”) \n904\n, registers \n906\n and a single or multiple layer cache \n908\n.', 'The arithmetic logic unit \n902\n may perform arithmetic functions as well as logic functions.', 'The floating point unit \n904\n may be a math coprocessor or numeric coprocessor to manipulate numbers far efficiently and quickly than other types of circuits.', 'The registers \n906\n are configured to store data that will be used by the processor \n900\n during calculations and supply operands to the arithmetic logic unit \n902\n and store the result of operations.', 'The single or multiple layer caches \n908\n are provided as a storehouse for data to help in calculation speed by preventing the processor \n900\n from continually accessing random access memory (“RAM”) \n914\n.', 'Aspects of the disclosure provide for the use of a single processor \n900\n.', 'Other embodiments of the disclosure allow the use of more than a single processor.', 'Such configurations may be called a multi-core processor where different functions are conducted by different processors to aid in calculation speed.', 'In embodiments, when different processors are used, calculations may be performed simultaneously by different processors, a process known as parallel processing.', 'The processor \n900\n may be located on a motherboard \n910\n.', 'The motherboard \n910\n is a printed circuit board that incorporates the processor \n900\n as well as other components helpful in processing, such as memory modules (“DIMMS”) \n912\n, random access memory \n914\n, read only memory, non-volatile memory chips \n916\n, a clock generator \n918\n that keeps components in synchronization, as well as connectors for connecting other components to the motherboard \n910\n.', 'The motherboard \n910\n may have different sizes according to the needs of the computer architect.', 'To this end, the different sizes, known as form factors, may vary from sizes from a cellular telephone size to a desktop personal computer size.', 'The motherboard \n910\n may also provide other services to aid in functioning of the processor \n900\n, such as cooling capacity.', 'Cooling capacity may include a thermometer \n920\n and a temperature controlled fan \n922\n that conveys cooling air over the motherboard \n910\n to reduce temperature.', 'Data stored for execution by the processor \n900\n may be stored in several locations, including the random access memory \n914\n, read only memory \n915\n, flash memory \n924\n, computer hard disk drives \n926\n, compact disks \n928\n, floppy disks \n930\n and solid state drives \n932\n.', 'For booting purposes, data may be stored in an integrated chip called an EEPROM, that is accessed during start-up of the processor \n900\n.', 'The data, known as a Basic Input/Output System (“BIOS”), contains, in some example embodiments, an operating system that controls both internal and peripheral components.', 'Different components may be added to the motherboard or may be connected to the motherboard to enhance processing.', 'Examples of such connections of peripheral components may be video input/output sockets, storage configurations (such as hard disks, solid state disks, or access to cloud based storage), printer communication ports, enhanced video processors, additional random access memory and network cards.', 'The processor and motherboard may be provided in a discrete form factor, such as personal computer, cellular telephone, tablet, personal digital assistant or other component.', 'The processor and motherboard may be connected to other such similar computing arrangement in networked form.', 'Data may be exchanged between different sections of the network to enhance desired outputs.', 'The network may be a public computing network or may be a secured network where only authorized users or devices may be allowed access.', 'As will be understood, method steps for completion may be stored in the random access memory, read only memory, flash memory, computer hard disk drives, compact disks, floppy disks and solid state drives.', 'Different input/output devices may be used in conjunction with the motherboard and processor.', 'Input of data may be through a keyboard, voice, Universal Serial Bus (“USB”) device, mouse, pen, stylus, Firewire, video camera, light pen, joystick, trackball, scanner, bar code reader and touch screen.', 'Output devices may include monitors, printers, headphones, plotters, televisions, speakers and projectors.', 'In one non-limiting embodiment, a method is disclosed.', 'The method may comprise selecting a packer system for testing a geological formation and choosing components for testing the geological formation.', 'The method may further comprise assembling the tool string components and the packer system into a test bed assembly.', 'The method may also comprise positioning the test bed assembly tool string components into a wellbore placed within the geological formation.', 'The method may further comprise performing a pressure meter test on the formation.', 'In one non-limiting embodiment, a method may be performed wherein the performing the pressure meter test has a calibration portion and a testing portion.', 'In one non-limiting embodiment, a method may be performed wherein the calibration portion comprises: placing the assembled tool string into a calibration testing position; conducting a series of inflation and deflation cycles with the tool string; obtaining data of pressure and volume from the series of inflation and deflation cycles; and processing the obtained data of pressure and volume to obtain a stiffness value of the tool string.', 'In one non-limiting embodiment, a method may be performed wherein at least one volume and pressure correction is performed on the data of pressure and volume from the series of inflation and deflation cycles.', 'In one non-limiting embodiment, a method may be performed wherein at least one volume and pressure correction is performed on the data of pressure and volume from the second series of inflation and deflation cycles.', 'In one non-limiting embodiment, a method may be performed wherein the testing portion comprises placing the assembled tool string into a testing position, conducting a second series of inflation and deflation cycles with the tool string, obtaining data of pressure and volume from the second series of inflation and deflation cycles and processing the obtained data of pressure and volume to obtain a stiffness value of the formation.', 'In one non-limiting embodiment, the method may be performed wherein smoothing filters are used on the obtained data of pressure and volume from at least one of the series of inflation and deflation cycles and the second series of inflation and deflation cycles.', 'In one non-limiting embodiment, the method may be performed wherein the choosing the components for testing the geological formation includes selecting a pump and a fluid delivery system.', 'In one non-limiting embodiment, the method may be performed wherein the calibration portion is performed in a section of the wellbore with a casing.', 'In one non-limiting embodiment, the method may be performed wherein the calibration portion is performed in a section of the wellbore without a casing.', 'In one non-limiting embodiment, the method may be performed wherein the method is performed on wireline.', 'In one non-limiting embodiment, the method may be performed while drilling.', 'In one non-limiting embodiment, the method may be performed wherein the selecting the packer system for testing the geological formation includes selecting a double packer arrangement.', 'In one non-limiting embodiment, the method may be performed wherein the selecting the packer system of testing the geological formation includes selecting a single packer arrangement.', 'In one non-limiting example embodiment, an arrangement is disclosed.', 'The arrangement may comprise a packer system and a fluid delivery system connected to the packer system.', 'The arrangement may also comprise at least one sensor system connected to the packer system and the fluid delivery system, wherein the at least one sensor system is configured to measure at least one of a pressure, a volume of fluid delivered to the packer system and a pressure experienced by the packer system.', 'The arrangement may also comprise at least one computing system configured to obtained data related to the at least one of the pressure, the volume of fluid delivered to the packer system and the pressure experienced by the packer system and calculate a geological stiffness factor.', 'In another example embodiment, the arrangement may be configured wherein the fluid delivery system includes a pump.', 'In another example embodiment, the arrangement may be configured wherein the fluid delivery system further comprises a piping system.', 'In another example embodiment, the arrangement may be configured wherein the packer system is configured with a single inflatable packer.', 'In another example embodiment, the arrangement may be configured wherein the packer system is configured with at least one non-inflatable packer.', 'In another example embodiment, the arrangement may be configured wherein the arrangement is configured to be delivered by a wireline.', 'The foregoing description of the embodiments has been provided for purposes of illustration and description.', 'It is not intended to be exhaustive or to limit the disclosure.', 'Individual elements or features of a particular embodiment are generally not limited to that particular embodiment, but, where applicable, are interchangeable and can be used in a selected embodiment, even if not specifically shown or described.', 'The same may be varied in many ways.', 'Such variations are not to be regarded as a departure from the disclosure, and all such modifications are intended to be included within the scope of the disclosure.', 'While embodiments have been described herein, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments are envisioned that do not depart from the inventive scope.', 'Accordingly, the scope of the present claims or any subsequent claims shall not be unduly limited by the description of the embodiments described herein.']

['1.', 'A method, comprising:\nassembling a logging tool for measuring a pressure within a portion of a wellbore, wherein the logging tool comprises one or more sensors and one or more packers;\npositioning the logging tool into the portion of the wellbore, wherein the one or more packers are positioned in a section of a geological formation associated with the portion of the wellbore;\npurging air from the logging tool; and\nperforming a pressure meter test on the section of the geological formation, wherein the pressure meter test comprises: performing a series of inflation and deflation cycles within the section of the geological formation; and receiving a plurality of pressure and volume measurements associated with the section of the geological formation from the one or more sensors during the series of inflation and deflation cycles.', '2.', 'The method according to claim 1, wherein the performing the pressure meter test comprises a calibration portion and a testing portion.', '3.', 'The method according to claim 2, wherein the calibration portion comprises:\nplacing the logging tool into a calibration testing position;\nconducting a first series of inflation and deflation cycles with the logging tool;\nobtaining data of pressure and volume measurements associated with the first series of inflation and deflation cycles; and\nprocessing the obtained data of pressure and volume measurements to obtain a stiffness value of the logging tool.\n\n\n\n\n\n\n4.', 'The method according to claim 3, wherein at least a portion of the data of pressure and volume measurements corresponds to a proxy for a cavity deformation.', '5.', 'The method according to claim 3, wherein at least one volume and pressure correction is performed on the data of pressure and volume measurements based on the first series of inflation and deflation cycles.', '6.', 'The method according to claim 3, wherein at least one volume and pressure correction is performed on the data of pressure and volume measurements based on a second series of inflation and deflation cycles.', '7.', 'The method according to claim 3, further comprising:\nusing smoothing filters on the obtained data of pressure and volume measurements associated with the first series of inflation and deflation cycles.', '8.', 'The method according to claim 2, wherein the testing portion comprises:\nplacing the logging tool into a testing position;\nconducting a one of the series of inflation and deflation cycles with the logging tool;\nobtaining data of pressure and volume measurements associated with the one of the series of inflation and deflation cycles; and\nprocessing the obtained data of pressure and volume measurements to obtain a stiffness value of the section of the geological formation.', '9.', 'The method according to claim 2, wherein the calibration portion is performed in the portion of the wellbore with a casing.', '10.', 'The method according to claim 2, wherein the calibration portion is performed in the portion of the wellbore without a casing.', '11.', 'The method according to claim 1, further comprising pumping one or more fluids into the wellbore via a pump.\n\n\n\n\n\n\n12.', 'The method according to claim 1, wherein the method is performed on wireline.', '13.', 'The method according to claim 1, wherein the method is performed while drilling.', '14.', 'The method according to claim 1, wherein the one or more packers for testing the section of the geological formation comprises a double packer arrangement.', '15.', 'The method according to claim 1, wherein the one or more packers for testing the section of the geological formation comprises a single packer arrangement.', '16.', 'A method, comprising\nassembling a logging tool for measuring a pressure within a portion of a wellbore, wherein the logging tool comprises one or more sensors and one or more packers;\npositioning the logging tool into the portion of the wellbore, wherein the one or more packers are positioned in a section of a geological formation associated with the portion of the wellbore;\npurging air from the logging tool;\nperforming a pressure meter test on the section of the geological formation, wherein the pressure meter test comprises: performing a series of inflation and deflation cycles within the section of the geological formation; and receiving a plurality of pressure and volume measurements associated with the section of the geological formation from the one or more sensors during the series of inflation and deflation cycles;\ncalculating a geological stiffness factor based on the plurality of pressure and volume measurements; and\nestimating an elastic shear modulus based on the calculated geological stiffness factor.', '17.', 'The method according to claim 16, wherein the estimating the elastic shear modulus is performed as a function of the pressure.']

['FIG.', '1 is a drill rig performing a hydrocarbon recovery operation in one aspect of the disclosure.', '; FIG.', '2 is a cross-section of a wireline operation of the wellbore established in FIG.', '1 conducting wireline formation tests on a formation.;', 'FIG. 3 is a method of performing a test on a geological stratum in accordance with one example embodiment of the disclosure.', '; FIG.', '4 is a method of performing the PMT calibration portion of the test on the geological stratum of FIG.', '3.; FIG.', '5 is a method of performing the PMT measurement portion of the test on the geological stratum of FIG.', '3.; FIG. 6 is a graph of a full deflation, increasing pressure protocol that may be used with the method of performing the PMT calibration portion of FIG.', '4 or PMT measurement portion of FIG.', '5.; FIG. 7 is a second graph of constant partial deflation protocol that may be used when performing the PMT calibration portion of FIG.', '4 or PMT measurement portion of FIG.', '5.; FIG. 8 is a third graph of increasing pressure with cycles protocol that may be used when performing the PMT calibration portion of FIG.', '4 or PMT measurement portion of FIG.', '5.; FIG. 9 is a graph of three stiffnesses as a function of pressure.; FIG.', "10 is a graph of elastic modulus, Young's and shear moduli, as a function of pressure.; FIG.", '11 is a computer apparatus used in performing a method described in FIG.', '3 and controlling apparatus for the wireline operations of FIG.', '2.; FIG.', '12 is a graph of pressure vs. volume pertaining to analysis performed by the method embodiment described.; FIG. 13 is a graph of stiffness vs. volume pertaining to analysis performed by the method embodiment described.; FIG.', '14 is a graph of stiffness vs. pressure pertaining to analysis performed by the method embodiment described.; FIG.', '7 illustrates a second inflation protocol that may be used.', 'This inflation protocol, similar to that in FIG. 6, may be used in either calibration or testing.', 'As illustrated, the graph provides a plot of pressure over time.', 'In the example embodiment, the graph provides pressure in pounds per square inch and the time axis provides time in minutes.', 'As illustrated, pressure in the first step is raised to a value of 2500 psi followed by a partial deflation to 1000 psi.', 'This is followed by a subsequent inflation to 3500 psi followed by a partial deflation 1000 psi.', 'Each subsequent inflation may increase to 4500 psi and 5500 psi with deflations back to 1000 psi.']

US11821269

Swivel system for downhole well tool orientation

May 3, 2022

Mark Callister Oettli

SCHLUMBERGER TECHNOLOGY CORPORATION

McMaster-Carr, Zinc-Plated Steel Hose Fitting for Hydraulic Fluid, Straight Adapter, 1/2 NPSM Female x 1/2 NPTF Male, retreived from https://www.mcmaster.com/5340K48/, 2021, 2 pages.; McMaster-Carr, Pipe Unions, retrieved from https://www.mcmaster.com/pipe-unions/type˜rotating-joint/, 2022, 2 pages.; International Search Report and Written Opinion issued in International Patent application PCT/US2023/020777 dated Aug. 25, 2023, 9 pages.

3136367; June 1964; Wright; 4100976; July 18, 1978; Stone; 4278942; July 14, 1981; Bonnet; 5468153; November 21, 1995; Brown et al.; 5823257; October 20, 1998; Peyton; 6032958; March 7, 2000; Fowler; 6241032; June 5, 2001; Falgout, Sr.; 6244345; June 12, 2001; Helms; 6899174; May 31, 2005; Maxwell; 7178611; February 20, 2007; Zupanick; 10036228; July 31, 2018; Coronado; 10844668; November 24, 2020; Gonzalez; 20030075321; April 24, 2003; Hall; 20130008669; January 10, 2013; Deere; 20150308249; October 29, 2015; Delchambre; 20160201401; July 14, 2016; Craik; 20180175545; June 21, 2018; Engel et al.; 20190085644; March 21, 2019; Ames; 20210013687; January 14, 2021; Lau et al.

Foreign Citations not found.

['Systems and methods presented herein include a downhole well tool having an electromechanical joint configured to connect to a downhole well tool component within a wellbore of an oil and gas well system.', 'The electromechanical joint is configured to rotate to facilitate connection of the electromechanical joint to the downhole well tool component.', 'For example, the electromechanical joint includes a main body portion, a rotating ring configured to rotate relative to the main body portion to facilitate connection of the electromechanical joint to the downhole well tool component, and a sealed electrical connection configured to couple with a mating electrical connection of the downhole well tool component.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThe subject matter disclosed herein relates to systems and methods for enabling rotate of an adapter of a downhole well tool to enable the downhole well tool to couple to a downhole well tool component both mechanically and electrically.', 'This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present techniques, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as an admission of any kind.', 'Certain downhole', 'well tools often need to connect to other downhole well tool components.', 'In such situations, adapters are often used to connect to the other downhole well tool components.', 'Certain adapters and downhole well tool components to which they connect include mono conductor connections, which means that there is only a single radial alignment of the adapter with respect to the downhole well tool component that enables electrical and mechanical coupling of the adapter to the downhole well tool component.', 'In such situations, a cable conveying the downhole well tool having the adapter may need to twist to enable the adapter to couple to the downhole well tool component.', 'However, certain cables are not capable of twisting quite as much as others.', 'For example, coupling of certain adapters to downhole well tool components may be relatively easily achieved when a wireline cable is used, but it may be relatively difficult to enable enough twisting when coiled tubing is used, due at least in part to the relatively high level of torsional stiffness of the coiled tubing.', 'SUMMARY\n \nA summary of certain embodiments disclosed herein is set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.', 'In one embodiment, a downhole well tool adapter includes an electromechanical joint configured to connect to a downhole well tool component within a wellbore of an oil and gas well system.', 'The electromechanical joint is configured to rotate to facilitate connection of the electromechanical joint to the downhole well tool component.', 'In another embodiment, an electromechanical joint includes a main body portion.', 'The electromechanical joint also includes a rotating ring configured to rotate relative to the main body portion to facilitate connection of the electromechanical joint to a downhole well tool component within a wellbore of an oil and gas well system.', 'The electromechanical joint further includes a sealed electrical connection configured to couple with a mating electrical connection of the downhole well tool component.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings in which:\n \nFIG.', '1\n is a schematic illustration of an oil and gas well system, in accordance with embodiments of the present disclosure;\n \nFIG.', '2\n illustrates a well control system that may include a surface processing system to control the oil and gas well system described herein, in accordance with embodiments of the present disclosure;\n \nFIG.', '3\n illustrates a conventional BHA that includes an upper BHA and a lower BHA;\n \nFIG.', '4\n illustrates a BHA having an adapter with a electromechanical joint, in accordance with embodiments of the present disclosure;\n \nFIG.', '5\n is a cross-sectional perspective view of an electromechanical joint and a downhole well tool component to depict how the electromechanical joint enables the adapter to couple both electrically and mechanically using only a mono conductor, in accordance with embodiments of the present disclosure;\n \nFIG.', '6\n is another cross-sectional perspective view of the electromechanical joint and the downhole well tool component of \nFIG.', '5\n, in accordance with embodiments of the present disclosure;\n \nFIG.', '7\n is another cross-sectional perspective view of the electromechanical joint and the downhole well tool component of \nFIGS.', '5\n and \n6\n, in accordance with embodiments of the present disclosure;\n \nFIG.', '8\n is a partial cross-sectional view of the electromechanical joint in the position illustrated in \nFIG.', '7\n, in accordance with embodiments of the present disclosure;\n \nFIG.', '9\n is a partial cross-sectional view of the electromechanical joint, in accordance with embodiments of the present disclosure;\n \nFIG.', '10\n is a perspective view of a bearing system of the electromechanical joint, in accordance with embodiments of the present disclosure; and\n \nFIG.', '11\n is a perspective view of a split ring of the electromechanical joint, in accordance with embodiments of the present disclosure.', 'DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS\n \nOne or more specific embodiments will be described below.', 'In an effort to provide a concise description of these embodiments, not all features of an actual implementation are described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'As used herein, the terms “connect,” “connection,” “connected,” “in connection with,” and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element.”', 'Further, the terms “couple,” “coupling,” “coupled,” “coupled together,” and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements.”', 'As used herein, the terms “up” and “down,” “uphole” and “downhole”, “upper” and “lower,” “top” and “bottom,” and other like terms indicating relative positions to a given point or element are utilized to more clearly describe some elements.', 'Commonly, these terms relate to a reference point as the surface from which drilling operations are initiated as being the top (e.g., uphole or upper) point and the total depth along the drilling axis being the lowest (e.g., downhole or lower) point, whether the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.', 'In addition, as used herein, the terms “automatic” and “automated” are intended to describe operations that are caused to be performed, for example, by an automation control system (i.e., solely by the automation control system, without human intervention).', 'The embodiments described herein relate to a downhole well tool having an electromechanical joint configured to connect to a downhole well tool component within a wellbore of an oil and gas well system.', 'The electromechanical joint is configured to rotate to facilitate connection of the electromechanical joint to the downhole well tool component.', 'For example, the electromechanical joint includes a main body portion, a rotating ring configured to rotate relative to the main body portion to facilitate connection of the electromechanical joint to the downhole well tool component, and a sealed electrical connection configured to couple with a mating electrical connection of the downhole well tool component.', 'With the foregoing in mind, \nFIG.', '1\n is a schematic illustration of an example oil and gas well system \n10\n.', 'As illustrated, in certain embodiments, a coiled tubing string \n12\n may be run into a wellbore \n14\n that traverses a hydrocarbon-bearing formation \n16\n.', 'While certain elements of the oil and gas well system \n10\n are illustrated in \nFIG.', '1\n, other elements of the well (e.g., blow-out preventers, wellhead “tree”, etc.) have been omitted for clarity of illustration.', 'In certain embodiments, the oil and gas well system \n10\n includes an interconnection of pipes, including vertical and/or horizontal casings \n18\n, coiled tubing \n20\n, and so forth, that connect to a surface facility \n22\n at the surface \n24\n of the oil and gas well system \n10\n.', 'In certain embodiments, the coiled tubing \n20\n extends inside the casing \n18\n and terminates at a tubing head (not shown) at or near the surface \n24\n.', 'In addition, in certain embodiments, the casing \n18\n contacts the wellbore \n14\n and terminates at a casing head (not shown) at or near the surface \n24\n.', 'In certain embodiments, a bottom hole assembly (“BHA”) \n26\n may be run inside the casing \n18\n by the coiled tubing \n20\n.', 'As illustrated, in certain embodiments, the BHA \n26\n may include a downhole motor \n28\n that operates to rotate a drill bit \n30\n (e.g., during drilling operations) or other downhole well tool.', 'In certain embodiments, the downhole motor \n28\n may be driven by hydraulic forces carried in fluid supplied from the surface \n24\n of the oil and gas well system \n10\n.', 'In certain embodiments, the BHA \n26\n may be connected to the coiled tubing \n20\n, which is used to run the BHA \n26\n to a desired location within the wellbore \n14\n.', 'It is also contemplated that, in certain embodiments, the rotary motion of the drill bit \n30\n may be driven by rotation of the coiled tubing \n20\n effectuated by a rotary table or other surface-located rotary actuator.', 'In such embodiments, the downhole motor \n28\n may be omitted.', 'In certain embodiments, the coiled tubing \n20\n may also be used to deliver fluid \n32\n to the drill bit \n30\n through an interior of the coiled tubing \n20\n to aid in the drilling process and carry cuttings and possibly other fluid and solid components in return fluid \n34\n that flows up the annulus between the coiled tubing \n20\n and the casing \n18\n (or via a return flow path provided by the coiled tubing \n20\n, in certain embodiments) for return to the surface facility \n22\n.', 'It is also contemplated that the return fluid \n34\n may include remnant proppant (e.g., sand) or possibly rock fragments that result from a hydraulic fracturing application, and flow within the oil and gas well system \n10\n.', 'Under certain conditions, fracturing fluid and possibly hydrocarbons (oil and/or gas), proppants and possibly rock fragments may flow from the fractured formation \n16\n through perforations in a newly opened interval and back to the surface \n24\n of the oil and gas well system \n10\n as part of the return fluid \n34\n.', 'In certain embodiments, the BHA \n26\n may be supplemented behind the rotary drill by an isolation device such as, for example, an inflatable packer that may be activated to isolate the zone below or above it, and enable local pressure tests.', 'As such, in certain embodiments, the oil and gas well system \n10\n may include a downhole well tool \n36\n that is moved along the wellbore \n14\n via the coiled tubing \n20\n.', 'In the illustrated embodiment, the downhole well tool \n36\n includes a drill bit \n30\n, which may be powered by a motor \n28\n (e.g., a positive displacement motor (PDM), or other hydraulic motor) of a BHA \n26\n.', 'In certain embodiments, the wellbore \n14\n may be an open wellbore or a cased wellbore defined by a casing \n18\n.', 'In addition, in certain embodiments, the wellbore \n14\n may be vertical or horizontal or inclined.', 'It should be noted the downhole well tool \n36\n may be part of various types of BHAs \n26\n coupled to the coiled tubing \n20\n.', 'For example, as described in greater detail herein, the BHA \n26\n may be configured to couple to other types of downhole well tools including, but not limited to, downhole plugs such as electrically expandable plugs.', 'As also illustrated in \nFIG.', '1\n, in certain embodiments, the oil and gas well system \n10\n may include a downhole sensor package \n38\n having a plurality of downhole sensors \n40\n.', 'In certain embodiments, the sensor package \n38\n may be mounted along the coiled tubing string \n12\n, although certain downhole sensors \n40\n may be positioned at other downhole locations in other embodiments.', 'In certain embodiments, data from the downhole sensors \n40\n may be relayed uphole to a surface processing system \n42\n (e.g., a computer-based processing system) disposed at the surface \n24\n and/or other suitable location of the oil and gas well system \n10\n.', 'In certain embodiments, the data may be relayed uphole in substantially real time (e.g., relayed while it is detected by the downhole sensors \n40\n during operation of the downhole well tool \n36\n) via a wired or wireless telemetric control line \n44\n, and this real-time data may be referred to as edge data.', 'In certain embodiments, the telemetric control line \n44\n may be in the form of an electrical line, fiber-optic line, or other suitable control line for transmitting data signals.', 'In certain embodiments, the telemetric control line \n44\n may be routed along an interior of the coiled tubing \n20\n, within a wall of the coiled tubing \n20\n, or along an exterior of the coiled tubing \n20\n.', 'In addition, in certain embodiments, additional data (e.g., surface data) may be supplied by surface sensors \n46\n and/or stored in memory locations \n48\n.', 'By way of example, historical data and other useful data may be stored in a memory location \n48\n such as cloud storage \n50\n.', 'As illustrated, in certain embodiments, the coiled tubing \n20\n may deployed by a coiled tubing unit \n52\n and delivered downhole via an injector head \n54\n.', 'In certain embodiments, the injector head \n54\n may be controlled to slack off or pick up on the coiled tubing \n20\n so as to control the tubing string weight and, thus, the weight on bit (WOB) acting on the downhole well tool \n36\n.', 'In certain embodiments, the downhole well tool \n36\n may be moved along the wellbore \n14\n via the coiled tubing \n20\n under control of the injector head \n54\n so as to apply a desired tubing weight.', 'In certain embodiments, fluid \n32\n may be delivered downhole under pressure from a pump unit \n56\n.', 'In certain embodiments, the fluid \n32\n may be delivered by the pump unit \n56\n through the downhole hydraulic motor \n28\n to power the downhole hydraulic motor \n28\n, for example.', 'In certain embodiments, the return fluid \n34\n is returned uphole, and this flow back of return fluid \n34\n is controlled by suitable flow back equipment \n58\n.', 'In certain embodiments, the flow back equipment \n58\n may include chokes and other components/equipment used to control flow back of the return fluid \n34\n in a variety of applications, including well treatment applications.\n \nFIG.', '2\n illustrates a well control system \n60\n that may include the surface processing system \n42\n to control the oil and gas well system \n10\n described herein.', 'In certain embodiments, the surface processing system \n42\n may include one or more analysis modules \n62\n (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, an analysis module \n62\n executes on one or more processors \n64\n of the surface processing system \n42\n, which may be connected to one or more storage media \n66\n of the surface processing system \n42\n.', 'Indeed, in certain embodiments, the one or more analysis modules \n62\n may be stored in the one or more storage media \n66\n.', 'In certain embodiments, the one or more processors \n64\n may include a microprocessor, a microcontroller, a processor module or subsystem, a programmable integrated circuit, a programmable gate array, a digital signal processor (DSP), or another control or computing device.', 'In certain embodiments, the one or more storage media \n66\n may be implemented as one or more non-transitory computer-readable or machine-readable storage media.', 'In certain embodiments, the one or more storage media \n66\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories; magnetic disks such as fixed, floppy and removable disks; other magnetic media including tape; optical media such as compact disks (CDs) or digital video disks (DVDs); or other types of storage devices.', 'Note that the computer-executable instructions and associated data of the analysis module(s) \n62\n may be provided on one computer-readable or machine-readable storage medium of the storage media \n66\n, or alternatively, may be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media are considered to be part of an article (or article of manufacture), which may refer to any manufactured single component or multiple components.', 'In certain embodiments, the one or more storage media \n66\n may be located either in the machine running the machine-readable instructions, or may be located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'In certain embodiments, the processor(s) \n64\n may be connected to a network interface \n68\n of the surface processing system \n42\n to allow the surface processing system \n42\n to communicate with the various downhole sensors \n40\n and surface sensors \n46\n described herein, as well as communicate with the actuators \n70\n and/or PLCs \n72\n of the surface equipment \n74\n (e.g., the coiled tubing unit \n52\n, the pump unit \n56\n, the flowback equipment \n58\n, and so forth) and of the downhole equipment \n76\n (e.g., the BHA \n26\n, the downhole well tool \n36\n, and so forth) for the purpose of controlling operation of the oil and gas well system \n10\n, as described in greater detail herein.', 'In certain embodiments, the network interface \n68\n may also facilitate the surface processing system \n42\n to communicate data to cloud storage \n50\n (or other wired and/or wireless communication network) to, for example, archive the data or to enable external computing systems \n78\n to access the data and/or to remotely interact with the surface processing system \n42\n.', 'It should be appreciated that the well control system \n60\n illustrated in \nFIG.', '2\n is only one example of a well control system, and that the well control system \n60\n may have more or fewer components than shown, may combine additional components not depicted in the embodiment of \nFIG.', '2\n, and/or the well control system \n60\n may have a different configuration or arrangement of the components depicted in \nFIG.', '2\n.', 'In addition, the various components illustrated in \nFIG.', '2\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'Furthermore, the operations of the well control system \n60\n as described herein may be implemented by running one or more functional modules in an information processing apparatus such as application specific chips, such as application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), programmable logic devices (PLDs), systems on a chip (SOCs), or other appropriate devices.', 'These modules, combinations of these modules, and/or their combination with hardware are all included within the scope of the embodiments described herein.', 'As described in greater detail herein, the BHA \n26\n illustrated in \nFIG.', '1\n may be configured to couple to various other downhole well tool components \n80\n that are disposed downhole within a wellbore \n14\n.', 'For example, in certain embodiments, a downhole well tool component \n80\n to which the BHA \n26\n may connect may include a downhole plug, such as an electrically expandable plug.', 'For example, \nFIG.', '3\n illustrates a conventional BHA \n26\n that includes an upper BHA \n26\nA and a lower BHA \n26\nB.', 'As illustrated, in certain embodiments, the upper BHA \n26\nA may include a motor head assembly (“MHA”) \n82\n having optical connectors configured to couple to optical lines \n84\n extend through coiled tubing \n20\n being used to convey the BHA \n26\n into a wellbore \n14\n and, in certain embodiments, a fiber optic cable \n86\n installed within the coiled tubing \n20\n to enable the BHA \n26\n to communicate with the surface processing system \n42\n, as described in greater detail herein.', 'In addition, in certain embodiments, the MHA \n82\n may be configured to transmit power to the downhole well tool component \n80\n via power lines \n88\n extending through the coiled tubing \n20\n, the fiber optic cable \n86\n, the MHA \n82\n and, in certain embodiments, an adapter \n90\n of the lower BHA \n26\nB that couples the upper BHA \n26\nA to the downhole', 'well tool component \n80\n.', 'In such conventional BHAs \n26\n, the adapter \n90\n may include a mono conductor connection \n92\n at a downhole axial end of the adapter \n90\n, which means that there is only a single radial alignment of the adapter \n90\n with respect to the downhole well tool component \n80\n that enables electrical and mechanical coupling of the adapter \n90\n to the downhole well tool component \n80\n.', 'In particular, in such embodiments, the coiled tubing \n20\n must twist to enable the adapter \n90\n to couple to the downhole well tool component \n80\n.', 'In certain situations, the amount of twist/rotation that the adapter \n90\n must undergo to engage the downhole well tool component \n80\n may be between 0° and about 70°.', 'If other types of cables (e.g., wireline cables) that do not resist rotation (or barely resist rotation) were used to convey (or otherwise couple to) the downhole well tool \n36\n, the cable may be relatively free to twist as far as it needs to in order to latch into and engage the downhole well tool component \n80\n.', 'As such, coupling of the adapter \n90\n to the downhole well tool component \n80\n may be relatively easily achieved when a wireline cable is used, but it may be relatively difficult to enable enough twisting when coiled tubing \n20\n is used, as illustrated in \nFIG.', '3\n, due at least in part to the relatively high level of torsional stiffness of the coiled tubing \n20\n.', 'In particular, one of the problems with the adapter \n90\n described with respect to \nFIG.', '3\n is that the adapter \n90\n is not configured to rotate relative to the other components of the BHA \n26\n.', 'In particular, the mono conductor connection \n92\n of the adapter \n90\n illustrated in \nFIG.', '3\n is not configured to rotate relative to the rest of the adapter \n90\n.', 'In contrast, as illustrated in \nFIG.', '4\n, the embodiments described herein provide an adapter \n94\n that includes a electromechanical joint \n96\n at a downhole axial end of the adapter \n94\n that facilitates easier coupling of the adapter \n94\n but facilitating rotation of the electromechanical joint \n96\n relative to the rest of the adapter \n94\n even when the BHA \n26\n is conveyed by coiled tubing \n20\n.', 'In particular, as described in greater detail herein, the electromechanical joint \n96\n includes a rotational swivel that enables the electromechanical joint \n96\n to easily rotate to enabling latching onto various downhole well tool components \n80\n.', 'The electromechanical joint \n96\n described herein enables not only mechanical connection of the adapter \n94\n to a downhole well tool component \n80\n, but also includes an electrical conductor that passes through the electromechanical joint \n96\n to enable the adapter \n94\n to couple both mechanically and electrically to the downhole well tool component \n80\n.', 'In addition, the electromechanical joint \n96\n described herein facilitates a connection between the adapter \n94\n and a downhole well tool component \n80\n that has only one electrical contact and one mechanical/hydraulic contact, which is relatively simple in design.', 'As such, the embodiments described herein provide a mono conductor electromechanical swivel that is specifically designed to swivel to facilitate coupling of the adapter \n94\n to a downhole well tool component \n80\n, as described in greater detail herein.', 'Therefore, the embodiments described herein provide both mechanical and electrical integrity of a mono conductor.\n \nFIG.', '5\n is a cross-sectional perspective view of an electromechanical joint \n96\n and a downhole well tool component \n80\n to depict how the electromechanical joint \n96\n enables the electromechanical joint \n96\n to couple both electrically and mechanically using only a mono conductor.', 'As illustrated in \nFIG.', '5\n, in certain embodiments, the electromechanical joint \n96\n may include a rotating ring \n100\n and a split ring \n102\n to hold axial force (e.g., both tension and compression), which enables the electromechanical joint \n96\n to have both mechanical integrity and electrical integrity while also being capable of easily coupling to a downhole well tool component \n80\n via rotation of the electromechanical joint \n96\n.', 'In addition, in certain embodiments, the electromechanical joint \n96\n may include a bearing system \n104\n to reduce the friction that the electromechanical joint \n96\n might otherwise experience when hydrostatic pressure acts to lock the electromechanical joint \n96\n closed within a wellbore \n14\n.', 'In addition, in certain embodiments, the electromechanical joint \n96\n may include a main body portion \n106\n that includes an upper body portion \n106\nA, a middle body portion \n106\nB around which the bearing system \n104\n, the rotating ring \n100\n, and the split ring \n102\n may be radially disposed, and a lower body portion \n106\nC. An exterior surface \n108\nA of the upper body portion \n106\nA of the electromechanical joint \n96\n will not contact the downhole well tool component \n80\n when the electromechanical joint \n96\n connects to the downhole well tool component \n80\n.', 'However, the rotating ring \n100\n and a split ring \n102\n of the electromechanical joint \n96\n will directly contact a first interior surface \n110\n of a main body portion \n112\n of the downhole well tool component \n80\n when the electromechanical joint \n96\n connects to the downhole well tool component \n80\n.', 'Similarly, an exterior surface \n108\nC of the lower body portion \n106\nC of the electromechanical joint \n96\n will at least partially directly contact a second interior surface \n114\n of the main body portion \n112\n of the downhole well tool component \n80\n when the electromechanical joint \n96\n connects to the downhole well tool component \n80\n.\n \nFIG.', '6\n is another cross-sectional perspective view of the electromechanical joint \n96\n and the downhole well tool component \n80\n of \nFIG.', '5\n with the electromechanical joint \n96\n further inserted within the downhole well tool component \n80\n.', 'At this point, exterior threading \n116\n on the rotating ring \n100\n will begin engaging with mating interior threading \n118\n on the first interior surface \n110\n of the main body portion \n112\n of the downhole well tool component \n80\n.', 'As will be appreciated, the rotating ring \n100\n (and portions of the bearing system \n104\n) are configured to rotate while the other components of the electromechanical joint \n96\n remain rotationally fixed.', 'FIG.', '7\n is another cross-sectional perspective view of the electromechanical joint \n96\n and the downhole well tool component \n80\n of \nFIGS.', '5\n and \n6\n with the exterior threading \n116\n on the rotating ring \n100\n almost fully engaged with the mating interior threading \n118\n on the first interior surface \n110\n of the main body portion \n112\n of the downhole well tool component \n80\n.', 'As also illustrated, at this point, a primary sealing element (e.g., o-ring) \n120\n disposed within an exterior groove \n122\n of the split ring \n102\n creates a primary seal with the first interior surface \n110\n of the main body portion \n112\n of the downhole well tool component \n80\n to protect the electrical components (e.g., a first mono conductor electrical line \n124\n disposed within an interior passage \n126\n of the middle body portion \n106\nB of the electromechanical joint \n96\n and a second mono conductor electrical line \n128\n disposed within an interior passage \n130\n of the main body portion \n112\n of the downhole well tool component \n80\n) and ensure that the electrical components remain dry and in electrical contact.', 'As also illustrated, in certain embodiments, a secondary sealing element (e.g., o-ring) \n132\n disposed within an exterior groove \n134\n of the main body portion \n112\n of the downhole well tool component \n80\n creates a secondary seal with the exterior surface \n108\nC of the lower body portion \n106\nC of the electromechanical joint \n96\n to further protect the electrical components.', 'It will be appreciated that, once the adapter \n94\n and the downhole well tool component \n80\n are connected to each other, the mono conductor electrical lines \n124\n, \n128\n may be extended from the electromechanical joint \n96\n and the downhole well tool component \n80\n, respectively, such that the mono conductor electrical lines \n124\n, \n128\n make contact to enable electrical coupling of the electromechanical joint \n96\n and the downhole well tool component \n80\n.', 'FIG.', '8\n is a partial cross-sectional view of the electromechanical joint \n96\n in the position illustrated in \nFIG.', '7\n (e.g., almost fully engaged with the downhole well tool component \n80\n), illustrating the solid, one-piece construction of the rotating ring \n100\n.', 'It will be appreciated that, once the electromechanical joint \n96\n is fully engaged with the downhole well tool component \n80\n (e.g., when the exterior threading \n116\n on the rotating ring \n100\n of the electromechanical joint \n96\n are fully threaded with respect to the interior threading \n118\n on the first interior surface \n110\n of the main body portion \n112\n of the downhole well tool component \n80\n), an upper axial end \n136\n of the main body portion \n112\n of the downhole well tool component \n80\n may abut a shoulder \n138\n of the rotating ring \n100\n.', 'FIG.', '9\n is a partial cross-sectional view of the electromechanical joint \n96\n with the rotating ring \n100\n removed to more fully illustrate the bearing system \n104\n.', 'As illustrated more clearly in \nFIG.', '10\n, in certain embodiments, the bearing system \n104\n may be a thrust bearing that includes a roller bearing \n140\n and one or more washers \n142\n that reduce friction in the electromechanical joint \n96\n and enhance the ability of the electromechanical joint \n96\n to rotate.', 'In particular, the bearing system \n104\n greatly reduces the friction that the electromechanical joint \n96\n would otherwise experience when hydrostatic pressure acts to lock the electromechanical joint \n96\n in a well.', 'In certain embodiments, a twist point of the bearing system \n104\n is on the roller bearing \n140\n and uphole load thrust washer \n142\n and a secondary twist point is the bronze bearing and the uphole load thrust washer \n142\n.', 'The electric connection of the electromechanical joint \n96\n should remain sealed from the wellbore fluids.', 'This creates a hydrostatic closing force on the electromechanical joint \n96\n, which will create relatively high friction on shoulders of the electromechanical joint \n96\n that are intended to rotate.', 'The shoulders would likely become “hydrostatically locked” unless the bearing system \n104\n is used to reduce the friction at the shoulders.\n \nFIG.', '11\n is a perspective view of the split ring \n102\n of the electromechanical joint \n96\n.', 'As illustrated in \nFIGS. \n5\n through \n7\n, in certain embodiments, the split ring \n102\n is disposed within an exterior groove \n144\n between the middle body portion \n106\nB and the lower body portion \n106\nC of the main body portion \n106\n of the electromechanical joint \n96\n.', 'In general, the split ring \n102\n holds the tension of the electromechanical joint \n96\n and, as such, is a key component of the mechanical functionality of the electromechanical joint \n96\n.', 'The rotating ring \n100\n rests against this split ring \n102\n, which is loaded in shear as the electromechanical joint \n96\n is loaded in tension.', 'As such, the embodiments described herein include an electromechanical joint \n96\n that has both a mechanical connection for tension and compression (i.e., the rotating ring \n100\n and the split ring \n102\n, as well as the bearing system \n104\n), and a sealed electrical connection \n124\n) that is free to rotate despite being surrounded by relatively high pressure fluid in a wellbore \n14\n.', 'In addition, the electromechanical joint \n96\n is not only free to rotate despite being surrounded by relatively high pressure fluid in the wellbore \n14\n, but also has a frictional reduction system (e.g., the bearing system \n104\n) built into it so that it can rotate freely despite the presence of relatively high friction.', 'For example, in certain embodiments, the electromechanical joint \n96\n may include a bearing system \n104\n in the joint load pathway when the electromechanical joint \n96\n is operating in compression but not in tension.', 'In addition, in certain embodiments, the electromechanical joint \n96\n reduces the frictional load on the shoulders of the electromechanical joint \n96\n by including a roller bearing \n140\n in the electromechanical joint \n96\n.', 'In addition, the electromechanical joint \n96\n requires no rotation of either the upper portion of the electromechanical joint \n96\n (e.g., the upper body portion \n106\nA) nor the lower portion of the electromechanical joint \n96\n (e.g., the lower body portion \n106\nA) because only the solid, one-piece rotating ring \n100\n (and portions of the bearing system \n104\n) are configured to rotate.', 'In addition, the electromechanical joint \n96\n transfers axial tension encountered into the split ring \n102\n, which is loaded in shear.', 'In addition, the electromechanical joint \n96\n can withstand the contact force from hydrostatic pressure acting on a sealed electrical chamber \n146\n of the electromechanical joint \n96\n by ensuring that force is transferred into a low friction bearing system \n104\n.', 'In particular, as described in greater detail herein, the embodiments described herein include an adapter \n94\n of a downhole well tool \n36\n that includes an electromechanical joint \n96\n configured to connect to a downhole well tool component \n80\n within a wellbore \n14\n of an oil and gas well system \n10\n, wherein the electromechanical joint \n96\n is configured to rotate to facilitate connection of the electromechanical joint \n96\n to the downhole well tool component \n80\n.', 'In certain embodiments, the electromechanical joint \n96\n includes a rotating ring \n100\n configured to experience axial tension forces and axial compression forces acting on the electromechanical joint \n96\n, and a sealed electrical connection \n124\n configured to couple with a mating electrical connection \n128\n of the downhole well tool component \n80\n.', 'In certain embodiments, the electromechanical joint \n96\n is configured to transfer the axial tension forces into a split ring \n102\n of the electromechanical joint \n96\n, which is loaded in shear.', 'In addition, in certain embodiments, the rotating ring \n100\n includes exterior threading \n116\n configured to engage mating interior threading \n118\n of the downhole well tool component \n80\n.', 'In addition, in certain embodiments, the rotating ring \n100\n is a solid, one-piece threaded ring.', 'In addition, in certain embodiments, the electromechanical joint \n96\n includes a frictional reduction system configured to reduce friction between the rotating ring \n100\n and a main body portion \n106\n of the electromechanical joint \n96\n.', 'In certain embodiments, the frictional reduction system includes a bearing system \n104\n disposed axially between the rotating ring \n100\n and the main body portion \n106\n of the electromechanical joint \n96\n.', 'In addition, in certain embodiments, the bearing system \n104\n includes a roller bearing \n140\n configured to reduce a frictional load on shoulders of the electromechanical joint \n96\n.', 'In addition, in certain embodiments, the rotating ring \n100\n and a portion of the bearing system \n104\n (e.g., rollers of the roller bearing \n140\n) are the only components of the electromechanical joint \n96\n configured to rotate (e.g., relative to the main body portion \n106\n of the electromechanical joint \n96\n).', 'In addition, in certain embodiments, the electromechanical joint \n96\n includes a plurality of sealing elements \n120\n, \n132\n configured to protect a sealed electrical chamber \n146\n of the electromechanical joint \n96\n from hydrostatic pressure external to the electromechanical joint \n96\n.', 'The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical.', 'Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ”', 'or “step for [perform]ing [a function] . . .', '”, it is intended that such elements are to be interpreted under 35 U.S.C. § 112(f).', 'However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. § 112(f).']

['1.', 'A downhole well tool adapter, comprising:\nan electromechanical joint configured to connect to a downhole well tool component within a wellbore of an oil and gas well system, wherein the electromechanical joint comprises:\na main body portion;\na rotating ring disposed radially around the main body portion and configured to rotate relative to the main body portion to facilitate transition to a single radial alignment of the electromechanical joint with the downhole well tool component, wherein the rotating ring is configured to directly contact an interior surface of the downhole well tool component when the electromechanical joint connects to the downhole well tool component;\na split ring disposed within a first exterior groove of the main body portion, wherein the split ring is configured to directly contact the interior surface of the downhole well tool component when the electromechanical joint connects to the downhole well tool component;\na frictional reduction system configured to reduce friction between the rotating ring and the main body portion, wherein the rotating ring and a portion of the frictional reduction system are the only components of the electromechanical joint configured to rotate relative to the main body portion;\na plurality of sealing elements comprising a primary sealing element disposed within an exterior groove of the split ring, and a secondary sealing element disposed within a second exterior groove of the main body portion; and\na sealed mono conductor electrical connection disposed within an interior passage extending axially through the main body portion, wherein the sealed mono conductor electrical connection is configured to couple with a mating mono conductor electrical connection of the downhole well tool component.', '2.', 'The downhole well tool adapter of claim 1, wherein the rotating ring is configured to experience axial tension forces and axial compression forces acting on the electromechanical joint.', '3.', 'The downhole well tool adapter of claim 2, wherein the electromechanical joint is configured to transfer the axial tension forces into the split ring of the electromechanical joint that is loaded in shear.', '4.', 'The downhole well tool adapter of claim 2, wherein the rotating ring comprises exterior threading configured to engage mating interior threading of the downhole well tool component.', '5.', 'The downhole well tool adapter of claim 2, wherein the rotating ring is a solid, one-piece threaded ring configured to abut only the main body portion, the split ring, and the frictional reduction system of the electromechanical joint.', '6.', 'The downhole well tool adapter of claim 1, wherein the frictional reduction system comprises a bearing system disposed axially between the rotating ring and the main body portion of the electromechanical joint.', '7.', 'The downhole well tool adapter of claim 6, wherein the bearing system comprises a roller bearing configured to reduce a frictional load on shoulders of the electromechanical joint.', '8.', 'The downhole well tool adapter of claim 3, wherein the plurality of sealing elements are configured to protect a sealed electrical chamber of the electromechanical joint from hydrostatic pressure external to the electromechanical joint.', '9.', 'An electromechanical joint, comprising:\na main body portion;\na rotating ring disposed radially around the main body portion and configured to rotate relative to the main body portion to facilitate connection of the electromechanical joint to a downhole well tool component within a wellbore of an oil and gas well system, wherein the rotating ring is configured to directly contact an interior surface of the downhole well tool component when the electromechanical joint connects to the downhole well tool component;\na split ring disposed within a first exterior groove of the main body portion, wherein the split ring is configured to directly contact the interior surface of the downhole well tool component when the electromechanical joint connects to the downhole well tool component;\na frictional reduction system configured to reduce friction between the rotating ring and the main body portion, wherein the rotating ring and a portion of the frictional reduction system are the only components of the electromechanical joint configured to rotate relative to the main body portion;\na plurality of sealing elements comprising a primary sealing element disposed within an exterior groove of the split ring, and a secondary sealing element disposed within a second exterior groove of the main body portion; and\na sealed mono conductor electrical connection disposed within an interior passage extending axially through the main body portion, wherein the sealed mono conductor electrical connection is configured to couple with a mating mono conductor electrical connection of the downhole well tool component; wherein rotation of the rotating ring relative to the main body portion facilitates transition to a single radial alignment of the electromechanical joint with the downhole well tool component.', '10.', 'The electromechanical joint of claim 9, wherein the rotating ring is configured to experience axial tension forces and axial compression forces acting on the electromechanical joint.', '11.', 'The electromechanical joint of claim 10, wherein the electromechanical joint is configured to transfer the axial tension forces into the split ring of the electromechanical joint that is loaded in shear.\n\n\n\n\n\n\n12.', 'The electromechanical joint of claim 9, wherein the rotating ring comprises exterior threading configured to engage mating interior threading of the downhole well tool component.', '13.', 'The electromechanical joint of claim 11, wherein the rotating ring is a solid, one-piece threaded ring configured to abut only the main body portion, the split ring, and the frictional reduction system of the electromechanical joint.\n\n\n\n\n\n\n14.', 'The electromechanical joint of claim 9, wherein the frictional reduction system comprises a bearing system disposed axially between the rotating ring and the main body portion.\n\n\n\n\n\n\n15.', 'The electromechanical joint of claim 14, wherein the bearing system comprises a roller bearing configured to reduce a frictional load on shoulders of the electromechanical joint.\n\n\n\n\n\n\n16.', 'The electromechanical joint of claim 11, wherein the plurality of sealing elements are configured to protect a sealed electrical chamber of the electromechanical joint from hydrostatic pressure external to the electromechanical joint.']

['FIG.', '1 is a schematic illustration of an oil and gas well system, in accordance with embodiments of the present disclosure;; FIG.', '2 illustrates a well control system that may include a surface processing system to control the oil and gas well system described herein, in accordance with embodiments of the present disclosure;; FIG.', '3 illustrates a conventional BHA that includes an upper BHA and a lower BHA;; FIG.', '4 illustrates a BHA having an adapter with a electromechanical joint, in accordance with embodiments of the present disclosure;; FIG.', '5 is a cross-sectional perspective view of an electromechanical joint and a downhole', 'well tool component to depict how the electromechanical joint enables the adapter to couple both electrically and mechanically using only a mono conductor, in accordance with embodiments of the present disclosure;; FIG.', '6 is another cross-sectional perspective view of the electromechanical joint and the downhole well tool component of FIG.', '5, in accordance with embodiments of the present disclosure;; FIG. 7 is another cross-sectional perspective view of the electromechanical joint and the downhole well tool component of FIGS.', '5 and 6, in accordance with embodiments of the present disclosure;; FIG.', '8 is a partial cross-sectional view of the electromechanical joint in the position illustrated in FIG.', '7, in accordance with embodiments of the present disclosure;; FIG. 9 is a partial cross-sectional view of the electromechanical joint, in accordance with embodiments of the present disclosure;; FIG.', '10 is a perspective view of a bearing system of the electromechanical joint, in accordance with embodiments of the present disclosure; and; FIG.', '11 is a perspective view of a split ring of the electromechanical joint, in accordance with embodiments of the present disclosure.', '; FIG.', '2 illustrates a well control system 60 that may include the surface processing system 42 to control the oil and gas well system 10 described herein.', 'In certain embodiments, the surface processing system 42 may include one or more analysis modules 62 (e.g., a program of computer-executable instructions and associated data) that may be configured to perform various functions of the embodiments described herein.', 'In certain embodiments, to perform these various functions, an analysis module 62 executes on one or more processors 64 of the surface processing system 42, which may be connected to one or more storage media 66 of the surface processing system 42.', 'Indeed, in certain embodiments, the one or more analysis modules 62 may be stored in the one or more storage media 66.; FIG.', '5 is a cross-sectional perspective view of an electromechanical joint 96 and a downhole well tool component 80 to depict how the electromechanical joint 96 enables the electromechanical joint 96 to couple both electrically and mechanically using only a mono conductor.', 'As illustrated in FIG.', '5, in certain embodiments, the electromechanical joint 96 may include a rotating ring 100 and a split ring 102 to hold axial force (e.g., both tension and compression), which enables the electromechanical joint 96 to have both mechanical integrity and electrical integrity while also being capable of easily coupling to a downhole well tool component 80 via rotation of the electromechanical joint 96.', 'In addition, in certain embodiments, the electromechanical joint 96 may include a bearing system 104 to reduce the friction that the electromechanical joint 96 might otherwise experience when hydrostatic pressure acts to lock the electromechanical joint 96 closed within a wellbore 14.; FIG.', '6 is another cross-sectional perspective view of the electromechanical joint 96 and the downhole well tool component 80 of FIG.', '5 with the electromechanical joint 96 further inserted within the downhole well tool component 80.', 'At this point, exterior threading 116 on the rotating ring 100 will begin engaging with mating interior threading 118 on the first interior surface 110 of the main body portion 112 of the downhole well tool component 80.', 'As will be appreciated, the rotating ring 100 (and portions of the bearing system 104) are configured to rotate while the other components of the electromechanical joint 96 remain rotationally fixed.; FIG. 7 is another cross-sectional perspective view of the electromechanical joint 96 and the downhole well tool component 80 of FIGS.', '5 and 6 with the exterior threading 116 on the rotating ring 100 almost fully engaged with the mating interior threading 118 on the first interior surface 110 of the main body portion 112 of the downhole well tool component 80.', 'As also illustrated, at this point, a primary sealing element (e.g., o-ring) 120 disposed within an exterior groove 122 of the split ring 102 creates a primary seal with the first interior surface 110 of the main body portion 112 of the downhole well tool component 80 to protect the electrical components (e.g., a first mono conductor electrical line 124 disposed within an interior passage 126 of the middle body portion 106B of the electromechanical joint 96 and a second mono conductor electrical line 128 disposed within an interior passage 130 of the main body portion 112 of the downhole well tool component 80) and ensure that the electrical components remain dry and in electrical contact.', 'As also illustrated, in certain embodiments, a secondary sealing element (e.g., o-ring) 132 disposed within an exterior groove 134 of the main body portion 112 of the downhole well tool component 80 creates a secondary seal with the exterior surface 108C of the lower body portion 106C of the electromechanical joint 96 to further protect the electrical components.', 'It will be appreciated that, once the adapter 94 and the downhole well tool component 80 are connected to each other, the mono conductor electrical lines 124, 128 may be extended from the electromechanical joint 96 and the downhole well tool component 80, respectively, such that the mono conductor electrical lines 124, 128 make contact to enable electrical coupling of the electromechanical joint 96 and the downhole well tool component 80.; FIG.', '8 is a partial cross-sectional view of the electromechanical joint 96 in the position illustrated in FIG.', '7', '(e.g., almost fully engaged with the downhole well tool component 80), illustrating the solid, one-piece construction of the rotating ring 100.', 'It will be appreciated that, once the electromechanical joint 96 is fully engaged with the downhole well tool component 80 (e.g., when the exterior threading 116 on the rotating ring 100 of the electromechanical joint 96 are fully threaded with respect to the interior threading 118 on the first interior surface 110 of the main body portion 112 of the downhole well tool component 80), an upper axial end 136 of the main body portion 112 of the downhole well tool component 80 may abut a shoulder 138 of the rotating ring 100.; FIG.', '9 is a partial cross-sectional view of the electromechanical joint 96 with the rotating ring 100 removed to more fully illustrate the bearing system 104.', 'As illustrated more clearly in FIG.', '10, in certain embodiments, the bearing system 104 may be a thrust bearing that includes a roller bearing 140 and one or more washers 142 that reduce friction in the electromechanical joint 96 and enhance the ability of the electromechanical joint 96 to rotate.', 'In particular, the bearing system 104 greatly reduces the friction that the electromechanical joint 96 would otherwise experience when hydrostatic pressure acts to lock the electromechanical joint 96 in a well.', 'In certain embodiments, a twist point of the bearing system 104 is on the roller bearing 140 and uphole load thrust washer 142 and a secondary twist point is the bronze bearing and the uphole load thrust washer 142.', 'The electric connection of the electromechanical joint 96 should remain sealed from the wellbore fluids.', 'This creates a hydrostatic closing force on the electromechanical joint 96, which will create relatively high friction on shoulders of the electromechanical joint 96 that are intended to rotate.', 'The shoulders would likely become “hydrostatically locked” unless the bearing system 104 is used to reduce the friction at the shoulders.; FIG.', '11 is a perspective view of the split ring 102 of the electromechanical joint 96.', 'As illustrated in FIGS.', '5 through 7, in certain embodiments, the split ring 102 is disposed within an exterior groove 144 between the middle body portion 106B and the lower body portion 106C of the main body portion 106 of the electromechanical joint 96.', 'In general, the split ring 102 holds the tension of the electromechanical joint 96 and, as such, is a key component of the mechanical functionality of the electromechanical joint 96.', 'The rotating ring 100 rests against this split ring 102, which is loaded in shear as the electromechanical joint 96 is loaded in tension.']

US11828155

Drilling control

Jan 29, 2020

Yingwei Yu, Velizar Vesselinov, Richard Meehan, Qiuhua Liu, Wei Chen, Minh Trang Chau, Yuelin Shen, Sylvain Chambon

Schlumberger Technology Corporation

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['A method can include receiving sensor data during drilling of a portion of a borehole in a geologic environment; determining a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issuing a control instruction for drilling an additional portion of the borehole using the determined drilling mode.']

['Description\n\n\n\n\n\n\nRELATED APPLICATION', 'This application claims priority to and the benefit of a U.S. Provisional Application having Ser.', 'No. 62/850,865, filed 21 May 2019, which is incorporated by reference herein.', 'BACKGROUND\n \nA resource field can be an accumulation, pool or group of pools of one or more resources (e.g., oil, gas, oil and gas) in a subsurface environment.', 'A resource field can include at least one reservoir.', 'A reservoir may be shaped in a manner that can trap hydrocarbons and may be covered by an impermeable or sealing rock.', 'A bore can be drilled into an environment where the bore (e.g., a borehole) may be utilized to form a well that can be utilized in producing hydrocarbons from a reservoir.', 'A rig can be a system of components that can be operated to form a bore in an environment, to transport equipment into and out of a bore in an environment, etc.', 'As an example, a rig can include a system that can be used to drill a bore and to acquire information about an environment, about drilling, etc.', 'A resource field may be an onshore field, an offshore field or an on- and offshore field.', 'A rig can include components for performing operations onshore and/or offshore.', 'A rig may be, for example, vessel-based, offshore platform-based, onshore, etc.', 'Field planning and/or development can occur over one or more phases, which can include an exploration phase that aims to identify and assess an environment (e.g., a prospect, a play, etc.), which may include drilling of one or more bores (e.g., one or more exploratory wells, etc.).', 'SUMMARY\n \nA method can include receiving sensor data during drilling of a portion of a borehole in a geologic environment; determining a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issuing a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', 'A system can include a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: receive sensor data during drilling of a portion of a borehole in a geologic environment; determine a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issue a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', 'One or more computer-readable storage media can include computer-executable instructions executable to instruct a computing system to: receive sensor data during drilling of a portion of a borehole in a geologic environment; determine a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issue a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', 'Various other apparatuses, systems, methods, etc., are also disclosed.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFeatures and advantages of the described implementations can be more readily understood by reference to the following description taken in conjunction with the accompanying drawings.\n \nFIG.', '1\n illustrates examples of equipment in a geologic environment;\n \nFIG.', '2\n illustrates examples of equipment and examples of hole types;\n \nFIG.', '3\n illustrates an example of a system;\n \nFIG.', '4\n illustrates an example of a wellsite system and an example of a computing system;\n \nFIG.', '5\n illustrates an example of equipment in a geologic environment;\n \nFIG.', '6\n illustrates an example of a graphical user interface;\n \nFIG.', '7\n illustrates an example of a method;\n \nFIG.', '8\n illustrates examples of directional drilling equipment;\n \nFIG.', '9\n illustrates an example of a graphical user interface;\n \nFIG.', '10\n illustrates an example of a graphical user interface;\n \nFIG.', '11\n illustrates an example of a graphical user interface;\n \nFIG.', '12\n illustrates an example of a method;\n \nFIG.', '13\n illustrates an example of a system;\n \nFIG.', '14\n illustrates an example of a method;\n \nFIG.', '15\n illustrates examples of approaches to link simulation and reality;\n \nFIG.', '16\n illustrates an example of a method;\n \nFIG.', '17\n illustrates an example of a system;\n \nFIG.', '18\n illustrates an example of a system;\n \nFIG.', '19\n illustrates an example of a system;\n \nFIG.', '20\n illustrates examples of graphical user interfaces;\n \nFIG.', '21\n illustrates examples of graphical user interfaces;\n \nFIG.', '22\n illustrates an example of a system;\n \nFIG.', '23\n illustrates an example of a method;\n \nFIG.', '24\n illustrates examples of coordinate systems;\n \nFIG.', '25\n illustrates examples of representations of a drillstring toolface with respect to coordinate systems;\n \nFIG.', '26\n illustrates an example of a training framework;\n \nFIG.', '27\n illustrates an example of a system;\n \nFIG.', '28\n illustrates an example of a sequence engine;\n \nFIG.', '29\n illustrates an example of a method and an example of a system;\n \nFIG.', '30\n illustrates an example of a method and an example of a system;\n \nFIG.', '31\n illustrates an example of a system;\n \nFIG.', '32\n illustrates an example of a computing system; and\n \nFIG.', '33\n illustrates example components of a system and a networked system.', 'DETAILED DESCRIPTION', 'The following description includes the best mode presently contemplated for practicing the described implementations.', 'This description is not to be taken in a limiting sense, but rather is made merely for the purpose of describing the general principles of the implementations.', 'The scope of the described implementations should be ascertained with reference to the issued claims.\n \nFIG.', '1\n shows an example of a geologic environment \n120\n.', 'In \nFIG.', '1\n, the geologic environment \n120\n may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir \n121\n and that may be, for example, intersected by a fault \n123\n (e.g., or faults).', 'As an example, the geologic environment \n120\n may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment \n122\n may include communication circuitry to receive and to transmit information with respect to one or more networks \n125\n.', 'Such information may include information associated with downhole equipment \n124\n, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment \n126\n may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more pieces of equipment may provide for measurement, collection, communication, storage, analysis, etc. of data (e.g., for one or more produced resources, etc.).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, \nFIG.', '1\n shows a satellite in communication with the network \n125\n that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', 'FIG.', '1\n also shows the geologic environment \n120\n as optionally including equipment \n127\n and \n128\n associated with a well that includes a substantially horizontal portion (e.g., a lateral portion) that may intersect with one or more fractures \n129\n.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment \n127\n and/or \n128\n may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, injection, production, etc.', 'As an example, the equipment \n127\n and/or \n128\n may provide for measurement, collection, communication, storage, analysis, etc. of data such as, for example, production data (e.g., for one or more produced resources).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.\n \nFIG.', '1\n also shows an example of equipment \n170\n and an example of equipment \n180\n.', 'Such equipment, which may be systems of components, may be suitable for use in the geologic environment \n120\n.', 'While the equipment \n170\n and \n180\n are illustrated as land-based, various components may be suitable for use in an offshore system (e.g., an offshore rig, etc.).', 'The equipment \n170\n includes a platform \n171\n, a derrick \n172\n, a crown block \n173\n, a line \n174\n, a traveling block assembly \n175\n, drawworks \n176\n and a landing \n177\n (e.g., a monkeyboard).', 'As an example, the line \n174\n may be controlled at least in part via the drawworks \n176\n such that the traveling block assembly \n175\n travels in a vertical direction with respect to the platform \n171\n.', 'For example, by drawing the line \n174\n in, the drawworks \n176\n may cause the line \n174\n to run through the crown block \n173\n and lift the traveling block assembly \n175\n skyward away from the platform \n171\n; whereas, by allowing the line \n174\n out, the drawworks \n176\n may cause the line \n174\n to run through the crown block \n173\n and lower the traveling block assembly \n175\n toward the platform \n171\n.', 'Where the traveling block assembly \n175\n carries pipe (e.g., casing, etc.)', ', tracking of movement of the traveling block \n175\n may provide an indication as to how much pipe has been deployed.', 'A derrick can be a structure used to support a crown block and a traveling block operatively coupled to the crown block at least in part via line.', 'A derrick may be pyramidal in shape and offer a suitable strength-to-weight ratio.', 'A derrick may be movable as a unit or in a piece by piece manner (e.g., to be assembled and disassembled).', 'As an example, drawworks may include a spool, brakes, a power source and assorted auxiliary devices.', 'Drawworks may controllably reel out and reel in line.', 'Line may be reeled over a crown block and coupled to a traveling block to gain mechanical advantage in a “block and tackle” or “pulley” fashion.', 'Reeling out and in of line can cause a traveling block (e.g., and whatever may be hanging underneath it), to be lowered into or raised out of a bore.', 'Reeling out of line may be powered by gravity and reeling in by a motor, an engine, etc.', '(e.g., an electric motor, a diesel engine, etc.).', 'As an example, a crown block can include a set of pulleys (e.g., sheaves) that can be located at or near a top of a derrick or a mast, over which line is threaded.', 'A traveling block can include a set of sheaves that can be moved up and down in a derrick or a mast via line threaded in the set of sheaves of the traveling block and in the set of sheaves of a crown block.', 'A crown block, a traveling block and a line can form a pulley system of a derrick or a mast, which may enable handling of heavy loads (e.g., drillstring, pipe, casing, liners, etc.) to be lifted out of or lowered into a bore.', 'As an example, line may be about a centimeter to about five centimeters in diameter as, for example, steel cable.', 'Through use of a set of sheaves, such line may carry loads heavier than the line could support as a single strand.', 'As an example, a derrickman may be a rig crew member that works on a platform attached to a derrick or a mast.', 'A derrick can include a landing on which a derrickman may stand.', 'As an example, such a landing may be about 10 meters or more above a rig floor.', 'In an operation referred to as trip out of the hole (TOH), a derrickman may wear a safety harness that enables leaning out from the work landing (e.g., monkeyboard) to reach pipe located at or near the center of a derrick or a mast and to throw a line around the pipe and pull it back into its storage location (e.g., fingerboards), for example, until it may be desirable to run the pipe back into the bore.', 'As an example, a rig may include automated pipe-handling equipment such that the derrickman controls the machinery rather than physically handling the pipe.', 'As an example, a trip may refer to the act of pulling equipment from a bore and/or placing equipment in a bore.', 'As an example, equipment may include a drillstring that can be pulled out of a hole and/or placed or replaced in a hole.', 'As an example, a pipe trip may be performed where a drill bit has dulled or has otherwise ceased to drill efficiently and is to be replaced.', 'As an example, a trip that pulls equipment out of a borehole may be referred to as pulling out of hole (POOH) and a trip that runs equipment into a borehole may be referred to as running in hole (RIH).', 'FIG.', '2\n shows an example of a wellsite system \n200\n (e.g., at a wellsite that may be onshore or offshore).', 'As shown, the wellsite system \n200\n can include a mud tank \n201\n for holding mud and other material (e.g., where mud can be a drilling fluid), a suction line \n203\n that serves as an inlet to a mud pump \n204\n for pumping mud from the mud tank \n201\n such that mud flows to a vibrating hose \n206\n, a drawworks \n207\n for winching drill line or drill lines \n212\n, a standpipe \n208\n that receives mud from the vibrating hose \n206\n, a kelly hose \n209\n that receives mud from the standpipe \n208\n, a gooseneck or goosenecks \n210\n, a traveling block \n211\n, a crown block \n213\n for carrying the traveling block \n211\n via the drill line or drill lines \n212\n (see, e.g., the crown block \n173\n of \nFIG. \n1\n), a derrick \n214\n (see, e.g., the derrick \n172\n of \nFIG. \n1\n), a kelly \n218\n or a top drive \n240\n, a kelly drive bushing \n219\n, a rotary table \n220\n, a drill floor \n221\n, a bell nipple \n222\n, one or more blowout preventors (BOPs) \n223\n, a drillstring \n225\n, a drill bit \n226\n, a casing head \n227\n and a flow pipe \n228\n that carries mud and other material to, for example, the mud tank \n201\n.', 'In the example system of \nFIG.', '2\n, a borehole \n232\n is formed in subsurface formations \n230\n by rotary drilling; noting that various example embodiments may also use one or more directional drilling techniques, equipment, etc.', 'As shown in the example of \nFIG.', '2\n, the drillstring \n225\n is suspended within the borehole \n232\n and has a drillstring assembly \n250\n that includes the drill bit \n226\n at its lower end.', 'As an example, the drillstring assembly \n250\n may be a bottom hole assembly (BHA).', 'The wellsite system \n200\n can provide for operation of the drillstring \n225\n and other operations.', 'As shown, the wellsite system \n200\n includes the traveling block \n211\n and the derrick \n214\n positioned over the borehole \n232\n.', 'As mentioned, the wellsite system \n200\n can include the rotary table \n220\n where the drillstring \n225\n pass through an opening in the rotary table \n220\n.', 'As shown in the example of \nFIG.', '2\n, the wellsite system \n200\n can include the kelly \n218\n and associated components, etc., or a top drive \n240\n and associated components.', 'As to a kelly example, the kelly \n218\n may be a square or hexagonal metal/alloy bar with a hole drilled therein that serves as a mud flow path.', 'The kelly \n218\n can be used to transmit rotary motion from the rotary table \n220\n via the kelly drive bushing \n219\n to the drillstring \n225\n, while allowing the drillstring \n225\n to be lowered or raised during rotation.', 'The kelly \n218\n can pass through the kelly drive bushing \n219\n, which can be driven by the rotary table \n220\n.', 'As an example, the rotary table \n220\n can include a master bushing that operatively couples to the kelly drive bushing \n219\n such that rotation of the rotary table \n220\n can turn the kelly drive bushing \n219\n and hence the kelly \n218\n.', 'The kelly drive bushing \n219\n can include an inside profile matching an outside profile (e.g., square, hexagonal, etc.) of the kelly \n218\n; however, with slightly larger dimensions so that the kelly \n218\n can freely move up and down inside the kelly drive bushing \n219\n.', 'As to a top drive example, the top drive \n240\n can provide functions performed by a kelly and a rotary table.', 'The top drive \n240\n can turn the drillstring \n225\n.', 'As an example, the top drive \n240\n can include one or more motors (e.g., electric and/or hydraulic) connected with appropriate gearing to a short section of pipe called a quill, that in turn may be screwed into a saver sub or the drillstring \n225\n itself.', 'The top drive \n240\n can be suspended from the traveling block \n211\n, so the rotary mechanism is free to travel up and down the derrick \n214\n.', 'As an example, a top drive \n240\n may allow for drilling to be performed with more joint stands than a kelly/rotary table approach.', 'In the example of \nFIG.', '2\n, the mud tank \n201\n can hold mud, which can be one or more types of drilling fluids.', 'As an example, a wellbore may be drilled to produce fluid, inject fluid or both (e.g., hydrocarbons, minerals, water, etc.).', 'In the example of \nFIG.', '2\n, the drillstring \n225\n (e.g., including one or more downhole tools) may be composed of a series of pipes threadably connected together to form a long tube with the drill bit \n226\n at the lower end thereof.', 'As the drillstring \n225\n is advanced into a wellbore for drilling, at some point in time prior to or coincident with drilling, the mud may be pumped by the pump \n204\n from the mud tank \n201\n (e.g., or other source) via a the lines \n206\n, \n208\n and \n209\n to a port of the kelly \n218\n or, for example, to a port of the top drive \n240\n.', 'The mud can then flow via a passage (e.g., or passages) in the drillstring \n225\n and out of ports located on the drill bit \n226\n (see, e.g., a directional arrow).', 'As the mud exits the drillstring \n225\n via ports in the drill bit \n226\n, it can then circulate upwardly through an annular region between an outer surface(s) of the drillstring \n225\n and surrounding wall(s) (e.g., open borehole, casing, etc.), as indicated by directional arrows.', 'In such a manner, the mud lubricates the drill bit \n226\n and carries heat energy (e.g., frictional or other energy) and formation cuttings to the surface where the mud (e.g., and cuttings) may be returned to the mud tank \n201\n, for example, for recirculation (e.g., with processing to remove cuttings, etc.).', 'The mud pumped by the pump \n204\n into the drillstring \n225\n may, after exiting the drillstring \n225\n, form a mudcake that lines the wellbore which, among other functions, may reduce friction between the drillstring \n225\n and surrounding wall(s) (e.g., borehole, casing, etc.).', 'A reduction in friction may facilitate advancing or retracting the drillstring \n225\n.', 'During a drilling operation, the entire drillstring \n225\n may be pulled from a wellbore and optionally replaced, for example, with a new or sharpened drill bit, a smaller diameter drillstring, etc.', 'As mentioned, the act of pulling a drillstring out of a hole or replacing it in a hole is referred to as tripping.', 'A trip may be referred to as an upward trip or an outward trip or as a downward trip or an inward trip depending on trip direction.', 'As an example, consider a downward trip where upon arrival of the drill bit \n226\n of the drillstring \n225\n at a bottom of a wellbore, pumping of the mud commences to lubricate the drill bit \n226\n for purposes of drilling to enlarge the wellbore.', 'As mentioned, the mud can be pumped by the pump \n204\n into a passage of the drillstring \n225\n and, upon filling of the passage, the mud may be used as a transmission medium to transmit energy, for example, energy that may encode information as in mud-pulse telemetry.', 'As an example, mud-pulse telemetry equipment may include a downhole device configured to effect changes in pressure in the mud to create an acoustic wave or waves upon which information may modulated.', 'In such an example, information from downhole equipment (e.g., one or more modules of the drillstring \n225\n) may be transmitted uphole to an uphole device, which may relay such information to other equipment for processing, control, etc.', 'As an example, telemetry equipment may operate via transmission of energy via the drillstring \n225\n itself.', 'For example, consider a signal generator that imparts coded energy signals to the drillstring \n225\n and repeaters that may receive such energy and repeat it to further transmit the coded energy signals (e.g., information, etc.).', 'As an example, the drillstring \n225\n may be fitted with telemetry equipment \n252\n that includes a rotatable drive shaft, a turbine impeller mechanically coupled to the drive shaft such that the mud can cause the turbine impeller to rotate, a modulator rotor mechanically coupled to the drive shaft such that rotation of the turbine impeller causes said modulator rotor to rotate, a modulator stator mounted adjacent to or proximate to the modulator rotor such that rotation of the modulator rotor relative to the modulator stator creates pressure pulses in the mud, and a controllable brake for selectively braking rotation of the modulator rotor to modulate pressure pulses.', 'In such example, an alternator may be coupled to the aforementioned drive shaft where the alternator includes at least one stator winding electrically coupled to a control circuit to selectively short the at least one stator winding to electromagnetically brake the alternator and thereby selectively brake rotation of the modulator rotor to modulate the pressure pulses in the mud.', 'In the example of \nFIG.', '2\n, an uphole control and/or data acquisition system \n262\n may include circuitry to sense pressure pulses generated by telemetry equipment \n252\n and, for example, communicate sensed pressure pulses or information derived therefrom for process, control, etc.', 'The assembly \n250\n of the illustrated example includes a logging-while-drilling (LWD) module \n254\n, a measurement-while-drilling (MWD) module \n256\n, an optional module \n258\n, a rotary-steerable system (RSS) and/or motor \n260\n, and the drill bit \n226\n.', 'Such components or modules may be referred to as tools where a drillstring can include a plurality of tools.', 'As to a RSS, it involves technology utilized for directional drilling.', 'Directional drilling involves drilling into the Earth to form a deviated bore such that the trajectory of the bore is not vertical; rather, the trajectory deviates from vertical along one or more portions of the bore.', 'As an example, consider a target that is located at a lateral distance from a surface location where a rig may be stationed.', 'In such an example, drilling can commence with a vertical portion and then deviate from vertical such that the bore is aimed at the target and, eventually, reaches the target.', 'Directional drilling may be implemented where a target may be inaccessible from a vertical location at the surface of the Earth, where material exists in the Earth that may impede drilling or otherwise be detrimental (e.g., consider a salt dome, etc.), where a formation is laterally extensive (e.g., consider a relatively thin yet laterally extensive reservoir), where multiple bores are to be drilled from a single surface bore, where a relief well is desired, etc.', 'One approach to directional drilling involves a mud motor; however, a mud motor can present some challenges depending on factors such as rate of penetration (ROP), transferring weight to a bit (e.g., weight on bit, WOB) due to friction, etc.', 'A mud motor can be a positive displacement motor (PDM) that operates to drive a bit (e.g., during directional drilling, etc.).', 'A PDM operates as drilling fluid is pumped through it where the PDM converts hydraulic power of the drilling fluid into mechanical power to cause the bit to rotate.', 'As an example, a PDM may operate in a combined rotating mode where surface equipment is utilized to rotate a bit of a drillstring (e.g., a rotary table, a top drive, etc.)', 'by rotating the entire drillstring and where drilling fluid is utilized to rotate the bit of the drillstring.', 'In such an example, a surface RPM (SRPM) may be determined by use of the surface equipment and a downhole RPM of the mud motor may be determined using various factors related to flow of drilling fluid, mud motor type, etc.', 'As an example, in the combined rotating mode, bit RPM can be determined or estimated as a sum of the SRPM and the mud motor RPM, assuming the SRPM and the mud motor RPM are in the same direction.', 'As an example, a PDM mud motor can operate in a so-called sliding mode, when the drillstring is not rotated from the surface.', 'In such an example, a bit RPM can be determined or estimated based on the RPM of the mud motor.', 'A RSS can drill directionally where there is continuous rotation from surface equipment, which can alleviate the sliding of a steerable motor (e.g., a PDM).', 'A RSS may be deployed when drilling directionally (e.g., deviated, horizontal, or extended-reach wells).', 'A RSS can aim to minimize interaction with a borehole wall, which can help to preserve borehole quality.', 'A RSS can aim to exert a relatively consistent side force akin to stabilizers that rotate with the drillstring or orient the bit in the desired direction while continuously rotating at the same number of rotations per minute as the drillstring.', 'The LWD module \n254\n may be housed in a suitable type of drill collar and can contain one or a plurality of selected types of logging tools.', 'It will also be understood that more than one LWD and/or MWD module can be employed, for example, as represented at by the module \n256\n of the drillstring assembly \n250\n.', 'Where the position of an LWD module is mentioned, as an example, it may refer to a module at the position of the LWD module \n254\n, the module \n256\n, etc.', 'An LWD module can include capabilities for measuring, processing, and storing information, as well as for communicating with the surface equipment.', 'In the illustrated example, the LWD module \n254\n may include a seismic measuring device.', 'The MWD module \n256\n may be housed in a suitable type of drill collar and can contain one or more devices for measuring characteristics of the drillstring \n225\n and the drill bit \n226\n.', 'As an example, the MWD tool \n254\n may include equipment for generating electrical power, for example, to power various components of the drillstring \n225\n.', 'As an example, the MWD tool \n254\n may include the telemetry equipment \n252\n, for example, where the turbine impeller can generate power by flow of the mud; it being understood that other power and/or battery systems may be employed for purposes of powering various components.', 'As an example, the MWD module \n256\n may include one or more of the following types of measuring devices: a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device.\n \nFIG.', '2\n also shows some examples of types of holes that may be drilled.', 'For example, consider a slant hole \n272\n, an S-shaped hole \n274\n, a deep inclined hole \n276\n and a horizontal hole \n278\n.', 'As an example, a drilling operation can include directional drilling where, for example, at least a portion of a well includes a curved axis.', 'For example, consider a radius that defines curvature where an inclination with regard to the vertical may vary until reaching an angle between about 30 degrees and about 60 degrees or, for example, an angle to about 90 degrees or possibly greater than about 90 degrees.', 'As an example, a directional well can include several shapes where each of the shapes may aim to meet particular operational demands.', 'As an example, a drilling process may be performed on the basis of information as and when it is relayed to a drilling engineer.', 'As an example, inclination and/or direction may be modified based on information received during a drilling process.', 'As an example, deviation of a bore may be accomplished in part by use of a downhole motor and/or a turbine.', 'As to a motor, for example, a drillstring can include a positive displacement motor (PDM).', 'As an example, a system may be a steerable system and include equipment to perform method such as geosteering.', 'As mentioned, a steerable system can be or include an RSS.', 'As an example, a steerable system can include a PDM or of a turbine on a lower part of a drillstring which, just above a drill bit, a bent sub can be mounted.', 'As an example, above a PDM, MWD equipment that provides real time or near real time data of interest (e.g., inclination, direction, pressure, temperature, real weight on the drill bit, torque stress, etc.) and/or LWD equipment may be installed.', 'As to the latter, LWD equipment can make it possible to send to the surface various types of data of interest, including for example, geological data (e.g., gamma ray log, resistivity, density and sonic logs, etc.).', 'The coupling of sensors providing information on the course of a well trajectory, in real time or near real time, with, for example, one or more logs characterizing the formations from a geological viewpoint, can allow for implementing a geosteering method.', 'Such a method can include navigating a subsurface environment, for example, to follow a desired route to reach a desired target or targets.', 'As an example, a drillstring can include an azimuthal density neutron (ADN) tool for measuring density and porosity; a MWD tool for measuring inclination, azimuth and shocks; a compensated dual resistivity (CDR) tool for measuring resistivity and gamma ray related phenomena; one or more variable gauge stabilizers; one or more bend joints; and a geosteering tool, which may include a motor and optionally equipment for measuring and/or responding to one or more of inclination, resistivity and gamma ray related phenomena.', 'As an example, geosteering can include intentional directional control of a wellbore based on results of downhole geological logging measurements in a manner that aims to keep a directional wellbore within a desired region, zone (e.g., a pay zone), etc.', 'As an example, geosteering may include directing a wellbore to keep the wellbore in a particular section of a reservoir, for example, to minimize gas and/or water breakthrough and, for example, to maximize economic production from a well that includes the wellbore.\n \nReferring again to \nFIG.', '2\n, the wellsite system \n200\n can include one or more sensors \n264\n that are operatively coupled to the control and/or data acquisition system \n262\n.', 'As an example, a sensor or sensors may be at surface locations.', 'As an example, a sensor or sensors may be at downhole locations.', 'As an example, a sensor or sensors may be at one or more remote locations that are not within a distance of the order of about one hundred meters from the wellsite system \n200\n.', 'As an example, a sensor or sensor may be at an offset wellsite where the wellsite system \n200\n and the offset wellsite are in a common field (e.g., oil and/or gas field).', 'As an example, one or more of the sensors \n264\n can be provided for tracking pipe, tracking movement of at least a portion of a drillstring, etc.\n \nAs an example, the system \n200\n can include one or more sensors \n266\n that can sense and/or transmit signals to a fluid conduit such as a drilling fluid conduit (e.g., a drilling mud conduit).', 'For example, in the system \n200\n, the one or more sensors \n266\n can be operatively coupled to portions of the standpipe \n208\n through which mud flows.', 'As an example, a downhole tool can generate pulses that can travel through the mud and be sensed by one or more of the one or more sensors \n266\n.', 'In such an example, the downhole tool can include associated circuitry such as, for example, encoding circuitry that can encode signals, for example, to reduce demands as to transmission.', 'As an example, circuitry at the surface may include decoding circuitry to decode encoded information transmitted at least in part via mud-pulse telemetry.', 'As an example, circuitry at the surface may include encoder circuitry and/or decoder circuitry and circuitry downhole may include encoder circuitry and/or decoder circuitry.', 'As an example, the system \n200\n can include a transmitter that can generate signals that can be transmitted downhole via mud (e.g., drilling fluid) as a transmission medium.', 'As an example, one or more portions of a drillstring may become stuck.', 'The term stuck can refer to one or more of varying degrees of inability to move or remove a drillstring from a bore.', 'As an example, in a stuck condition, it might be possible to rotate pipe or lower it back into a bore or, for example, in a stuck condition, there may be an inability to move the drillstring axially in the bore, though some amount of rotation may be possible.', 'As an example, in a stuck condition, there may be an inability to move at least a portion of the drillstring axially and rotationally.', 'As to the term “stuck pipe”, this can refer to a portion of a drillstring that cannot be rotated or moved axially.', 'As an example, a condition referred to as “differential sticking” can be a condition whereby the drillstring cannot be moved (e.g., rotated or reciprocated) along the axis of the bore.', 'Differential sticking may occur when high-contact forces caused by low reservoir pressures, high wellbore pressures, or both, are exerted over a sufficiently large area of the drillstring.', 'Differential sticking can have time and financial cost.', 'As an example, a sticking force can be a product of the differential pressure between the wellbore and the reservoir and the area that the differential pressure is acting upon.', 'This means that a relatively low differential pressure (delta p) applied over a large working area can be just as effective in sticking pipe as can a high differential pressure applied over a small area.', 'As an example, a condition referred to as “mechanical sticking” can be a condition where limiting or prevention of motion of the drillstring by a mechanism other than differential pressure sticking occurs.', 'Mechanical sticking can be caused, for example, by one or more of junk in the hole, wellbore geometry anomalies, cement, keyseats or a buildup of cuttings in the annulus.\n \nFIG.', '3\n shows an example of a system \n300\n that includes various equipment for evaluation \n310\n, planning \n320\n, engineering \n330\n and operations \n340\n.', 'For example, a drilling workflow framework \n301\n, a seismic-to-simulation framework \n302\n, a technical data framework \n303\n and a drilling framework \n304\n may be implemented to perform one or more processes such as a evaluating a formation \n314\n, evaluating a process \n318\n, generating a trajectory \n324\n, validating a trajectory \n328\n, formulating constraints \n334\n, designing equipment and/or processes based at least in part on constraints \n338\n, performing drilling \n344\n and evaluating drilling and/or formation \n348\n.', 'In the example of \nFIG.', '3\n, the seismic-to-simulation framework \n302\n can be, for example, the PETREL framework (Schlumberger, Houston, Tex.) and the technical data framework \n303\n can be, for example, the TECHLOG framework (Schlumberger, Houston, Tex.).', 'As an example, a framework can include entities that may include earth entities, geological objects or other objects such as wells, surfaces, reservoirs, etc. Entities can include virtual representations of actual physical entities that are reconstructed for purposes of one or more of evaluation, planning, engineering, operations, etc.', 'Entities may include entities based on data acquired via sensing, observation, etc. (e.g., seismic data and/or other information).', 'An entity may be characterized by one or more properties (e.g., a geometrical pillar grid entity of an earth model may be characterized by a porosity property).', 'Such properties may represent one or more measurements (e.g., acquired data), calculations, etc.', 'A framework may be an object-based framework.', 'In such a framework, entities may include entities based on pre-defined classes, for example, to facilitate modeling, analysis, simulation, etc.', 'An example of an object-based framework is the MICROSOFT .NET framework (Redmond, Wash.), which provides a set of extensible object classes.', 'In the .NET framework, an object class encapsulates a module of reusable code and associated data structures.', 'Object classes can be used to instantiate object instances for use in by a program, script, etc.', 'For example, borehole classes may define objects for representing boreholes based on well data.', 'As an example, a framework may be implemented within or in a manner operatively coupled to the DELFI cognitive exploration and production (E&P) environment (Schlumberger, Houston, Tex.), which is a secure, cognitive, cloud-based collaborative environment that integrates data and workflows with digital technologies, such as artificial intelligence and machine learning.', 'As an example, such an environment can provide for operations that involve one or more frameworks.', 'As an example, a framework can include an analysis component that may allow for interaction with a model or model-based results (e.g., simulation results, etc.).', 'As to simulation, a framework may operatively link to or include a simulator such as the ECLIPSE reservoir simulator (Schlumberger, Houston Tex.), the INTERSECT reservoir simulator (Schlumberger, Houston Tex.), etc.', 'The aforementioned PETREL framework provides components that allow for optimization of exploration and development operations.', 'The PETREL framework includes seismic to simulation software components that can output information for use in increasing reservoir performance, for example, by improving asset team productivity.', 'Through use of such a framework, various professionals (e.g., geophysicists, geologists, well engineers, reservoir engineers, etc.) can develop collaborative workflows and integrate operations to streamline processes.', 'Such a framework may be considered an application and may be considered a data-driven application (e.g., where data is input for purposes of modeling, simulating, etc.).', 'As mentioned with respect to the DELFI environment, one or more frameworks may be interoperative and/or run upon one or another.', 'As an example, a framework environment marketed as the OCEAN framework environment (Schlumberger, Houston, Tex.) may be utilized, which allows for integration of add-ons (or plug-ins) into a PETREL framework workflow.', 'In an example embodiment, various components may be implemented as add-ons (or plug-ins) that conform to and operate according to specifications of a framework environment (e.g., according to application programming interface (API) specifications, etc.).', 'As an example, a framework can include a model simulation layer along with a framework services layer, a framework core layer and a modules layer.', 'In a framework environment (e.g., OCEAN, DELFI, etc.), a model simulation layer can include or operatively link to a model-centric framework.', 'In an example embodiment, a framework may be considered to be a data-driven application.', 'For example, the PETREL framework can include features for model building and visualization.', 'As an example, a model may include one or more grids where a grid can be a spatial grid that conforms to spatial locations per acquired data (e.g., satellite data, logging data, seismic data, etc.).', 'As an example, a model simulation layer may provide domain objects, act as a data source, provide for rendering and provide for various user interfaces.', 'Rendering capabilities may provide a graphical environment in which applications can display their data while user interfaces may provide a common look and feel for application user interface components.', 'As an example, domain objects can include entity objects, property objects and optionally other objects.', 'Entity objects may be used to geometrically represent wells, surfaces, reservoirs, etc., while property objects may be used to provide property values as well as data versions and display parameters.', 'For example, an entity object may represent a well where a property object provides log information as well as version information and display information (e.g., to display the well as part of a model).', 'As an example, data may be stored in one or more data sources (or data stores, generally physical data storage devices), which may be at the same or different physical sites and accessible via one or more networks.', 'As an example, a model simulation layer may be configured to model projects.', 'As such, a particular project may be stored where stored project information may include inputs, models, results and cases.', 'Thus, upon completion of a modeling session, a user may store a project.', 'At a later time, the project can be accessed and restored using the model simulation layer, which can recreate instances of the relevant domain objects.', 'As an example, the system \n300\n may be used to perform one or more workflows.', 'A workflow may be a process that includes a number of worksteps.', 'A workstep may operate on data, for example, to create new data, to update existing data, etc.', 'As an example, a workflow may operate on one or more inputs and create one or more results, for example, based on one or more algorithms.', 'As an example, a system may include a workflow editor for creation, editing, executing, etc. of a workflow.', 'In such an example, the workflow editor may provide for selection of one or more pre-defined worksteps, one or more customized worksteps, etc.', 'As an example, a workflow may be a workflow implementable at least in part in the PETREL framework, for example, that operates on seismic data, seismic attribute(s), etc.', 'As an example, seismic data can be data acquired via a seismic survey where sources and receivers are positioned in a geologic environment to emit and receive seismic energy where at least a portion of such energy can reflect off subsurface structures.', 'As an example, a seismic data analysis framework or frameworks (e.g., consider the OMEGA framework, marketed by Schlumberger, Houston, Tex.) may be utilized to determine depth, extent, properties, etc. of subsurface structures.', 'As an example, seismic data analysis can include forward modeling and/or inversion, for example, to iteratively build a model of a subsurface region of a geologic environment.', 'As an example, a seismic data analysis framework may be part of or operatively coupled to a seismic-to-simulation framework (e.g., the PETREL framework, etc.).', 'As an example, a workflow may be a process implementable at least in part in a framework environment and by one or more frameworks.', 'As an example, a workflow may include one or more worksteps that access a set of instructions such as a plug-in (e.g., external executable code, etc.).', 'As an example, a framework environment may be cloud-based where cloud resources are utilized that may be operatively coupled to one or more pieces of field equipment such that data can be acquired, transmitted, stored, processed, analyzed, etc., using features of a framework environment.', 'As an example, a framework environment may employ various types of services, which may be backend, frontend or backend and frontend services.', 'For example, consider a client-server type of architecture where communications may occur via one or more application programming interfaces (APIs), one or more microservices, etc.', 'As an example, a framework may provide for modeling petroleum systems.', 'For example, the modeling framework marketed as the PETROMOD framework (Schlumberger, Houston, Tex.), which includes features for input of various types of information (e.g., seismic, well, geological, etc.) to model evolution of a sedimentary basin.', 'The PETROMOD framework provides for petroleum systems modeling via input of various data such as seismic data, well data and other geological data, for example, to model evolution of a sedimentary basin.', 'The PETROMOD framework may predict if, and how, a reservoir has been charged with hydrocarbons, including, for example, the source and timing of hydrocarbon generation, migration routes, quantities, pore pressure and hydrocarbon type in the subsurface or at surface conditions.', 'In combination with a framework such as the PETREL framework, workflows may be constructed to provide basin-to-prospect scale exploration solutions.', 'Data exchange between frameworks can facilitate construction of models, analysis of data (e.g., PETROMOD framework data analyzed using PETREL framework capabilities), and coupling of workflows.', 'As mentioned, a drillstring can include various tools that may make measurements.', 'As an example, a wireline tool or another type of tool may be utilized to make measurements.', 'As an example, a tool may be configured to acquire electrical borehole images.', 'As an example, the fullbore Formation Microlmager (FMI) tool (Schlumberger, Houston, Tex.) can acquire borehole image data.', 'A data acquisition sequence for such a tool can include running the tool into a borehole with acquisition pads closed, opening and pressing the pads against a wall of the borehole, delivering electrical current into the material defining the borehole while translating the tool in the borehole, and sensing current remotely, which is altered by interactions with the material.', 'Analysis of formation information may reveal features such as, for example, vugs, dissolution planes (e.g., dissolution along bedding planes), stress-related features, dip events, etc.', 'As an example, a tool may acquire information that may help to characterize a reservoir, optionally a fractured reservoir where fractures may be natural and/or artificial (e.g., hydraulic fractures).', 'As an example, information acquired by a tool or tools may be analyzed using a framework such as the TECHLOG framework.', 'As an example, the TECHLOG framework can be interoperable with one or more other frameworks such as, for example, the PETREL framework.', 'As an example, various aspects of a workflow may be completed automatically, may be partially automated, or may be completed manually, as by a human user interfacing with a software application that executes using hardware (e.g., local and/or remote).', 'As an example, a workflow may be cyclic, and may include, as an example, four stages such as, for example, an evaluation stage (see, e.g., the evaluation equipment \n310\n), a planning stage (see, e.g., the planning equipment \n320\n), an engineering stage (see, e.g., the engineering equipment \n330\n) and an execution stage (see, e.g., the operations equipment \n340\n).', 'As an example, a workflow may commence at one or more stages, which may progress to one or more other stages (e.g., in a serial manner, in a parallel manner, in a cyclical manner, etc.).', 'As an example, a workflow can commence with an evaluation stage, which may include a geological service provider evaluating a formation (see, e.g., the evaluation block \n314\n).', 'As an example, a geological service provider may undertake the formation evaluation using a computing system executing a software package tailored to such activity; or, for example, one or more other suitable geology platforms may be employed (e.g., alternatively or additionally).', 'As an example, the geological service provider may evaluate the formation, for example, using earth models, geophysical models, basin models, petrotechnical models, combinations thereof, and/or the like.', 'Such models may take into consideration a variety of different inputs, including offset well data, seismic data, pilot well data, other geologic data, etc.', 'The models and/or the input may be stored in the database maintained by the server and accessed by the geological service provider.', 'As an example, a workflow may progress to a geology and geophysics (“G&G”) service provider, which may generate a well trajectory (see, e.g., the generation block \n324\n), which may involve execution of one or more G&G software packages.', 'Examples of such software packages include the PETREL framework.', 'As an example, a G&G service provider may determine a well trajectory or a section thereof, based on, for example, one or more model(s) provided by a formation evaluation (e.g., per the evaluation block \n314\n), and/or other data, e.g., as accessed from one or more databases (e.g., maintained by one or more servers, etc.).', 'As an example, a well trajectory may take into consideration various “basis of design” (BOD) constraints, such as general surface location, target (e.g., reservoir) location, and the like.', 'As an example, a trajectory may incorporate information about tools, bottom-hole assemblies, casing sizes, etc., that may be used in drilling the well.', 'A well trajectory determination may take into consideration a variety of other parameters, including risk tolerances, fluid weights and/or plans, bottom-hole pressures, drilling time, etc.', 'As an example, a workflow may progress to a first engineering service provider (e.g., one or more processing machines associated therewith), which may validate a well trajectory and, for example, relief well design (see, e.g., the validation block \n328\n).', 'Such a validation process may include evaluating physical properties, calculations, risk tolerances, integration with other aspects of a workflow, etc.', 'As an example, one or more parameters for such determinations may be maintained by a server and/or by the first engineering service provider; noting that one or more model(s), well trajectory(ies), etc. may be maintained by a server and accessed by the first engineering service provider.', 'For example, the first engineering service provider may include one or more computing systems executing one or more software packages.', 'As an example, where the first engineering service provider rejects or otherwise suggests an adjustment to a well trajectory, the well trajectory may be adjusted or a message or other notification sent to the G&G service provider requesting such modification.', 'As an example, one or more engineering service providers (e.g., first, second, etc.) may provide a casing design, bottom-hole assembly (BHA) design, fluid design, and/or the like, to implement a well trajectory (see, e.g., the design block \n338\n).', 'In some embodiments, a second engineering service provider may perform such design using one of more software applications.', 'Such designs may be stored in one or more databases maintained by one or more servers, which may, for example, employ STUDIO framework tools (Schlumberger, Houston, Tex.), and may be accessed by one or more of the other service providers in a workflow.', 'As an example, a second engineering service provider may seek approval from a third engineering service provider for one or more designs established along with a well trajectory.', "In such an example, the third engineering service provider may consider various factors as to whether the well engineering plan is acceptable, such as economic variables (e.g., oil production forecasts, costs per barrel, risk, drill time, etc.), and may request authorization for expenditure, such as from the operating company's representative, well-owner's representative, or the like (see, e.g., the formulation block \n334\n).", 'As an example, at least some of the data upon which such determinations are based may be stored in one or more database maintained by one or more servers.', 'As an example, a first, a second, and/or a third engineering service provider may be provided by a single team of engineers or even a single engineer, and thus may or may not be separate entities.', 'As an example, where economics may be unacceptable or subject to authorization being withheld, an engineering service provider may suggest changes to casing, a bottom-hole assembly, and/or fluid design, or otherwise notify and/or return control to a different engineering service provider, so that adjustments may be made to casing, a bottom-hole assembly, and/or fluid design.', 'Where modifying one or more of such designs is impracticable within well constraints, trajectory, etc., the engineering service provider may suggest an adjustment to the well trajectory and/or a workflow may return to or otherwise notify an initial engineering service provider and/or a G&G service provider such that either or both may modify the well trajectory.', 'As an example, a workflow can include considering a well trajectory, including an accepted well engineering plan, and a formation evaluation.', 'Such a workflow may then pass control to a drilling service provider, which may implement the well engineering plan, establishing safe and efficient drilling, maintaining well integrity, and reporting progress as well as operating parameters (see, e.g., the blocks \n344\n and \n348\n).', 'As an example, operating parameters, formation encountered, data collected while drilling (e.g., using logging-while-drilling or measuring-while-drilling technology), may be returned to a geological service provider for evaluation.', 'As an example, the geological service provider may then re-evaluate the well trajectory, or one or more other aspects of the well engineering plan, and may, in some cases, and potentially within predetermined constraints, adjust the well engineering plan according to the real-life drilling parameters (e.g., based on acquired data in the field, etc.).', 'Whether the well is entirely drilled, ora section thereof is completed, depending on the specific embodiment, a workflow may proceed to a post review (see, e.g., the evaluation block \n318\n).', 'As an example, a post review may include reviewing drilling performance.', 'As an example, a post review may further include reporting the drilling performance (e.g., to one or more relevant engineering, geological, or G&G service providers).', 'Various activities of a workflow may be performed consecutively and/or may be performed out of order (e.g., based partially on information from templates, nearby wells, etc. to fill in any gaps in information that is to be provided by another service provider).', 'As an example, undertaking one activity may affect the results or basis for another activity, and thus may, either manually or automatically, call for a variation in one or more workflow activities, work products, etc.', 'As an example, a server may allow for storing information on a central database accessible to various service providers where variations may be sought by communication with an appropriate service provider, may be made automatically, or may otherwise appear as suggestions to the relevant service provider.', 'Such an approach may be considered to be a holistic approach to a well workflow, in comparison to a sequential, piecemeal approach.', 'As an example, various actions of a workflow may be repeated multiple times during drilling of a wellbore.', 'For example, in one or more automated systems, feedback from a drilling service provider may be provided at or near real-time, and the data acquired during drilling may be fed to one or more other service providers, which may adjust its piece of the workflow accordingly.', 'As there may be dependencies in other areas of the workflow, such adjustments may permeate through the workflow, e.g., in an automated fashion.', 'In some embodiments, a cyclic process may additionally or instead proceed after a certain drilling goal is reached, such as the completion of a section of the wellbore, and/or after the drilling of the entire wellbore, or on a per-day, week, month, etc., basis.', 'Well planning can include determining a path of a well (e.g., a trajectory) that can extend to a reservoir, for example, to economically produce fluids such as hydrocarbons therefrom.', 'Well planning can include selecting a drilling and/or completion assembly which may be used to implement a well plan.', 'As an example, various constraints can be imposed as part of well planning that can impact design of a well.', 'As an example, such constraints may be imposed based at least in part on information as to known geology of a subterranean domain, presence of one or more other wells (e.g., actual and/or planned, etc.) in an area (e.g., consider collision avoidance), etc.', 'As an example, one or more constraints may be imposed based at least in part on characteristics of one or more tools, components, etc.', 'As an example, one or more constraints may be based at least in part on factors associated with drilling time and/or risk tolerance.', 'As an example, a system can allow for a reduction in waste, for example, as may be defined according to LEAN.', 'In the context of LEAN, consider one or more of the following types of waste: transport (e.g., moving items unnecessarily, whether physical or data); inventory (e.g., components, whether physical or informational, as work in process, and finished product not being processed); motion (e.g., people or equipment moving or walking unnecessarily to perform desired processing); waiting (e.g., waiting for information, interruptions of production during shift change, etc.); overproduction (e.g., production of material, information, equipment, etc. ahead of demand); over processing (e.g., resulting from poor tool or product design creating activity); and defects (e.g., effort involved in inspecting for and fixing defects whether in a plan, data, equipment, etc.).', 'As an example, a system that allows for actions (e.g., methods, workflows, etc.) to be performed in a collaborative manner can help to reduce one or more types of waste.', 'As an example, a system can be utilized to implement a method for facilitating distributed well engineering, planning, and/or drilling system design across multiple computation devices where collaboration can occur among various different users (e.g., some being local, some being remote, some being mobile, etc.).', 'In such a system, the various users via appropriate devices may be operatively coupled via one or more networks (e.g., local and/or wide area networks, public and/or private networks, land-based, marine-based and/or areal networks, etc.).', 'As an example, a system may allow well engineering, planning, and/or drilling system design to take place via a subsystems approach where a wellsite system is composed of various subsystem, which can include equipment subsystems and/or operational subsystems (e.g., control subsystems, etc.).', 'As an example, computations may be performed using various computational platforms/devices that are operatively coupled via communication links (e.g., network links, etc.).', 'As an example, one or more links may be operatively coupled to a common database (e.g., a server site, etc.).', 'As an example, a particular server or servers may manage receipt of notifications from one or more devices and/or issuance of notifications to one or more devices.', 'As an example, a system may be implemented for a project where the system can output a well plan, for example, as a digital well plan, a paper well plan, a digital and paper well plan, etc.', 'Such a well plan can be a complete well engineering plan or design for the particular project.\n \nFIG.', '4\n shows an example of a wellsite system \n400\n, specifically, \nFIG.', '4\n shows the wellsite system \n400\n in an approximate side view and an approximate plan view along with a block diagram of a system \n470\n.', 'In the example of \nFIG.', '4\n, the wellsite system \n400\n can include a cabin \n410\n, a rotary table \n422\n, drawworks \n424\n, a mast \n426\n (e.g., optionally carrying a top drive, etc.), mud tanks \n430\n (e.g., with one or more pumps, one or more shakers, etc.), one or more pump buildings \n440\n, a boiler building \n442\n, an HPU building \n444\n (e.g., with a rig fuel tank, etc.), a combination building \n448\n (e.g., with one or more generators, etc.), pipe tubs \n462\n, a catwalk \n464\n, a flare \n468\n, etc.', 'Such equipment can include one or more associated functions and/or one or more associated operational risks, which may be risks as to time, resources, and/or humans.', 'As shown in the example of \nFIG.', '4\n, the wellsite system \n400\n can include a system \n470\n that includes one or more processors \n472\n, memory \n474\n operatively coupled to at least one of the one or more processors \n472\n, instructions \n476\n that can be, for example, stored in the memory \n474\n, and one or more interfaces \n478\n.', 'As an example, the system \n470\n can include one or more processor-readable media that include processor-executable instructions executable by at least one of the one or more processors \n472\n to cause the system \n470\n to control one or more aspects of the wellsite system \n400\n.', 'In such an example, the memory \n474\n can be or include the one or more processor-readable media where the processor-executable instructions can be or include instructions.', 'As an example, a processor-readable medium can be a computer-readable storage medium that is not a signal and that is not a carrier wave.\n \nFIG.', '', '4\n also shows a battery \n480\n that may be operatively coupled to the system \n470\n, for example, to power the system \n470\n.', 'As an example, the battery \n480\n may be a back-up battery that operates when another power supply is unavailable for powering the system \n470\n.', 'As an example, the battery \n480\n may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery \n480\n can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.', 'In the example of \nFIG.', '4\n, services \n490\n are shown as being available, for example, via a cloud platform.', 'Such services can include data services \n492\n, query services \n494\n and drilling services \n496\n.', 'As an example, the services \n490\n may be part of a system such as the system \n300\n of \nFIG.', '3\n.', 'As an example, the system \n470\n may be utilized to generate one or more sequences and/or to receive one or more sequences, which may, for example, be utilized to control one or more drilling operations.', 'For example, consider a sequence that includes a sliding mode and a drilling mode and a transition therebetween.\n \nFIG.', '5\n shows a schematic diagram depicting an example of a drilling operation of a directional well in multiple sections.', 'The drilling operation depicted in \nFIG.', '5\n includes a wellsite drilling system \n500\n and a field management tool \n520\n for managing various operations associated with drilling a bore hole \n550\n of a directional well \n517\n.', 'The wellsite drilling system \n500\n includes various components (e.g., drillstring \n512\n, annulus \n513\n, bottom hole assembly (BHA) \n514\n, kelly \n515\n, mud pit \n516\n, etc.).', 'As shown in the example of \nFIG.', '5\n, a target reservoir may be located away from (as opposed to directly under) the surface location of the well \n517\n.', 'In such an example, special tools or techniques may be used to ensure that the path along the bore hole \n550\n reaches the particular location of the target reservoir.', 'As an example, the BHA \n514\n may include sensors \n508\n, a rotary steerable system (RSS) \n509\n, and a bit \n510\n to direct the drilling toward the target guided by a pre-determined survey program for measuring location details in the well.', 'Furthermore, the subterranean formation through which the directional well \n517\n is drilled may include multiple layers (not shown) with varying compositions, geophysical characteristics, and geological conditions.', 'Both the drilling planning during the well design stage and the actual drilling according to the drilling plan in the drilling stage may be performed in multiple sections (see, e.g., sections \n501\n, \n502\n, \n503\n and \n504\n), which may correspond to one or more of the multiple layers in the subterranean formation.', 'For example, certain sections (e.g., sections \n501\n and \n502\n) may use cement \n507\n reinforced casing \n506\n due to the particular formation compositions, geophysical characteristics, and geological conditions.', 'In the example of \nFIG.', '5\n, a surface unit \n511\n may be operatively linked to the wellsite drilling system \n500\n and the field management tool \n520\n via communication links \n518\n.', 'The surface unit \n511\n may be configured with functionalities to control and monitor the drilling activities by sections in real time via the communication links \n518\n.', 'The field management tool \n520\n may be configured with functionalities to store oilfield data (e.g., historical data, actual data, surface data, subsurface data, equipment data, geological data, geophysical data, target data, anti-target data, etc.) and determine relevant factors for configuring a drilling model and generating a drilling plan.', 'The oilfield data, the drilling model, and the drilling plan may be transmitted via the communication link \n518\n according to a drilling operation workflow.', 'The communication links \n518\n may include a communication subassembly.', 'During various operations at a wellsite, data can be acquired for analysis and/or monitoring of one or more operations.', 'Such data may include, for example, subterranean formation, equipment, historical and/or other data.', 'Static data can relate to, for example, formation structure and geological stratigraphy that define the geological structures of the subterranean formation.', 'Static data may also include data about a bore, such as inside diameters, outside diameters, and depths.', 'Dynamic data can relate to, for example, fluids flowing through the geologic structures of the subterranean formation over time.', 'The dynamic data may include, for example, pressures, fluid compositions (e.g. gas oil ratio, water cut, and/or other fluid compositional information), and states of various equipment, and other information.', 'The static and dynamic data collected via a bore, a formation, equipment, etc. may be used to create and/or update a three dimensional model of one or more subsurface formations.', 'As an example, static and dynamic data from one or more other bores, fields, etc. may be used to create and/or update a three dimensional model.', 'As an example, hardware sensors, core sampling, and well logging techniques may be used to collect data.', 'As an example, static measurements may be gathered using downhole measurements, such as core sampling and well logging techniques.', 'Well logging involves deployment of a downhole tool into the wellbore to collect various downhole measurements, such as density, resistivity, etc., at various depths.', 'Such well logging may be performed using, for example, a drilling tool and/or a wireline tool, or sensors located on downhole production equipment.', 'Once a well is formed and completed, depending on the purpose of the well (e.g., injection and/or production), fluid may flow to the surface (e.g., and/or from the surface) using tubing and other completion equipment.', 'As fluid passes, various dynamic measurements, such as fluid flow rates, pressure, and composition may be monitored.', 'These parameters may be used to determine various characteristics of a subterranean formation, downhole equipment, downhole operations, etc.', 'As an example, a system can include a framework that can acquire data such as, for example, real time data associated with one or more operations such as, for example, a drilling operation or drilling operations.', 'As an example, consider the PERFORM toolkit framework (Schlumberger Limited, Houston, Tex.).', 'As an example, a service can be or include one or more of OPTIDRILL, OPTILOG and/or other services marketed by Schlumberger Limited, Houston, Tex.', 'The OPTIDRILL technology can help to manage downhole conditions and BHA dynamics as a real time drilling intelligence service.', 'The service can incorporate a rigsite display (e.g., a wellsite display) of integrated downhole and surface data that provides actionable information to mitigate risk and increase efficiency.', 'As an example, such data may be stored, for example, to a database system (e.g., consider a database system associated with the STUDIO framework).', 'The OPTILOG technology can help to evaluate drilling system performance with single- or multiple-location measurements of drilling dynamics and internal temperature from a recorder.', 'As an example, post-run data can be analyzed to provide input for future well planning.', 'As an example, information from a drill bit database may be accessed and utilized.', 'For example, consider information from Smith Bits (Schlumberger Limited, Houston, Tex.), which may include information from various operations (e.g., drilling operations) as associated with various drill bits, drilling conditions, formation types, etc.', 'As an example, one or more QTRAC services (Schlumberger Limited, Houston Tex.) may be provided for one or more wellsite operations.', 'In such an example, data may be acquired and stored where such data can include time series data that may be received and analyzed, etc.', 'As an example, one or more M-I SWACO services (M-I L.L.C., Houston, Tex.) may be provided for one or more wellsite operations.', 'For example, consider services for value-added completion and reservoir drill-in fluids, additives, cleanup tools, and engineering.', 'In such an example, data may be acquired and stored where such data can include time series data that may be received and analyzed, etc.', 'As an example, one or more ONE-TRAX services (e.g., via the ONE-TRAX software platform, M-I L.L.C., Houston, Tex.) may be provided for one or more wellsite operations.', 'In such an example, data may be acquired and stored where such data can include time series data that may be received and analyzed, etc.', 'As an example, various operations can be defined with respect to WITS or WITSML, which are acronyms for well-site information transfer specification or standard (WITS) and markup language (WITSML).', 'WITS/WITSML specify how a drilling rig or offshore platform drilling rig can communicate data.', 'For example, as to slips, which are an assembly that can be used to grip a drillstring in a relatively non-damaging manner and suspend the drillstring in a rotary table, WITS/WITSML define operations such as “bottom to slips” time as a time interval between coming off bottom and setting slips, for a current connection; “in slips” as a time interval between setting the slips and then releasing them, for a current connection; and “slips to bottom” as a time interval between releasing the slips and returning to bottom (e.g., setting weight on the bit), for a current connection.', 'Well construction can occur according to various procedures, which can be in various forms.', 'As an example, a procedure can be specified digitally and may be, for example, a digital plan such as a digital well plan.', 'A digital well plan can be an engineering plan for constructing a wellbore.', 'As an example, procedures can include information such as well geometries, casing programs, mud considerations, well control concerns, initial bit selections, offset well information, pore pressure estimations, economics and special procedures that may be utilized during the course of well construction, production, etc.', 'While a drilling procedure can be carefully developed and specified, various conditions can occur that call for adjustment to a drilling procedure.', 'As an example, an adjustment can be made at a rigsite when acquisition equipment acquire information about conditions, which may be for conditions of drilling equipment, conditions of a formation, conditions of fluid(s), conditions as to environment (e.g., weather, sea, etc.), etc.', 'Such an adjustment may be made on the basis of personal knowledge of one or more individuals at a rigsite.', 'As an example, an operator may understand that conditions call for an increase in mudflow rate, a decrease in weight on bit, etc.', 'Such an operator may assess data as acquired via one or more sensors (e.g., torque, temperature, vibration, etc.).', 'Such an operator may call for performance of a procedure, which may be a test procedure to acquire additional data to understand better actual physical conditions and physical phenomena that may occur or that are occurring.', 'An operator may be under one or more time constraints, which may be driven by physical phenomena, such as fluid flow, fluid pressure, compaction of rock, borehole stability, etc.', 'In such an example, decision making by the operator can depend on time as conditions evolve.', 'For example, a decision made at one fluid pressure may be sub-optimal at another fluid pressure in an environment where fluid pressure is changing.', 'In such an example, timing as to implementing a decision as an adjustment to a procedure can have a broad ranging impact.', 'An adjustment to a procedure that is made too late or too early can adversely impact other procedures compared to an adjustment to a procedure that is made at an optimal time (e.g., and implemented at the optimal time).', 'As an example, a system can include one or more automation assisted features.', 'For example, consider a feature that can generate and/or receive one or more sequences that can be utilized to control a drilling operation.', 'In such an example, a driller may utilize a generated sequence to control one or more pieces of equipment to drill a borehole.', 'As an example, where automation can issue signals to one or more pieces of equipment, a controller can utilize a generated sequence or a portion thereof for automatic control.', 'As explained, where a driller is involved in decision making and/or control, a generated sequence may facilitate drilling as the driller may rely on the generated sequence for making one or more adjustments to a drilling operation.', 'Where one or more generated sequences are received in advance and/or in real-time, drilling operations can be performed more efficiently, for example, with respect to time to drill a section, a portion of a section, an entire borehole, etc.', 'Such an approach may take equipment integrity (e.g., health, etc.) into consideration, for example, such an approach may account for risk of contact between a bit body and a formation and/or mud motor performance where a mud motor can be utilized to drive a bit.\n \nFIG.', '6\n shows an example of a graphical user interface (GUI) \n600\n that includes information associated with a well plan.', 'Specifically, the GUI \n600\n includes a panel \n610\n where surfaces representations \n612\n and \n614\n are rendered along with well trajectories where a location \n616\n can represent a position of a drillstring \n617\n along a well trajectory.', 'The GUI \n600\n may include one or more editing features such as an edit well plan set of features \n630\n.', 'The GUI \n600\n may include information as to individuals of a team \n640\n that are involved, have been involved and/or are to be involved with one or more operations.', 'The GUI \n600\n may include information as to one or more activities \n650\n.', 'As shown in the example of \nFIG.', '6', ', the GUI \n600\n can include a graphical control of a drillstring \n660\n where, for example, various portions of the drillstring \n660\n may be selected to expose one or more associated parameters (e.g., type of equipment, equipment specifications, operational history, etc.).', 'In the example of \nFIG. \n6\n, the drillstring graphical control \n660\n includes components such as drill pipe, heavy weight drill pipe (HWDP), subs, collars, jars, stabilizers, motor(s) and a bit.', 'A drillstring can be a combination of drill pipe, a bottom hole assembly (BHA) and one or more other tools, which can include one or more tools that can help a drill bit turn and drill into material (e.g., a formation).', 'As an example, a workflow can include utilizing the graphical control of the drillstring \n660\n to select and/or expose information associated with a component or components such as, for example, a bit and/or a mud motor.', 'As an example, in response to selection of a bit and/or a mud motor (e.g., consider a bit and mud motor combination), a computational framework (e.g., via a sequence engine, etc.) can generate one or more sequences, which may be utilized, for example, to operating drilling equipment in a particular mode (e.g., sliding mode, rotating mode, etc.).', 'In the example of \nFIG. \n6\n, a graphical control \n665\n is shown that can be rendered responsive to interaction with the graphical control of the drillstring \n660\n, for example, to select a type of component and/or to generate one or more sequences, etc.\n \nFIG.', '6\n also shows an example of a table \n670\n as a point spreadsheet that specifies information for a plurality of wells.', 'As shown in the example table \n670\n, coordinates such as “x” and “y” and “depth” can be specified for various features of the wells, which can include pad parameters, spacings, toe heights, step outs, initial inclinations, kick offs, etc.\n \nFIG.', '7\n shows an example of a method \n700\n that utilizes drilling equipment to perform drilling operations.', 'As shown, the drilling equipment includes a rig \n701\n, a lift system \n702\n, a block \n703\n, a platform \n704\n, slips \n705\n and a bottom hole assembly \n706\n.', 'As shown, the rig \n701\n supports the lift system \n702\n, which provides for movement of the block \n703\n above the platform \n704\n where the slips \n705\n may be utilized to support a drillstring that includes the bottom hole assembly \n706\n, which is shown as including a bit to drill into a formation to form a borehole.', 'As to the drilling operations, they include a first operation \n710\n that completes a stand (Stand X) of the drillstring; a second operation \n720\n that pulls the drillstring off the bottom of the borehole by moving the block \n703\n upwardly and that supports the drillstring in the platform \n704\n using the slips \n705\n; a third operation \n730\n that adds a stand (Stand X+1) to the drillstring; and a fourth operation \n740\n that removes the slips \n705\n and that lowers the drillstring to the bottom of the borehole by moving the block \n703\n downwardly.', 'Various details of examples of equipment and examples of operations are also explained with respect to \nFIGS.', '1\n, \n2\n, \n3\n, \n4\n, \n5\n and \n6\n.', 'As an example, drilling operations may utilize one or more types of equipment to drill, which can provide for various modes of drilling.', 'As a borehole is deepened by drilling, as explained, stands can be added to a drillstring.', 'A stand can be one or more sections of pipe; noting that a pipe-by-pipe or hybrid stand and pipe approach may be utilized.', 'In the example of \nFIG.', '7\n, the operations \n710\n, \n720\n, \n730\n and \n740\n may take a period of time that may be of the order of minutes.', 'For example, consider the amount of time it takes to position and connect a stand to another stand of a drillstring.', 'A stand may be approximately 30 meters in length where precautions are taken to avoid detrimental contacting of the stand (metal or metal alloy) with other equipment or humans.', 'During the period of time, one or more types of calculations, computations, communications, etc., may occur.', 'For example, a driller may perform a depth of hole calculation based on a measured length of a stand, etc.', 'As an example, a driller may analyze survey data as acquired by one or more downhole tools of a drillstring.', 'Such survey data may help a driller to determine whether or not a planned or otherwise desired trajectory is being followed, which may help to inform the driller as to how drilling is to occur for an increase in borehole depth corresponding approximately to the length of the added stand.', 'As an example, where a top drive is utilized (e.g., consider the block \n703\n as including a top drive), as the top drive approaches the platform \n704\n, rotation and circulation can be stopped and the drillstring lifted a distance off the bottom of the borehole.', 'As the top drive is to be coupled to another stand, it is to be disconnected, which means that the drillstring is to be supported, which can be accomplished through use of the slips \n705\n.', 'The slips \n705\n can be set on a portion of the last stand (e.g., a pipe) to support the weight of the drillstring such that the top drive can be disconnected from the drillstring by operator(s), for example, using a top drive pipehandler.', 'Once disconnected, the driller can then raise the top drive (e.g., the block \n703\n) to an appropriate level such as a fingerboard level, where another stand of pipe (e.g., approximately 30 m) can be delivered to a set of drill pipe elevators hanging from the top drive.', 'The stand (e.g., Stand X+1) can be raised and stabbed into the drillstring.', 'The top drive can then be lowered until its drive stem engages an upper connection of the stand (e.g., Stand X+1).', 'The top drive motor can be engaged to rotate the drive stem such that upper and lower connections of the stand are made up relatively simultaneously.', 'In such an example, a backup tong may be used at the platform \n704\n (e.g., drill floor) to prevent rotation of the drillstring as the connections are being made.', 'After the connections are properly made up, the slips \n705\n can be released (e.g., out-of-slips).', 'Circulation of drilling fluid (e.g., mud) can commence (e.g., resume) and, once the bit of the bottom hole assembly \n706\n contacts the bottom of the borehole, the top drive can be utilized for drilling to deepen the borehole.', 'The entire process, from the time the slips are set on the drillstring (e.g., in-slips), a new stand is added, the connections are made up, and the slips are released (e.g., out-of-slips), allowing drilling to resume, can take on the order of tens of seconds to minutes, generally less than 10 minutes where operations are normal and as expected.', 'As to the aforementioned top drive approach, the process of adding a new stand of pipe to the drillstring, and drilling down to the platform (e.g., the floor), can involve fewer actions and demand less involvement from a drill crew when compared to kelly drilling (e.g., rotary table drilling).', 'Drillers and rig crews can become relatively proficient in drilling with top drives.', 'Built-in features such as thread compensation, remote-controlled valves to stop the flow of drilling fluids, and mechanisms to tilt the elevators and links to the derrickman or floor crew can add to speed, convenience and safety associated with top drive drilling.', 'As an example, a top drive can be utilized when drilling with single joints (e.g., 10 m lengths) of pipe, although greater benefit may be achieved by drilling with triples (e.g., stands of pipe).', 'As explained, with the drill pipe being supported and rotated from the top, an entire stand of drill pipe can be drilled down at one time.', 'Such an approach can extend the time the bit is on bottom and can help to produce a cleaner borehole.', 'Compared to kelly drilling, where a connection is made after drilling down a single joint of pipe, top drive drilling can result in faster drilling by reducing demand for two out of three connections.', 'As mentioned, a well can be a direction well, which is constructed using directional drilling.', 'Directional wells have been a boon to oil and gas production, particularly in unconventional plays, where horizontal and extended-reach wells can help to maximize wellbore exposure through productive zones.', 'One or more of various technologies can be utilized for directional drilling.', 'For example, consider a steerable mud motor that can be utilized to achieve a desired borehole trajectory to and/or through one or more target zones.', 'As an example, a directional drilling operation can use a downhole mud motor when they kick off the well, build angle, drill tangent sections and maintain trajectory.', 'A mud motor can include a bend in a motor bearing housing that provides for steering a bit toward a desired target.', 'A bend can be surface adjustable (e.g., a surface adjustable bend (SAB)) and, for example, set at an angle in a range of operational angles (e.g., consider 0 degrees to approximate 5 degrees, 0 degrees to approximately 4 degrees, 0 degrees to approximately 3 degrees, etc.).', 'The bend can aim to be sufficient for pointing the bit in a given direction while being small enough to permit rotation of the entire mud motor assembly during rotary drilling.', 'The deflection cause by a bend can be a factor that determines a rate at which a mud motor can build angle to construct a desired borehole.', 'By orienting the bend in a specific direction, referred to as a toolface angle, a drilling operation can change the inclination and azimuth of a borehole trajectory.', 'To maintain the orientation of the bend, the drillstring is operated in a sliding mode where the entire drillstring itself does not rotate in the borehole (e.g., via a top drive, a rotary table, etc.)', 'and where bit rotation for drilling is driven by a mud motor of the drillstring.', 'A mud motor is a type of positive displacement motor (PDM) powered by drilling fluid.', 'As an example, a mud motor can include an eccentric helical rotor and stator assembly drive.', 'As drilling fluid (e.g., mud) is pumped downhole, the drilling fluid flows through the stator and turns the rotor.', 'The mud motor converts hydraulic power to mechanical power to turn a drive shaft that causes a bit operatively coupled to the mud motor to rotate.', 'Through use of a mud motor, a directional drilling operation can alternate between rotating and sliding modes of drilling.', 'In the rotating mode, a rotary table or top drive is operated to rotate an entire drillstring to transmit power to a bit.', 'As mentioned, the rotating mode can include combined rotation via surface equipment and via a downhole mud motor.', 'In the rotating mode, rotation enables a bend in the motor bearing housing to be directed equally across directions and thus maintain a straight drilling path.', 'As an example, one or more measurement-while-drilling (MWD) tools integrated into a drillstring can provide real-time inclination and azimuth measurements.', 'Such measurements may be utilized to alert a driller, a controller, etc., to one or more deviations from a desired trajectory (e.g., a planned trajectory, etc.).', 'To adjust for a deviation or to alter a trajectory, a drilling operation can switch from the rotating mode to the sliding mode.', 'As mentioned, in the sliding mode, the drillstring is not rotated; rather, a downhole motor turns the bit and the borehole is drilled in the direction the bit is point, which is controlled by a motor toolface orientation.', 'Upon adjustment of course and reestablishing a desired trajectory that aims to hit a target (or targets), a drilling operation may transition from the sliding mode to the rotating mode, which, as mentioned, can be a combined surface and downhole rotating mode.', 'Of the two modes, slide drilling of the sliding mode tends to be less efficient; hence, lateral reach can come at the expense of penetration rate.', 'The rate of penetration (ROP) achieved using a sliding technique tends to be approximately 10 percent to 25 percent of that attainable using a rotating technique.', 'For example, when a mud motor is operated in the sliding mode, axial drag force in a curve portion and/or in a lateral portion acts to reduce the impact of surface weight such that surface weight is not effectively transferred downhole to a bit, which can lead to a lower penetration rate and lower drilling efficiency.', 'Various types of automated systems (e.g., auto drillers) may aim to help a drilling operation to achieve gains in horizontal reach with noticeably faster rates of penetration.', 'When transitioning from the rotating mode to the sliding mode, a drilling operation can halt rotation of a drillstring and initiate a slide by orienting a bit to drill, for example, in alignment with a trajectory proposed in a well plan.', 'As to halting rotation of a drillstring, consider, as an example, a drilling operation that pulls a bit off-bottom and reciprocates drillpipe to release torque that has built up within the drillstring.', 'The drilling operation can then orient a downhole mud motor using real-time MWD toolface measurements to ensure the specified borehole deviation is obtained.', 'Following this relatively time-consuming orientation process, the drilling operation can set a top drive brake to prevent further rotation from the surface.', 'In such an example, a sliding drilling operation can begin as the drilling operation eases off a drawworks brake to control hook load, which, in turn, affects the magnitude of weight imposed at the bit (e.g., WOB).', 'As an example, minor right and left torque adjustments (e.g., clockwise and counter-clockwise) may be applied manually to steer the bit as appropriate to keep the trajectory on course.', 'As the depth or lateral reach increases, a drillstring tends to be subjected to greater friction and drag.', 'These forces, in turn, affect ability to transfer weight to the bit (e.g., WOB) and control toolface orientation while sliding, which may make it more difficult to attain sufficient ROP and maintain a desired trajectory to a target (or targets).', 'Such issues can result in increased drilling time, which may adversely impact project economics and ultimately limit length of a lateral section of a borehole and hence a lateral section of a completed well (e.g., a producing well).', 'The capability to transfer weight to a bit affects several aspects of directional drilling.', 'As an example, a drilling operation can transfers weight to a bit by easing, or slacking off, a brake, which can transfer some of the hook load, or drillstring weight, to the bit.', 'The difference between the weight imposed at the bit and the amount of weight made available by easing the brake at the surface is primarily caused by drag.', 'As a horizontal departure of a borehole increases, longitudinal drag of the drillpipe along the borehole tends to increase.', 'Controlling weight at the bit throughout the sliding mode can be made more difficult by drillstring elasticity, which permits the pipe to move nonproportionally.', 'Such elasticity can cause one segment of drillstring to move while other segments remain stationary or move at different velocities.', 'Conditions such as, for example, poor hole cleaning may also affect weight transfer.', 'In the sliding mode, hole cleaning tends to be less efficient because of a lack of pipe rotation; noting that pipe rotation facilitates turbulent flow in the annulus between the pipe (drillstring pipe or stands) and the borehole and/or cased section(s).', 'Poor hole cleaning is associated with ability to carry solids (e.g., crushed rock) in drilling fluid (e.g., mud).', 'As solids accumulate on the low side of a borehole due to gravity, the cross-sectional area of the borehole can decrease and cause an increase in friction on a drillstring (e.g., pipe or stands), which can make it more difficult to maintain a desired weight on bit (WOB), which may be a desired constant WOB.', 'As an example, poor hole cleaning may give rise to an increased risk of sticking (e.g., stuck pipe).', 'Differences in frictional forces between a drillstring inside of casing versus that in open hole can cause weight to be released suddenly, as can hang-ups caused by key seats and ledges.', "A sudden transfer of weight to the bit that exceeds a downhole motor's capacity may cause bit rotation to abruptly halt and the motor to stall.", 'Frequent stalling can damage the stator component of a mud motor, depending on the amount of the weight transferred.', 'A drilling operation can aim to operate a mud motor within a relatively narrow load range in an effort to maintain an acceptable ROP without stalling.', 'As an example, a system can include a console, which can include one or more displays that can render one or more graphical user interfaces (GUIs) that include data from one or more sensors.', 'As an example, an impending stall might be indicated by an increase in WOB as rendered to a GUI, for example, with no corresponding upsurge in downhole pressure to signal that an increase in downhole WOB has actually occurred.', 'In such an example, at some point, the WOB indicator may show an abrupt decrease, indicating a sudden transfer of force from the drillstring to the bit.', 'Increases in drag impede an ability to remove torque downhole, making it more difficult to set and maintain toolface orientation.', 'Toolface orientation can be affected by torque and WOB.', 'When weight is applied to the bit, torque at the bit tends to increase.', 'As mentioned, torque can be transmitted downhole through a drillstring, which is operated generally for drilling by turning to the right, in a clockwise direction.', 'As weight is applied to the bit, reactive torque, acting in the opposite direction, can develop.', 'Such left-hand torque (e.g., bit reaction torque in a counter-clockwise direction) tends to twist the drillstring due to the elastic flexibility of drillstring in torsional direction.', 'In such conditions, the motor toolface angle can rotate with the twist of drillstring.', 'A drilling operation can consider the twist angle due to reactive torque when the drilling operation tries to orient the toolface of a mud motor from the surface.', 'Reactive torque tends to build as weight is increased, for example, reaching its maximum value when a mud motor stalls.', 'As an example, reactive torque can be taken into account as a drilling operation tries to orient a mud motor from the surface.', 'In practice, a drilling operation may act to make minor shifts in toolface orientation by changing downhole WOB, which alters the reactive torque.', 'To produce larger changes, the drilling operation may act to lift a bit off-bottom and reorient the toolface.', 'However, even after the specified toolface orientation is achieved, maintaining that orientation can be at times challenging.', 'As mentioned, longitudinal drag tends to increases with lateral reach, and weight transfer to the bit can become more erratic along the length of a horizontal section, thus allowing reactive torque to build and consequently change the toolface angle.', 'The effort and time spent on orienting the toolface can adversely impact productive time on the rig.', 'As explained, directional drilling can involve operating in the rotating mode and operating in the sliding mode where multiple transitions can be made between these two modes.', 'As mentioned, drilling fluid can be utilized to drive a downhole mud motor and hence rotate a bit in a sliding mode while surface equipment can be utilized to rotate an entire drillstring in a rotating mode (e.g., a rotary table, a top drive, etc.), optionally in combination with drilling fluid being utilized to drive a downhole mud motor (e.g., a combined rotating mode).', 'Directional drilling operations can depend on various factors, including operational parameters that can be at least to some extent controllable.', 'For example, one or more factors such as mode transitions, lifting, WOB, RPM, torque, and drilling fluid flow rate can be controllable during a drilling operation.', 'FIG.', '8\n shows an example of a drilling assembly \n800\n in a geologic environment \n801\n that includes a borehole \n803\n where the drilling assembly \n800\n (e.g., a drillstring) includes a bit \n804\n and a motor section \n810\n where the motor section \n810\n includes a mud motor that can drive the bit \n804\n (e.g., cause the bit \n804\n to rotate and deepen the borehole \n803\n).', 'As shown, the motor section \n810\n includes a dump valve \n812\n, a power section \n814\n, a surface-adjustable bent housing \n816\n, a transmission assembly \n818\n, a bearing section \n820\n and a drive shaft \n822\n, which can be operatively coupled to a bit such as the bit \n804\n.', 'Flow of drilling fluid through the power section \n814\n can generate power that can rotate the drive shaft \n822\n, which can rotate the bit \n804\n.', 'As to the power section \n814\n, two examples are illustrated as a power section \n814\n-\n1\n and a power section \n814\n-\n2\n each of which includes a housing \n842\n, a rotor \n844\n and a stator \n846\n.', 'The rotor \n844\n and the stator \n846\n can be characterized by a ratio.', 'For example, the power section \n814\n-\n1\n can be a 5:6 ratio and the power section \n814\n-\n2\n can be a 1:2 ratio, which, as seen in cross-sectional views, can involve lobes (e.g., a rotor/stator lobe configuration).', 'The motor section \n810\n of \nFIG.', '8\n may be a POWERPAK family motor section (Schlumberger Limited, Houston, Tex.) or another type of motor section.', 'The POWERPAK family of motor sections can include ratios of 1:2, 2:3, 3:4, 4:5, 5:6 and 7:8 with corresponding lobe configurations.', 'A power section can convert hydraulic energy from drilling fluid into mechanical power to turn a bit.', 'For example, consider the reverse application of the Moineau pump principle.', 'During operation, drilling fluid can be pumped into a power section at a pressure that causes the rotor to rotate within the stator where the rotational force is transmitted through a transmission shaft and drive shaft to a bit.', 'A motor section may be manufactured in part of corrosion-resistant stainless steel where a thin layer of chrome plating may be present to reduce friction and abrasion.', 'As an example, tungsten carbide may be utilized to coat a rotor, for example, to reduce abrasion wear and corrosion damage.', 'As to a stator, it can be formed of a steel tube, which may be a housing (see, e.g., the housing \n842\n) with an elastomeric material that lines the bore of the steel tube to define a stator.', 'An elastomeric material may be referred to as a liner or, when assembled with the tube or housing, may be referred to as a stator.', 'As an example, an elastomeric material may be molded into the bore of a tube.', 'An elastomeric material can be formulated to resist abrasion and hydrocarbon induced deterioration.', 'Various types of elastomeric materials may be utilized in a power section and some may be proprietary.', 'Properties of an elastomeric material can be tailored for particular types of operations, which may consider factors such as temperature, speed, rotor type, type of drilling fluid, etc.', 'Rotors and stators can be characterized by helical profiles, for example, by spirals and/or lobes.', 'A rotor can have one less fewer spiral or lobe than a stator (see, e.g., the cross-sectional views in \nFIG. \n8\n).', 'During operation, the rotor and stator can form a continuous seal at their contact points along a straight line, which produces a number of independent cavities.', 'As fluid is forced through these progressive cavities, it causes the rotor to rotate inside the stator.', 'The movement of the rotor inside the stator is referred to as nutation.', 'For each nutation cycle, the rotor rotates by a distance of one lobe width.', 'The rotor nutates each lobe in the stator to complete one revolution of the bit box.', 'For example, a motor section with a 7:8 rotor/stator lobe configuration and a speed of 100 RPM at the bit box will have a nutation speed of 700 cycles per minute.', 'Generally, torque output increases with the number of lobes, which corresponds to a slower speed.', 'Torque also depends on the number of stages where a stage is a complete spiral of a stator helix.', 'Power is defined as speed times torque; however, a greater number of lobes in a motor does not necessarily mean that the motor produces more power.', 'Motors with more lobes tend to be less efficient because the seal area between the rotor and the stator increases with the number of lobes.', 'The difference between the size of a rotor mean diameter (e.g., valley to lobe peak measurement) and the stator minor diameter (lobe peak to lobe peak) is defined as the rotor/stator interference fit.', 'Various motors are assembled with a rotor sized to be larger than a stator internal bore under planned downhole conditions, which can produce a strong positive interference seal that is referred to as a positive fit.', 'Where higher downhole temperatures are expected, a positive fit can be reduced during motor assembly to allow for swelling of an elastomeric material that forms the stator (e.g., stator liner).', 'Mud weight and vertical depth can be considered as they can influence the hydrostatic pressure on the stator liner.', 'A computational framework such as, for example, the POWERFIT framework (Schlumberger Limited, Houston, Tex.), may be utilized to calculate a desired interference fit.', 'As to some examples of elastomeric materials, consider nitrile rubber, which tends to be rated to approximately 138 C (280 F), and highly saturated nitrile, which may be formulated to resist chemical attack and be rated to approximately 177 C (350 F).', 'The spiral stage length of a stator is defined as the axial length for one lobe in the stator to rotate 360 degrees along its helical path around the body of the stator.', 'The stage length of a rotor differs from that of a stator as a rotor has a shorter stage length than its corresponding stator.', 'More stages can increase the number of fluid cavities in a power section, which can result in a greater total pressure drop.', 'Under the same differential pressure conditions, the power section with more stages tends to maintain speed better as there tends to be less pressure drop per stage and hence less leakage.', 'Drilling fluid temperature, which may be referred to as mud temperature or mud fluid temperature, can be a factor in determining an amount of interference in assembling a stator and a rotor of a power section.', 'As to interference, greater interference can result in a stator experiencing higher shearing stresses, which can cause fatigue damage.', 'Fatigue can lead to premature chunking failure of a stator liner.', 'As an example, chlorides or other such halides may cause damage to a power section.', 'For example, such halides may damage a rotor through corrosion where a rough edged rotor can cut into a stator liner (e.g., cutting the top off an elastomeric liner).', 'Such cuts can reduce effectiveness of a rotor/stator seal and may cause a motor to stall (e.g., chunking the stator) at a low differential pressure.', 'For oil-based mud (OBM) with supersaturated water phases and for salt muds, a coated rotor can be beneficial.', 'As to differential pressure, as mentioned, it is defined as the difference between the on-bottom and off-bottom drilling pressure, which is generated by the rotor/stator section (power section) of a motor.', 'As mentioned, for a larger pressure difference, there tends to be higher torque output and lower shaft speed.', 'A motor that is run with differential pressures greater than recommended can be more prone to premature chunking.', 'Such chunking may follow a spiral path or be uniform through the stator liner.', 'A life of a power section can depend on factors that can lead to chunking (e.g., damage to a stator), which may depend on characteristics of a rotor (e.g., surface characteristics, etc.).', 'As to trajectory of a wellbore to be drilled, it can be defined in part by one or more dogleg seventies (DLSs).', 'Rotating a motor in high DLS interval of a well can increase risk of damage to a stator.', 'For example, the geometry of a wellbore can cause a motor section to bend and flex.', 'A power section stator can be relatively more flexible that other parts of a motor.', 'Where the stator housing bends, the elastomeric liner can be biased or pushed upon by the housing, which can result in force being applied by the elastomeric liner to the rotor.', 'Such force can lead to excessive compression on the stator lobes and cause chunking.', 'A motor can have a power curve.', 'A test can be performed using a dynamo meter in a laboratory, for example, using water at room temperature to determine a relationship between input, which is flow rate and differential pressure, to power output, in the form of RPM and torque.', 'Such information can be available in a motor handbook.', 'However, what is actually happening downhole can differ due to various factors.', 'For example, due to effect of downhole pressure and temperature, output can be reduced (e.g., the motor power output).', 'Such a reduction may lead one to conclude that a motor is not performing.', 'In response, a driller may keep pushing such that the pressure becomes too high, which can damage elastomeric material due to stalling (e.g., damage a stator).', 'FIG.', '9\n shows an example of a graphical user interface \n900\n that includes a graphic of a system \n910\n and a graphic of a trajectory \n930\n where the system \n910\n can perform directional drilling to drill a borehole according to the trajectory \n930\n.', 'As shown, the trajectory \n930\n includes a substantially vertical section, a dogleg and a substantially lateral section (e.g., a substantially horizontal section).', 'As an example, the dogleg can be defined between a kickoff point (K) and a landing point (L), which are shown approximately as points along the trajectory \n930\n.', 'The system \n910\n can be operated in various operational modes, which can include, for example, rotary drilling and sliding.', 'In the example of \nFIG.', '9\n, longitudinal drag along the drillstring can be reduced from the surface down to a maximum rocking depth, at which friction and imposed torque are in balance.', 'As an example, a drilling operation can include manipulating surface torque oscillations such that the maximum rock depth may be moved deep enough to produce a substantial reduction in drag.', 'As an example, reactive torque from a bit can create vibrations that propagate back uphole, breaking friction and longitudinal drag across a bottom section of a drillstring up to a point of interference, where the torque is balanced by static friction.', 'As shown in the example of \nFIG.', '9\n, an intermediate zone may remain relatively unaffected by surface rocking torque or by reactive torque.', 'In the example of \nFIG.', '9\n, a drilling operation can include monitoring torque, WOB and ROP while sliding.', 'As an example, such a drilling operation may aim to minimize length of the intermediate zone and thus reduce longitudinal drag.', 'A drilling operation in the sliding mode that involves manual adjustments to change and/or maintain a toolface orientation can be challenging.', 'As an example, a drilling operation in the sliding mode can depend on an ability to transfer weight to a bit without stalling a mud motor and an ability to reduce longitudinal drag sufficiently to achieve and maintain a desired toolface angle.', 'As an example, a drilling operation in the sliding mode can aim to achieve an acceptable ROP while taking into account one or more of various other factors (e.g., equipment capabilities, equipment condition, tripping, etc.).', 'In a drilling operation, as an example, amount of surface torque (e.g., STOR) supplied by a top drive can largely dictate how far downhole rocking motion can be transmitted.', 'As an example, a relationship between torque and rocking depth can be modeled using a torque and drag framework (e.g., T&D framework).', 'As an example, a system may include one or more T&D features.', 'As an example, a system may utilize inputs from surface hook load and standpipe pressure as well as downhole MWD toolface angle.', 'In such an example, the system may automatically determine the amount of surface torque that is appropriate to transfer weight downhole to a bit, which may allow an operation to not come off-bottom to make a toolface adjustment, which can results in a more efficient drilling operation and reduced wear on downhole equipment.', 'Such a system may be referred to as an automation assisted system.', 'FIG.', '10\n shows an example of a graphical user interface \n1000\n that includes various tracks for different types of operations, which include rotating, manual sliding, and automation assisted sliding according to a provided amount of surface torque.', 'As shown in the GUI \n1000\n, comparisons can be made for rotating and sliding drilling parameters for the rotating mode and the sliding mode.', 'As shown, rate of penetration (ROP) and toolface orientation control can depend large on an ability of a system to transfer weight to the bit and counter the effects of torque and drag between rotating and sliding modes.', 'As shown, the best ROP is achieved while rotating; however, toolface varies drastically, as there is no attempt to control it (Track 3).', 'Hook load (Track 2) and weight on bit (WOB) remain fairly constant while differential pressure (Track 1) shows a slight increase as depth increases.', 'To begin manual sliding, a drilling operation can act to pull off-bottom to release trapped torque; during this time, WOB (Track 1) decreases while hook load (Track 2) increases.', 'As drilling proceeds, inconsistencies in differential pressure (e.g., difference between pressures when the bit is on-bottom versus off-bottom) indicate poor transfer of weight to the bit (Track 1).', 'Spikes of rotary torque indicate efforts to orient and maintain toolface orientation (Track 2).', 'As shown, toolface control may be poor because of trouble transferring weight to bit, which is also reflected by poor ROP (Track 3).', 'Using an automation assisted sliding mode system, a directional driller can more quickly gain toolface orientation.', 'When the WOB increased, differential pressure was consistent, demonstrating good weight transfer (Track 1).', 'In the example of \nFIG. \n10\n, weight on bit during a sliding operation is lower than during a manual sliding operation.', 'Left-right oscillation of the drillpipe is relatively constant through the slide (Track 2).', 'Average ROP is substantially higher than that attained during the manual slide, and toolface orientation is more consistent (Track 3).\n \nFIG.', '11\n shows an example of a graphical user interface \n1100\n that includes various types of information for construction of a well where times are rendered for corresponding actions.', 'In the example of \nFIG. \n11\n, the times are shown as an estimated time (ET) in hours and a total or cumulative time (TT), which is in days.', 'Another time may be a clean time, which can be for performing an action or actions without occurrence of non-productive time (NPT) while the estimated time (ET) can include NPT, which may be determined using one or more databases, probabilistic analysis, etc.', 'In the example of \nFIG. \n11\n, the total time (TT or cumulative time) may be a sum of the estimated time column.', 'As an example, during execution and/or replanning the GUI \n1100\n may be rendered and revised accordingly to reflect changes.', 'As shown in the example of \nFIG. \n11\n, the GUI \n1100\n can include selectable elements and/or highlightable elements.', 'As an example, an element may be highlighted responsive to a signal that indicates that an activity is currently being performed, is staged, is to be revised, etc.', 'For example, a color coding scheme may be utilized to convey information to a user via the GUI \n1100\n.', 'As an example, the GUI \n1100\n can be operatively coupled to one or more systems that can assist and/or control one or more drilling operations.', 'For example, consider the aforementioned automation assisted sliding mode system, which provides a desired toolface angle for a mud motor and a drilling distance for the sliding mode.', 'As another example, consider a system that generates rate of penetration values, which may be, for example, rate of penetration set points.', 'Such a system may be an automation assisted system and/or a control system.', 'For example, a system may render a GUI that displays one or more generated rate of penetration values and/or a system may issue one or more commands to one or more pieces of equipment to cause operation thereof at a generated rate of penetration.', 'In the example GUI \n1100\n, an entry \n1110\n corresponds to a drilling run, drill to depth operation, which specifies a distance (e.g., a total interval to be drilled) along with a time estimate.', 'In such an example, the drill to depth operation can be implemented using agent-based guidance that, for example, provides for a sequence of drilling parameters (e.g., mode, toolface angle, etc.).', 'As an example, a time estimate may be given for the drill to depth operation using manual, automated and/or semi-automated drilling.', 'For example, where a driller enters a sequence of modes, the time estimate may be based on that sequence; whereas, for an automated approach, a sequence can be generated (e.g., an estimated automated sequence, a recommended estimated sequence, etc.)', 'with a corresponding time estimate.', 'In such an approach, a driller may compare the sequences and select one or the other or, for example, generate a hybrid sequence (e.g., part manual and part automated, etc.).', 'FIG.', '12\n shows an example of a method \n1200\n that can output a predicted propagation direction of a drill bit based on forces and bit characteristics.', 'The method \n1200\n can utilize a computational framework that includes one or more features of a framework such as, for example, the IDEAS framework (Schlumberger Limited, Houston, Tex.).', 'The IDEAS framework utilizes the finite element method (FEM) to model various physical phenomena, which can include reaction force at a bit (e.g., using a static, physics-based model).', 'The FEM utilizes a grid or grids that discretize one or more physical domains.', 'Equations such as, for example, continuity equations, are utilized to represent physical phenomena.', 'The IDEAS framework, as with other types of FEM-based approaches, provides for numerical experimentation that approximates real-physical experimentation.', 'In various instances, a framework can be a simulator that performs simulations to generation simulation results that approximate results that have occurred, are occurring or may occur in the real-world.', 'In the context of drilling, such a framework can provide for execution of scenarios that can be part of a workflow or workflows as to planning, control, etc.', 'As to control, a scenario may be based on data acquired by one or more sensors during one or more well construction operations such as, for example, directional drilling.', 'In such an approach, determinations can be made using scenario result(s) that can directly and/or indirectly control one or more aspects of directional drilling.', 'For example, consider control of sliding and/or rotating as modes of performing directional drilling.', 'In \nFIG. \n12\n, the method \n1200\n commences in a force determination block \n1210\n for determining forces on a bit, which are utilized in a vector determination block \n1220\n for determining a vector as to how a drill bit of a BHA may be expected to move in a formation during drilling (e.g., according to one or more drilling modes).', 'In the block \n1230\n, a sufficiently small drilling distance (e.g., hole propagation length) is added to the bore along the direction of the vector determined by the drilling directional determination block \n1220\n.', 'The process can be repeated until the specified total drilling distance (e.g., pipe length, stand length, etc.) is completed.', 'As explained, a mud motor can be a directional drilling tool that can help to deliver a desired directional capability to land a borehole in a production zone.', 'As explained a directional motor can include various features such as, for example, a power unit, a bent sub, etc.', 'To drill a curved hole, the bend can be pointed to a desired orientation while rotation from the surface rig (e.g., table or top drive) may be stopped such that circulation of mud (e.g., drilling fluid)', 'acts to drive the mud motor to rotate the bit downhole.', 'As mentioned, in some instances, there can be a combination of surface rotation and downhole rotation.', 'In general, where surface rotation is not provided, the drillstring is in a sliding mode as it slides downward as drilling ahead occurs via rotation of the bit via operation of the mud motor.', 'Such an operation can be referred to as a sliding operation (e.g., sliding mode).', 'Another mode can be for holding the borehole direction tangent where surface equipment rotates the drillstring such that the motor bend also rotates with drillstring.', 'In such a mode, the BHA does not have a particular drill-ahead direction.', 'Such an operation can be referred to as a rotating operation (e.g., a rotating mode or rotary mode).', 'As an example, for a bent motor, a “rotating mode” (or rotary mode) can be for surface_RPM>0 and motor_RPM>0 (e.g., flow of drilling fluid driving a mud motor) and, a “sliding mode” can be for surface_RPM=0 and motor_RPM>0.', 'During a directional drilling planning phase, a well trajectory tends to be designed to ensure better reservoir exposure and less collision risk.', 'A given trajectory in a curved section can include one or more arcs with constant curvatures (DLS) and straight holding sections.', 'For a motor-based directional drilling plan, drilling can be improved if it is known a priori (e.g., or during drilling) when to use a particular mode (e.g., and when to switch modes).', 'Additionally, it is desirable to know if a particular BHA is able to deliver a desired DLS.', 'As explained, a method can include utilizing various types of data to determine what sliding and rotating sequence can be utilized to improve drilling efficiency for a particular BHA (or BHAs) to adhere to designed trajectory.', 'As to BHA capabilities, a method can include performing one or more sliding simulations with given motor BHA specifications to check if a corresponding motor sliding DLS capability is higher than that of a desired DLS.', 'Such a method may be performed prior to performing a method that can determine one or more sequences (e.g., mode sequences) for a BHA where such one or more sequences can help to improve an ability to create a desired or desirable borehole trajectory.', 'For a given motor BHA design, DLS capability adjustability is limited in the sliding operation.', 'To match motor DLS output with a designed trajectory, an operation sequence mixing sliding and rotating can be utilized.', 'However, switching between rotating and sliding tends to be undesirable as it can be time-consuming (e.g., non-productive time (NPT)).', 'For example, switching operational modes can involve stopping equipment of a rig and reorienting a motor bent toolface angle (TFA).', 'Further, switching can compromise borehole quality, for example, by introducing ledges.', 'Therefore, it can be quite helpful to plan a motor operation sequence in a manner whereby a desired or desirable DLS can be achieved, for example, with high drilling efficiency (e.g., limited or reduced NPT).', 'As explained, drilling a directional well in the oil and gas industry can help to ensure better reservoir exposure and less wellbore collision risk.', 'In various high-volume drilling markets, mud motors can be utilized for directional drilling.', 'As explained, a mud motor can be capable of delivering a desired well curvature via operations that can include switching between rotating and sliding modes (e.g., rotate mode and slide mode).', 'To follow a predefined well trajectory, drilling operations can aim to determine an optimal operation control sequence of a mud motor or mud motors.', 'In various examples, a method can include training an agent for motor directional drilling using deep reinforcement learning (DRL).', 'As an example, mud motor-based directional drilling (e.g., downhole motor-based directional drilling) can be framed into a reinforcement learning scheme with an automatic drilling system.', 'As an example, a trained machine model or trained machine learning model (trained ML model) can be referred to as an agent, which can be trained with respect to interactions with an environment (e.g., formations, wellbore geometry, equipment, etc.), for example, through choices of controls in a sequence.', 'As an example, an agent can receive information such that it can perceive states (e.g., inclination, MD, TVD at survey points and the planned trajectories, etc.).', 'The information can be from an environment where the agent can utilize the information to decide on a best action such as sliding or rotating.', 'In such an example, the decisions (or choices) made by an agent can be to achieve a maximum in total rewards, which can be appropriately defined to suit one or more drilling operations.', "As an example, a loop can exist where the environment is affected by the agent's actions and where a reward calculator (e.g., reward computational component or components) returns corresponding rewards to the agent.", 'As an example, a reward can be positive (such as drilling to target) or negative (such as offset distance to the planned trajectory, cost of drilling and action switching).', 'To train an agent, a drilling simulator can be utilized that simulates drilling in a multi-dimensional spatial environment such as, for example, a 2D and/or a 3D environment of a layered earth model with layer depths and BHA directional responses in layers.', 'As an example, various attributes of a drilling system may be constant and/or varied and handled by a simulator.', 'As an example, for training, a planned trajectory can be provided, which can be part of a goal-based approach where, for example, an end target may be a high priority goal.', 'As an example, a directional-drilling agent (DD agent) can be trained for hundreds or thousands or more episodes.', 'As an example, an agent can be trained to successfully drill to a target in a simulated environment through making of decisions as to sliding and rotating and/or, for example, toolface angle.', 'As an example, an agent can provide for a system that can implement an automated directional drilling method based on deep reinforcement learning, which makes a sequence of decisions of rotating and sliding actions to follow a planned trajectory.', 'As explained, a driller can drill a straight hole in a “rotary” mode, while building a curve in a “sliding” mode.', 'To automate the decisions of “rotary” or “sliding” (e.g., and optionally toolface), a reinforcement learning approach can be utilized.', 'FIG.', '13\n shows an example of a system \n1300\n that includes an agent \n1310\n and an environment \n1350\n where the agent \n1310\n interacts with the environment \n1350\n though action (A), state (S), and reward (R).', 'For example, the agent \n1310\n can observe a state from the environment \n1350\n, and make a decision as to one or more actions.', 'An action (or actions) can then be applied to the environment \n1350\n, and the environment \n1350\n can yield a reward as a feedback to the agent \n1310\n, together with a new state which the agent \n1310\n observes in a subsequent round (e.g., a next round).', 'The goal of the agent \n1310\n can be to take actions that maximize the total future rewards.', 'In the drilling decision making, the motor-based directional drilling agent can interact with the environment (e.g., formations, wellbore geometry, and equipment), through choices of controls in a sequence, which may include mode controls, toolface controls and/or other controls.', 'For example, in a 3D environment, toolface angle may be considered and modeled such that an agent can learn to control toolface angle (e.g., output actions as instructions as to toolface angle changes).', 'As another example, consider decisions as to surveys such as checkpoint surveys or check shot surveys.', 'Such surveys can involve time as a factor, which may be a negative in terms of reward (e.g., greater time being more negative); however, a survey can provide an indication of location of a portion of a drillstring, which can help to assess whether or not, and to what degree, a drilled borehole may be complying with a planned trajectory.', 'As an example, an agent can be trained using rewards where an action can have an associated reward scheme.', 'As mentioned, an action can have positive aspects and/or negative aspects with respect to one or more goals.', 'As an example, an agent can be trained and/or implemented using one or more safety constrains.', 'For example, a safety constraint can be utilized to help assure that an optimal sequence of control instructions abides by one or more safety constraints and/or does not get implemented without assessment with respect to one or more safety constraints.', 'As mentioned, a directional drilling agent can be trained in a simulated environment.', 'For example, consider a multi-dimensional earth model with building rates of formation and thickness attributes.', 'In such an example, the agent perceives the states (e.g., inclination, MD, TVD at survey points and the planned trajectories) from the environment, and then decides the best action of sliding or rotating to achieve the maximum total rewards.', "The environment can be affected by the agent's actions and returns corresponding rewards to the agent through, for example, a hole propagation model, a reward calculator and a definition of completed.", 'As to a hole propagation model, which can implement at least some basic drilling mechanisms, it can be a part of the environment component (see, e.g., the environment \n1350\n).', 'For example, a simulator can take each of the commands of “sliding up”, “sliding down”, and “rotation” from an agent, and proceed with a corresponding simulation using a hole propagation model.', 'In such an example, at each interval, a build rate can be sampled from a rock model.', 'In addition, to train with uncertainty, noise such as a Gaussian noise of approximately 10 percent standard deviation of the build rate may be added in each interval.', 'As to a reward calculator, it can receive a state from a simulator, and calculate the rewards to feedback to an agent.', 'In such an example, the reward calculator evaluates the reward based on one or more considerations such as, for example, accuracy and operation efficiency.', 'For accuracy, it can take a planned survey as an input, and compare it with actual drilled locations, and return a scalar based on a deviation to the plan.', 'Rewards can be positive (e.g., such as drilling to target) or negative (e.g., such as offset distance to the planned trajectory, cost of drilling and action switching).', 'As to a definition of “completed” (e.g., done), the completion of drilling can be, for example, “failed” or “successful”.', 'A successful one can be defined as reaching a drilling target within a tolerance of inclination and a bounding box (e.g., a predefined bounding box), otherwise, it can be defined as a failed one.\n \nFIG.', '14\n shows an example of a method \n1400\n that involves a Q function approach for reinforcement learning using a deep neural network.', 'An article by Mnih et al., Human-level control through deep reinforcement learning, Nature, Vol. 518: pp.', '529-533, is incorporated by reference herein.', 'In the example of \nFIG.', '14\n, an example of a Q-learning diagram \n1410\n is shown along with an example of a graph of trials \n1430\n and an example of a graph with trial results \n1450\n.', 'As an example, a method can include deep Q-learning using a deep Q-learning network (DQN).', 'As to some other types of examples, consider a deep deterministic policy gradient (DDPG) network or a proximal policy optimization (FPO).', 'As an example, an agent can be trained using reinforcement learning through estimating a Q function using a deep neural network.', 'In such an example, the Q-value can be referred to as an action value, which can be defined as the expected long-term return with discount when taking a given action.', 'Given a policy π, state s, and action a, the Q value can be estimated as: \n \nQ\nπ\n(\ns,a\n)=\nE\n[\nr\nt+1\n+γr\nt+2\n+γ\n2\nr\nt+3\n+ . . .', '|s,a], \n \n where γ is the discount factor or the reward r, and t is the step count.', 'As an example, t can be an interval count, for example, consider an interval as to a distance such as a measured distance along an axis of a trajectory of a borehole, which can be a planned trajectory.', 'As to the Q-function, it is a prediction of future reward based on state and action pair.', 'To act optimally with policy π*, an action is chosen that yields the highest optimal Q-function (Q*) value among possible actions at the current step t. \n π*(\ns\n)=\na\nargmax\nQ*(\ns,a\n)', 'The Q* function can be expressed into a Bellman equation in a recurrent form, where s′ and a′ are the next state and next action: \n \nQ\n*(\ns,a\n)=\na\nE\n[r+γmax Q*(\ns′,a′\n)|\ns,a].', 'The Bellman equation can be solved iteratively, and Q* can then be estimated through a neural network.', 'As an example, a neural network for a 2D implementation can include five fully-connected layers with three outputs which map to the actions of “Sliding Up”, “Sliding Down”, and “Rotating”.', 'In such an example, the first two layers have 1024 neurons, the third and fourth layers have 512 neurons, and the last layer has 256 neurons.', 'To train the neural network, a loss function may be defined as the mean-square-error of the predicted Q* using the Bellman equation.', 'The loss can then minimized by stochastic gradient descent and back propagation.', 'Such an approach generates weights that define the agent and make the agent trained for receiving input and generating output.', 'In a trial example, training of a directional-drilling agent involved 8000 trials of drilling simulation, or episodes.', 'The drilling trajectories during the training and evaluation processes are shown in the graphs \n1430\n and \n1450\n.', 'In the graph \n1430\n, horizontal lines are the boundaries of formations in the simulated environment and the lines are plans used in the training process, which are random plans with fixed length of 3000 ft in total.', 'As to the graph \n1450\n, it shows decision results generated by the agent as evaluated with input for a random drilling plan.', 'In each interval, a small amount of random noise is added to the formation build rate value and the agent is trained to handle such an uncertainty and make appropriate decisions.', 'As in the graph \n1430\n, the horizontal lines are formation layers while thinner lines represent rotating operation and thicker lines represent sliding operation.', 'As demonstrated, the agent succeeded drilling to the target by suitable adherence to the plan in the simulated environment.', 'As an example, a noise approach can be implemented that utilizes a noisy layer.', 'In such an example, noise can be parameter noise, which may allow for expedited training compared to approaches without parameter noise (e.g., consider comparing parameter noise to action noise).', 'Parameter noise can add adaptive noise to parameters of a neural network policy, rather than to its action space.', 'Action space noise acts to change the likelihoods associated with each action an agent might take from one moment to the next.', 'Parameter space noise injects randomness directly into parameters of an agent, altering the types of decisions it makes such that they depend on what the agent currently senses.', 'As an example, training can utilize deep reinforcement learning (DRL) and parameter noise.', 'As an example, noise may be introduced via simulation such as via a hole propagation model simulator.', 'As an example, the type of noise applied to a neural network (e.g., parameter noise) can differ from the type of noise applied to a simulator.', 'For example, parameter space noise can be applied via a noisy layer that can provide for improved exploration of a DRL agent while domain randomization can be a noise that is applied to a simulator that can provide for a more robust agent and that can facilitate transfer from a simulated environment to a real-world environment.', 'As explained, parameter noise can help algorithms explore their environments more effectively, leading to higher scores and more elegant behaviors.', "Such an approach can be viewed as adding noise in a deliberate manner to the parameters of a policy, which can make an agent's exploration more consistent across different timesteps; whereas, adding noise to the action space (e.g., epsilon-greedy exploration) tends to lead to more unpredictable exploration which may not be correlated to an agent's parameters.", 'As demonstrated in \nFIG.', '14\n, a multi-dimensional automated directional drilling decision agent can provide for making, through deep reinforcement learning (DRL), a sequence of decisions of rotating and sliding actions to follow a planned trajectory, and drill to target.', 'As to a 3D environment with a 3D agent, graphs such as the graphs \n1430\n and \n1450\n can be represented in three spatial dimensions (see, e.g., \nFIG.', '19\n, \nFIG.', '20\n, etc.).', 'FIG.', '15\n shows various examples of approaches for handling simulation and reality.', 'For example, in an approach \n1510\n, a calibrated simulation aims to provide for system identification as to reality; in an approach \n1530\n, domain adaptation is utilized to bridge a calibrated simulation with reality; and, in an approach \n1550\n, a distribution of domain-randomized sums is utilized to encapsulate at least a portion of reality.', 'As an example, domain randomization can be utilized for enhanced simulation.', 'Such an approach can help to assure that a trained model does better in the real-world.', 'For example, a model trained on simulation without some type of probabilistic variations (e.g., randomizations or “noise”) may perform well in a “world” that behaves like the simulation but is likely to be suboptimal as to the types of variations that can and do occur in the real-world.', 'As to types of randomizations, these can be dependent on the types of tasks.', 'For example, for a robot that utilizes machine vision, appearance, scene/object and/or physics randomization may be utilized.', 'As to appearance, aspects such as color, lighting, reflectivity, etc., may be utilized.', 'As to scene/object, aspects such as real and unreal objects may be utilized where training on unreal objects may enhance training as to real objects.', 'As to physics, aspects such as dimensions, masses, friction, damping, actuator gains, joint limits and gravity may be utilized.', 'As an example, randomization may be for mass and dimensions of objects, mass and dimensions of robot bodies, damping, friction of the joints, gains for a PID controller (e.g., P term), joint limit, action delay, observation noise, etc.', 'As an example, domain randomization can be implemented in a hole propagation model for simulating hole propagation.', 'Such an approach can act to introduce some amount of noise to a system.', 'As an example, another type of noise can be parameter noise, which may be introduced via a noisy layer.', 'As an example, a system may utilize one or more types of noises (e.g., via domain randomization, via a noisy layer, etc.).', 'As an example, safety can be a desirable aspect of reinforcement learning when a physical system operates in the real-world, particularly where equipment, humans, formations, the environment, etc., may be damaged.', 'Various techniques may be utilized for purposes of safety.', 'For example, consider a system that integrates temporal logic guided reinforcement learning (RL) with control barrier functions (CBFs) and control Lyapunov functions.', 'Such an approach can be beneficial in sim-to-real transfer whereby real-world control via a trained agent occurs with some assurances as to safety concerns.', 'As shown in \nFIG.', '16\n, a local control system can be configured to verify instructions against its own set of constraints.', 'In particular, \nFIG. \n16\n shows an example of a simulation environment that includes an agent with known dynamics, safety constraints in the form of two straight lines forming a channel that the agent has to stay within, three circular goal regions whose positions are kept fixed in an episode but can be randomized between episodes, and two obstacles that move in the vicinity of the channel and whose dynamics are unknown.', 'In the example of \nFIG. \n16\n, for a reinforcement learning (RL) component, a learning algorithm can employ proximal policy optimization.', 'For example, a policy can be represented by a feed-forward neural network (NN).', 'As an example, consider a feed-forward NN with 3 hidden layers of 300, 200, 100 ReLU units, respectively.', 'In such an approach, the value function can be of the same architecture type.', 'As to episodes, consider each episode having a horizon T=200 steps and positions of goal regions being randomized between episodes (e.g., goals may initiate outside the safe channel).', 'In such an approach, a process can collect a batch of 5 trajectories for each update iteration.', 'And, during learning, an episode can terminate when the horizon is reached or the task is completed.', 'As an example, depending on CBFs being enabled or not, an agent may (not enabled) or may not (enabled) be allowed to travel outside the safety channel (e.g., safety constraints) and collide with a moving obstacle(s) during learning (e.g., to receive a penalty).', 'As an example, a minimum distance between an agent and one or more moving obstacles as a function of policy updates can be tracked to show that, as learning progresses, the agent learns to stay away from the moving obstacles.', 'As to actual task oriented behaviors, the agent A in \nFIG.', '16\n may start close to and try to move towards G\n2\n; however, via learning, the agent A can know that if it keeps trying to get to G\n2\n it will get stuck at the border (safety constraint) and receive a low return.', 'Therefore, near the border (safety constraint) the agent A chooses to instead move towards G\n1\n and eventually finish the task.', 'Depending on training, a RL agent may choose an obstacle free path and try to make a tradeoff between accomplishing the task, avoiding obstacles and minimizing safety violations (e.g., as may be controlled by weights, etc.).', 'As an example, during an evaluation phase, during evaluation an episode can terminate in a number of circumstances such as, for example, a horizon is reached, a task is accomplished and an RL agent collides with a moving obstacle (e.g., defined by a minimum threshold on relative distance, etc.).', 'As explained, to ensure safety, one or more control barrier functions (CBFs) can be enabled (e.g., turned on).', 'As an example, RL agents trained with CBFs can exhibit higher success rates as, for example, RL agents trained without CBF sometimes rely on traveling outside a safe zone (e.g., safety constraints) to avoid obstacles and get to goals.', 'As an example, an agent may be trained using reinforcement learning with one or more control barrier functions (CBFs).', 'FIG.', '17\n shows an example of a system \n1700\n that can be utilized for training an agent such as a deep reinforcement learning agent (DRL agent) \n1710\n using an environment \n1730\n that includes a simulator \n1750\n and a reward calculator \n1770\n.', 'As an example, a trained agent can provide for automated directional drilling in a geologic environment (see, e.g., \nFIG.', '27\n, \nFIG.', '28\n, etc.).', 'As shown in \nFIG. \n17\n, the agent \n1710\n issues an action to the simulator \n1750\n in the environment \n1730\n where the simulator \n1750\n provides information to the reward calculator \n1770\n that can generate a reward that is transmitted to the agent \n1710\n (e.g., to impact operation of the agent \n1710\n).', 'As shown, the simulator \n1750\n can provide an observation to the agent \n1710\n, which can provide for assessment of an inferred state.', 'For example, the simulator \n1750\n can generate a simulated state while the agent \n1710\n, which is outside of the environment \n1730\n, can perceive an inferred state.\n \nFIG.', '17\n also shows an example of a loop where a domain expert \n1790\n may be utilized that can make one or more adjustments to and/or one or more definitions for operation of the reward calculator \n1770\n.', 'For example, feedback from the environment \n1730\n can cause the agent \n1710\n to issue an action, which can be observed (e.g., assessed, analyzed, etc.)', 'by the domain expert \n1790\n where, based at least in part on such observation, the reward calculator \n1770\n may be adjusted, further defined, etc.', 'As shown, the reward calculator \n1770\n can be applied to the environment \n1730\n, as shown in the system \n1700\n.', 'In such an approach, the agent \n1710\n can be further trained, honed, etc., using domain expertise (e.g., a domain expert and/or other domain expertise).', 'As an example, domain expertise may be from one or more wells that have been drilled using an agent or not using an agent.', 'As to an example of an earth model that can be utilized for purposes of simulation, consider the following example specified according to various parameters in Table 1, below.\n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \n \n \nExample Earth Model\n \n \n \n \n \n \n \n \n \n \n \n \n \nForma-\n \n \nDog Leg\n \n \n \n \n \n \ntion\n \nThick-\n \nSeverity\n \nNatural\n \n \nToolface\n \n \n \nLayer\n \nness\n \n(DLS)\n \nBuild Rate\n \nWalk Rate\n \nOffset\n \n \n \nIndex\n \n(ft)\n \ndeg/100 ft\n \n(deg/100 ft)\n \n(deg/100 ft)\n \n(TFO, deg)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n1\n \n600\n \n8\n \n−1.2\n \n0.8\n \n5\n \n \n \n2\n \n1200\n \n12\n \n−0.8\n \n0.3\n \n15\n \n \n \n3\n \n950\n \n10.5\n \n−2.1\n \n0.5\n \n23\n \n \n \n4\n \n2000\n \n8.2\n \n−1.2\n \n0.6\n \n14\n \n \n \n5\n \n1000\n \n10.1\n \n−3.1\n \n0.2\n \n16\n \n \n \n \n \n \n \n \n \n \nAs mentioned, a system can utilize a reward calculator such as the reward calculator \n1770\n, which can determine rewards as may be defined with respect to various factors.', 'For example, consider factors such as taking planned survey points, taking actual drilled point locations from a simulator, evaluating done or not done, accuracy to plan, operational efficiency, goal achievement, etc.', 'As an example, a reward can be based on one or more operational parameter such as, for example, sliding ration and survey interval (e.g., reward=(1−|sliding ratio|)*survey_intervar*k, where k is a predefine parameter such as 0.5).', 'As explained, actions can be for sliding (e.g., sliding mode) or rotating (e.g., rotary mode).', 'As to sliding, sliding can include sliding up or sliding down.', 'As explained, one or more actions may be taken as to toolface such as setting a toolface angle.', 'As an example, an agent can be trained through use of a drilling simulator that operates in a simulated multi-dimensional geologic environment as may be defined via an earth model (e.g., a 2D earth model, a 3D earth model, etc.).', 'Such an earth model can be a layered earth model with layer depths and BHA directional responses in layers.', 'An agent can be trained with respect to a trajectory, which may be a planned trajectory.', 'Training may utilize one or more of known plans, random plans, etc.', 'As to actions output by an agent, consider an approach that provides for actions with respect to stands, which can include, for example, one or more of the following, which are listed with stand numbering:\n \nStand #1-2, HD: 0.0-180.0, ROTATING\n \nStand #3-90 ft, HD:180.0-270.0, SET TOOLFACE:−150 deg, Sliding Ratio (slide->rotate):1.0\n \nStand #4-90 ft, HD:270.0-360.0, SET TOOLFACE:−150 deg, Sliding Ratio (slide->rotate):1.0\n \nStand #5-90 ft, HD:360.0-451.0, ROTATING\n \n* * *\n \nStand #20-90 ft, HD:1716.0-1806.0, SET TOOLFACE:−15 deg, Sliding Ratio (slide->rotate):1.0\n \nStand #21-90 ft, HD:1806.0-1896.0, SET TOOLFACE:−135 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #22-90 ft, HD:1896.0-1986.0, SET TOOLFACE:75 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #23-90 ft, HD:1986.0-2076.0, SET TOOLFACE:15 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #24-90 ft, HD:2076.0-2166.0, SET TOOLFACE:15 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #25-90 ft, HD:2166.0-2256.0, SET TOOLFACE:15 deg, Sliding Ratio (slide->rotate):0.2\n \n*', '* *\n \nStand #30-90 ft, HD:2616.0-2706.0, SET TOOLFACE:75 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #31-90 ft, HD:2706.0-2796.0, SET TOOLFACE:15 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #32-90 ft, HD:2796.0-2886.0, SET TOOLFACE:−135 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #33-90 ft, HD:2886.0-2976.0, SET TOOLFACE:0 deg, Sliding Ratio (slide->rotate):0.8\n \nStand #34-90 ft, HD:2976.0-3066.0, SET TOOLFACE:180 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #35-90 ft, HD:3066.0-3156.0, SET TOOLFACE:−135 deg, Sliding Ratio (slide->rotate):0.2\n \n*', '* *\n \nStand #48-90 ft, HD:4236.0-4327.0, ROTATING\n \nStand #49-90 ft, HD:4327.0-4418.0, ROTATING\n \nStand #50-90 ft, HD:4418.0-4508.0, SET TOOLFACE:−135 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #51-90 ft, HD:4508.0-4598.0, SET TOOLFACE:0 deg, Sliding Ratio (slide->rotate):0.8\n \nStand #52-90 ft, HD:4598.0-4688.0, SET TOOLFACE:−135 deg, Sliding Ratio (slide->rotate):0.2\n \n*', '* *\n \nStand #70-30 ft, HD:6222.0-6252.0, SET TOOLFACE:75 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #71-30 ft, HD:6252.0-6282.0, SET TOOLFACE:75 deg, Sliding Ratio (slide->rotate):0.2\n \nStand #72-30 ft, HD:6282.0-6300.0, SET TOOLFACE:75 deg, Sliding Ratio (slide->rotate):0.2\n \nHD:6300.0, SET TOOLFACE:75 deg, Sliding Ratio (slide->rotate):0.2\n \nTarget Location: X:3282.56, Y:0.00, Z:4989.28\n \nDone.', 'Success!, Reward: 18045.251893914232\n \nIn the foregoing examples, drilling is completed upon reaching the target location (e.g., X:3282.56, Y:0.00, Z:4989.28) where the agent that provides the actions has operated in a manner that maximizes total rewards (e.g., Reward: 18045.251893914232).', 'FIG.', '18\n shows an example of a system \n1800\n for training an agent \n1810\n (see, e.g., the agent \n1710\n) in a simulated environment \n1830\n such as the environment \n1730\n of \nFIG.', '17\n.', 'As shown, the simulated environment \n1830\n is multidimensional and includes a lateral dimension as offset and a depth dimension as depth.', 'The simulated environment \n1830\n shows a trajectory where drilling can be via rotation (e.g., rotate or rotary) or via sliding (e.g., slide).', 'In the example of \nFIG.', '18\n, the agent \n1810\n can issue one or more control instructions that can instruction drilling equipment to operation in a particular mode, which can include a rotate mode and a slide mode (e.g., slide up or slide down).', 'In the example, above the kickoff point, the agent \n1810\n issues an instruction to drill in a rotate mode while at a position below the kickoff point and prior to the landing point, the agent \n1810\n issues an instruction to drill in a slide mode.', 'As an example, where two modes exist, an instruction can be to transition from one mode to the other (e.g., consider a binary state transition as from 0 to 1 or 1 to 0 where a rotate mode is 0 and a slide mode is 1 or vice versa).', 'As an example, where three modes exist, an instruction can be to transition from one mode to another one of the modes (e.g., consider an instruction such as −1, 0, +1 for slide down, rotary, and slide up).', 'In the example of \nFIG.', '18\n, the agent \n1810\n can be trained using information as to a formation (e.g., various types of materials, lithologies, etc.), a planned trajectory (e.g., or trajectories for multi-lateral wells, etc.), one or more actions (e.g., modes of drilling, etc.), a physical model of drilling (e.g., a drilling simulator, etc.), and one or more types of rewards.\n \nFIG.', '19\n shows an example of a system \n1900\n for training an agent \n1910\n (see, e.g., the agent \n1710\n) in a simulated environment \n1930\n such as the environment \n1730\n of \nFIG.', '17\n.', 'As shown, the environment \n1930\n can be three-dimensional with dimensions such as total vertical depth (e.g., Z), offset in an E-W direction (e.g., X) and offset in an S-N direction (e.g., Y).', 'In the environment \n1930\n, various surfaces are illustrate that may represent horizons and/or other structural features as may be discerned through various field operations (e.g., drilling, seismic surveys, etc.).', 'In the example of \nFIG. \n19\n, the agent \n1910\n can be trained to issue control instructions as to mode and toolface, which can account for more than two-dimensions in space.', 'For example, the agent \n1910\n can include three-dimensional capabilities to make one or more decisions (e.g., issue one or more control instructions, etc.)', 'as to one or more operational parameters that can be defined in a three-dimensional space.', 'For example, consider toolface (TF) as being defined in a three-dimensional space.', 'In the example of \nFIG. \n19\n, the agent \n1910\n is shown as issuing instructions for drilling operations that include rotate, slide and toolface instructions.', 'As shown, a thick line represents rotate mode, a dashed line represents slide mode and open circles represent toolface changes.', 'As shown, the agent \n1910\n can be trained to issue various types of instructions for performing drilling using drilling equipment that can include surface equipment and downhole equipment.\n \nFIG.', '20\n shows examples of graphical user interfaces \n2010\n, \n2030\n and \n2050\n as to evaluation of a three-dimensional agent to drill according to a planned trajectory.', 'In the GUIs \n2010\n, \n2030\n and \n2050\n, a dashed line represents the planned trajectory while solid lines represent evaluations of the agent, which show some amount of deviations with respect to the planned trajectory.', 'The GUIs \n2010\n, \n2030\n and \n2050\n can also present information as to controls.', 'For example, consider highlighting rotate, slide and/or toolface control instructions.', 'As to specific portions, a graphical control can be utilized to render a specific control instruction to a display.', 'For example, consider: Delta_TF_RIGHT_12: Delta clockwise 12 deg, no drill; Delta_TF_LEFT_12: Delta Anti-clockwise 12 deg, no drill; Set_TF (0, 90, 180, 270), etc.', 'As an example, a toolface control may call for continuous settings or, for example, a schedule over an interval.', 'As to some examples of three-dimensional control instructions, consider the following examples where Example A is without natural tendency and where Example B is with natural tendency.', 'Example A\n \nSet MTF 90, GTF0\n \nRotate 500 ft\n \nSlide 200 ft\n \nGTF_Right_12\n \nSlide 200 ft\n \nRotate 200 ft\n \nGTF_Right_12\n \nSlide 300 ft\n \nRotate 200 ft\n \nGTF_Left_12\n \nSlide 100 ft\n \nRotate 200 ft\n \nGTF_Left_12\n \nSlide 150 ft\n \nGTF_Left_12\n \nSlide 100 ft\n \nRotate 300 ft\n \nExample B\n \nSet TF 90\n \nRotate 500 ft\n \nSlide 200 ft\n \nTF_Right\n \nSlide 200 ft\n \nRotate 200 ft\n \nTF_Right\n \nSlide 300 ft\n \nRotate 200 ft\n \nTF_Left\n \nSlide 100 ft\n \nRotate 200 ft\n \nTF_Left\n \nSlide 150 ft\n \nTF_Left\n \nSlide 100 ft\n \nRotate 300 ft\n \nAs an example, an agent can be trained using information pertaining to one or more of azimuth, build rate, walk rate, toolface changes, noise, etc.', 'As an example, a model can be a multi-dimensional spatial model that is in two dimensions or three dimensions.', 'As an example, an agent can operate iteratively, for example, according to intervals, which may be distance along a borehole (e.g., measured distance intervals).', 'For example, consider a 1 ft interval (e.g., approximately a 30 cm interval) where an action compressor is utilized to interpret an action sequence of an interval to one or more actions that can be utilized by drilling equipment (e.g., directional drilling (DD) equipment).', 'As an example, a driller may receive the output of an action compressor where the output is in the form of one or more actions that the driller may take to perform one or more drilling operations.', 'As an example, a trained neural network (e.g., DD-Net) can be run in a simulator to generate a full sequence of a next interval and then pass that sequence to an action compressor (AC).', 'In such an example, the AC can generate a sequence of actions in a compressed version that can be passed to a directional driller (DD) to execute (e.g., automatically, semi-automatically and/or manually).', 'After execution of one or more of the actions (e.g., as appropriately selected, etc.), a new observation can be made and fed to the trained neural network (e.g., DD-Net, etc.).', 'As an example, consider the following approach to operation of an action compressor (AC: [sliding, rotating, changing TF, sliding, sliding, . . .', ']', 'to [Rotating 10 ft, change TF to 30 deg, sliding 20 ft, . . .', '].', 'In such an example, the actions output as a sequence (e.g., sliding, rotating, etc.) can be transformed into a sequence of understandable and distance coordinate actions, which may be suitable for a directional driller.', 'As an example, an action compressor (AC) may output actions that are in code or other types of commands that can be suitable for one or more computerized controllers to act upon (e.g., in an appropriate sequence, etc.).', 'As to a simulator, as mentioned, a hole propagation model may be utilized, which can be implemented in a multi-dimensional environment (e.g., 2D or 3D).', 'As an example, a simulator can be in the form of a computational framework executable using computational resources, which can be dedicated, distributed (e.g., cloud-based or other), non-distributed, etc.', 'As to drilling in a formation, various parameters can include depth, dogleg severity (DLS), build rate (e.g., natural tendency), walk rate (e.g., natural tendency), toolface offset (TFO), etc. (see, e.g., Table 1).', 'As to a reward or rewards, as mentioned, a system can include one or more reward calculators.', 'As an example, a reward can be an accuracy-based reward.', 'For example, consider a trajectory and/or a well plan and a reward or rewards that are based on how accurate drilling proceeds as informed by an agent according to the trajectory and/or the well plan.', 'For example, deviation from the trajectory and/or one or more other aspects of a well plan can result in no reward, a lesser reward, a penalty, etc.', 'As another example, consider one or more of a cost and/or efficiency based reward or rewards.', 'As to a goal achievement approach, consider a reward based on a target that can be a target of a trajectory, which may be a particular point or points in a reservoir of a formation.', 'As explained, upon reaching a target, an agent can accumulate a total number of rewards where the agent acts to maximize that number.', 'Below, an example of a reward scheme is presented for operational rewards.', 'Cost:\n \nSlide −3, Rotate: −0.3\n \nToolface settings: −50 (first), −100 (immediate next)\n \nTransition:\n \nRotate to Slide: −5\n \nSlide to Rotate: −1\n \nToolface changes to Rotate: −200\n \nToolface left/right to Toolface right/left: −200\n \nAs indicated, rewards can be for modes and/or transitions from one mode to another mode and/or for toolface settings and/or transitions in toolface settings.', 'Such rewards can be based on physical parameters germane to operation of equipment to drill.', 'For example, a particular mode can be more taxing on equipment than another mode and transitions from one mode to another mode may be taxing on equipment and pose some increased operational risks (e.g., to equipment, borehole, formation, humans, etc.).', 'As an example, rewards can be based on one or more measurements.', 'For example, consider the following reward scheme:\n \nTortuosity\n \nDistance to plan\n \nDistance reward (−):', 'At bit point\n \nCloser reward (−0.1): If the bit is getting away to plan\n \nDrilling reward (+)\n \nStaged \n \n \n \n1000-2000 ft, dist2plan<10: +7\n \n2000-2500 ft, dist2plan<20:', '+10\n \n2500-finish, dist2plan<30: +20 \n Final bonus: 10000', 'As an example, a method can include using a measurement reward weight scheduling such as, for example:\n \nreward=\n \nmeasure_reward*measure_reward_weight', '+op_reward*(1-measure_reward_weight)', '+drilling_reward\n \nAs an example, a reward scheme can include various parts such as, for example, a measure reward, an operation reward and a drilling reward.', 'As explained, various weights may be utilized to tailor a reward scheme.', 'In the forgoing example, a measure_reward_weight is utilized where the operation reward is weighted by the equation 1-measure_reward_weight and where the drilling reward is not explicitly weighted.', 'As explained with respect to \nFIG.', '17\n, a reward scheme can be adjustable such that an agent acts in a desirable manner as it aims to maximize total rewards for a series of actions to drill a borehole in an environment.\n \nFIG.', '21\n shows various examples of graphical user interfaces \n2110\n, \n2130\n and \n2150\n that can plot rewards as determined during training.', 'The GUI \n2110\n shows an accuracy reward, the GUI \n2130\n shows an operational reward and the GUI \n2150\n shows a total reward.', 'In the GUIs \n2110\n, \n2130\n and \n2150\n, various types of statistical analyses may be performed on reward data, for example, to understand how one or more definitions, adjustments, etc., may be refined.', 'For example, a portion of reward data can be selected and rendered to a display with respect to a plot such as the plot of the GUI \n2010\n, which can provide zoom functionality.', 'In such an approach, a trajectory can be viewed in combination with reward data as to how an agent is behaving.', 'As the plot of the GUI \n2010\n can include data corresponding to an environment, an analysis may determine that one or more environmental parameters may be giving rise to certain actions and corresponding rewards.', 'In such an example, a reward calculator may be adjusted, redefined, etc., to account for the behavior, for example, in a manner that may depend on lithology, dogleg severity, type of equipment, etc.', 'As an example, an agent (e.g., DRL agent, etc.) can issue an action according to an interval, which may be fixed.', 'In the example of \nFIG.', '18\n, various small open circles are shown with respect to the trajectory, which may be, for example, intervals, which may optionally be adjusted by a driller, a planner, etc.', 'As an example, one or more types of markers may be utilized (e.g., triggers) that can be for purposes of agent-based control of one or more aspects of drilling operations (e.g., agent action, survey action, tripping action, etc.).', 'As an example, an agent may be updated as to a state according to a length or distance.', 'For example, consider an update that corresponds to a length of pipe, which may be a single pipe or multiple pipes (e.g., a stand).', 'As an example, an update as to state can be on a 10 meter basis (e.g., 30 ft), a 30 meter basis (e.g., 90 ft), etc.', 'As an example, an agent can make an inference as to a state where the agent has been trained to learn and predict a current state.', 'As explained, such an inference can be based on data acquired at a rigsite where such data can be considered observable data.', 'Observable data or observables may be insufficient to characterize a state with specificity sufficient to make a decision as to an action to be recommended or taken.', 'As explained, a trained agent can through inference characterize a state such that the trained agent can make a decision as to an action to be recommended or taken.', 'As explained, a trained agent can aim to maximize rewards that accumulate over a series of action where each of the actions, when taken, affect an environment, which, in turn, can be characterized at least in part via observables (e.g., data acquired via one or more sensors, etc.).', 'As explained, directional drilling can be performed using an agent that can optimize a sequence of actions (e.g., sliding up, sliding down, rotating actions, etc.)', 'such that the directional drilling can desirably follow a plan trajectory.', 'In such an example, drilling may be via one or more of a steerable motor, via a rotary steerable system, or another directional drilling technique.\n \nFIG.', '22\n shows an example of a system \n2200\n that includes various graphical user interfaces (GUIs) \n2201\n, \n2202\n and \n2203\n.', 'As shown, the GUI \n2201\n can include a geographic map with various labeled regions such as basins, plays, and prospective plays.', 'In such an example, a graphic control can be utilized to select a region and, for example, a rig or rigsite in the region.', 'As shown, a graphical control is utilized to render another graphical control with information and menu items such as trajectory file, digital well plan, and other.', 'As an example, upon receipt of a command responsive to input (e.g., a mouse click, a hover, a touch, a stylus position, a voice command, etc.), the system \n2200\n can access a database that includes information as to various agents where such the system \n2200\n can select one or more agents, optionally ranking them, for use with a project such as, for example, a particular Marcellus rig at a rigsite in the Marcellus basin.', 'In such an example, the system \n2200\n can tailor the selection or selections using data about the rig, the play, drillstring equipment, etc.', 'In the example of \nFIG.', '22\n, the GUI \n2202\n shows various directional drilling (DD) agents along with some indicia as to capabilities such as, for example, rotate/slide modes, toolface, custom, etc.', 'Upon receipt of an instruction responsive to selection of one of the DD agents, the GUI \n2203\n may be rendered to a display, where various details about the selected DD agent can be seen.', 'For example, consider details about activity (e.g., where an instance of the agent may be currently in use), personal (e.g., how trained, when trained, trained for what conditions, etc.), experience (e.g., past use, whether simulated and/or real), expertise (e.g., types of equipment, types of formations, types of dogleg seventies, etc.), and professional (e.g., associated resources that may be available through one or more service providers, etc.).', 'As shown, such a system can facilitate decision making, planning, drilling, etc., in one or more regions.', 'After selection of an agent, or agents, equipment at a rigsite can be operatively coupled to computational resources for execution of the agent or agents.', 'In such an example, the agent or agents may generate control instructions suitable for automated, semi-automated and/or manual control of one or more drilling operations (e.g., consider a rotate instruction, a slide instruction, a toolface instruction, etc.).', 'As an example, consider the system \n470\n of \nFIG.', '4\n being operatively coupled to one or more agents for purposes of drilling a borehole at least in part according to a planned trajectory of a digital well plan.\n \nFIG.', '23\n shows an example of a method that includes a coordinate transformation with respect to an example of an environment \n2310\n and an example of a transformation \n2330\n of the environment \n2310\n where a planned trajectory is shown and another trajectory is shown that represents at least some amount of an actually drilled borehole.', 'As shown, there are some deviations from the planned trajectory where an actual drilled point can be compared to a planned point where the planned point may be an intersection point.', 'In the transformation \n2330\n, U, V coordinates are shown, where V represents an axial direction (e.g., axial direction of a bit) and where U is orthogonal to V; noting that the coordinates U and V may be represented as V and U, for example, where U is the axial direction (e.g., axial direction of a bit).', 'As to the environment \n2310\n, as mentioned, it can involve a layered earth model, which can specify build rate of formation p and thickness (ft).', 'As shown, the planned trajectory can be specified by points (e.g., multi-dimensional points such as x, y, z points).', 'An environment and/or a planned trajectory can be specified, for example, planned survey points, and inclination, MD, TVD at survey points.', 'As explained, motor-based directional drilling can be instituted via a reinforcement learning framework with an automatic drilling system (e.g., including an agent) that interacts with an environment (e.g., earth, well, equipment, etc.) through choices of controls in a sequence, etc.', 'The agent can perceive states (e.g., inclination, MD, TVD at survey points and the planned trajectories) from the environment, and then decides the best action, for example, to slide or to rotate to achieve the maximum total rewards.', "As explained, the environment is affected by the agent's actions, and returns corresponding rewards to the agent.", 'The rewards can be positive (such as drilling to target) or negative (such as off distance to the planned trajectory, cost of drilling and action switching).', 'As explained, there can be a reward definition or definitions.', 'A reward calculator may determine one or more reward values at each interval.', 'For example, at each measurement point, get the intersection point (e.g., project the actual drilling point onto the planed trajectory), and calculate the distance.', 'The reward value can be less negative with shorter distance.', 'At each interval, there can be a negative reward: sliding (e.g., −3); rotating (e.g., −1).', 'As an example, there can be a reward at occasional points (+/−): each rotating to sliding change, there is a negative reward (−3); each sliding up/down change, there is a negative reward (−3); each sliding to rotating change, there is a negative reward (−1).', 'As an example, there can be future reward(s): taking check shot, there is a negative reward (−10); some position reward when reaching at particular points (+10).', 'As an example, there can be a reward at end of drilling.', 'For example, consider a positive reward is given based on MD projected on intersect point drilled; for a successful “done”, a bonus is given; a reward for smoothness (e.g., borehole condition, etc.); at each measurement, a tortuosity based reward; a future reward as to ROP at each interval; etc.', 'As an example, a reward calculator may be utilized to implement one or more constraints.', 'For example, consider one or more of a minimum slide length, a maximum allowed deviation from a planned trajectory, a maximum DLS per survey interval, a maximum number of slides per length of pipe and/or stand, etc.', 'As mentioned, an agent may issue an action on a fixed interval (e.g., each step, pipe, stand, etc.).', 'As an example, an agent may be updated as to state information at a fixed length interval (e.g., 30 meters, etc.).', 'As an example, an agent can via inference learn and predict a current state.', 'As to an agent state definition, consider the following example that may be applied in a 2D representation of a geologic environment:\n \na. Inferred: \n \n \n \ni. MD of last measurement\n \nii.', 'Hole Bottom Position (TVD, NS)\n \niii.', 'Hole Bottom Inclination\n \n \n \n \n \nb.', 'From Observables: \n \n \n \ni. Hole depth: each step (e.g., interval)\n \nii.', 'Measured depth: at measurement point\n \niii.', 'Position at MD (TVD, NS): at measurement point\n \niv.', 'Inclination at MD: at measurement point\n \nv. Whether current step at measurement point\n \n \n \n \n \nc. Planned Trajectory Intersect Point at MD and at bottom: \n \n \n \ni. MD\n \nii.', 'Inclination\n \niii.', 'Position\n \niv.', 'Guiding points along the trajectory (x, y, incl.):', 'Several intervals ahead, such as 10, 100, 200, 300, 500, 1000, 1500 ft ahead\n \nv. History: \n \n1.', 'Inclinations (previous N measurements)\n \n2.', 'Actions taken\n \n \n \n \n \n \n \nd. Agent Coordinate Transformation \n \n \n \ni. Coordinate is transformed from original offset/TVD to U, V coordinates, which are relative to the agent location of the last measured point (LMP) (see, e.g., the plot \n2330\n of \nFIG. \n23\n).', 'As to transformed sensor state elements, consider the following approach with reference to the plot \n2330\n of \nFIG.', '23\n: \n \n \n \na. Inclination at last measure point (LMP)\n \nb. At_measure: a flag to show if current location is at LMP\n \nc. Distance of bit to LMP (HD-MD)\n \nd. Target location (x, y, inclination) converted to U, V coordinates\n \ne. Distance to target\n \nf.', 'Intercept point (relative to LMP) projected to U, V coordinates including inclination\n \ng. Guide points from plan projected to U, V coordinates including inclinations\n \nh. Previous actions (e.g., 4 shots×30 ft) in history\n \ni. Previous inclinations in U, V coordinates (e.g., 4×30) in history\n \n \n \n \n \nAs explained, actions can include one or more of sliding up, sliding down, rotating, toolface orientation, taking measurement (e.g., default measurement is updated each survey interval), etc.', 'As to a definition of “completed” (e.g., “done”), failed can be more than the maximum allowed deviation from the planned trajectory; can include defining a boundary plane (e.g., by the target point and tolerance) where if the drilling passes the plane, it is deemed to have failed; can involve more than a maximum allowed MD (e.g., twice of the planned trajectory MD); and/or can involve drilling to the target within a boundary box, where inclination is out of tolerance range.', 'As to a definition of success, consider reaching a drilling target within the tolerance of inclination, position (e.g., x, y, and z), etc.', 'As an example, training can involve preliminary training of an agent with various random environments and plans; saving the trained agent network parameters; from offset wells, deriving a target environment as a prior; lightly training with the specific target environment (e.g., formations in a selected basin and specific plans) from the saved network parameters with a modified reward profile; adjusting the target environment (e.g., as may be learnt from other models), and repeating the training using the adjusted target environment.', 'Referring again to \nFIG.', '23\n, in such an example, a planned trajectory intersection point at a measured depth and at bottom may be taken into account.', 'For example, consider an approach that defines current parameters as follows:\n \nMeasured depth (MD)\n \nInclination (from last measurement)\n \nAzimuth\n \nPosition: x, y, z (from last measurement)\n \nDistance to last measurement\n \nFlags of survey, toolface (TF) measurment\n \nInterception point location\n \nAs to future parameters, consider, for example, future guiding points along a trajectory (e.g., x, y, z, including azimuth):\n \nNear: from 4 ft to 100 ft each 4 ft\n \nFar: from 200 ft to 1500 ft each 100 ft\n \nAs to past parameters, consider, for example:\n \nInclinations of previous N measurements (e.g., size: 8) Last actions taken in previous N measurements (e.g., size: 8*30)', 'In the foregoing examples as to current, future and past, there can be a total of approximately 536 state dimensions.', 'Such dimensions can be part of a neural network architecture where a trained neural network can receive inputs and output an action from a group of actions as to one or more drilling operations.', 'As to another example, consider the following definitions for planned trajectory intersection point at MD and at bottom.', 'Current: MD; inclination (from last measurement); position: x, y (from last measurement); distance to last measurement.', 'Future: Guiding points along the trajectory (x, y, inclination):', 'Near: from 4 ft to 100 ft each 4 ft; and Far: from 200 ft to 1500 ft each 100', 'ft.\n \nPast: Inclinations of previous 8 measurements (size: 8); Last actions took in previous 8 measurements (size: 8*30).', 'Plan points: X, Y.', 'Such an approach provides for a total of 372 state dimensions.', 'As demonstrated, a number of state dimensions can depend on definitions as to various current, future and past aspects of an agent state.', 'As an example, a neural network architecture may be selected to include a number of channels where the number of channels can be determined at least in part via a number of dimensions such as state dimensions.', 'As an example, one or more types of transforms may facilitate handling of spatial dimensions in relationship to state dimensions.', 'As an example, a transform can make an agent more robust to various plans (e.g., random plans, dynamic plans, etc.), which can be in contrast to an approach that utilizes an original coordinate system of an entire fixed plan (e.g., a fixed plan in an x, y coordinate system, an x, y and z coordinate system, etc.).', 'For example, a transform can make the “view” of an agent relative where, for example, a last measured point (LMP) can be a “new” origin for an agent.', 'Training of an agent through use of a coordinate transform can help train the agent in a relative space such that the agent can handle changes to a plan.', "Such a relative space (e.g., transformed space) can be part of an agent's state (e.g., an agent state defined in a U and V or a U, V and W space).", 'Referring again to \nFIG.', '23\n, a coordinate transform can facilitate training of an agent and/or use of an agent (e.g., which may make the agent more robust to various plans, etc.).', 'As shown in \nFIG. \n23\n, coordinates can include U and V (e.g., a 2D agent) or, for example, U, V and W (e.g., 3D agent).', 'As an example, a last measured point (LMP) can provide via one or more sensors an inclination, which can be utilized for setting a direction of an axial axis, which can be a tangent line of a curved portion of a borehole.\n \nFIG.', "24\n shows various examples of coordinate system in space, which include a right hand Cartesian coordinate system \n2402\n with x, y, and z; a left hand Cartesian coordinate system \n2404\n with x, y, and z; a hybrid cylindrical and Cartesian coordinate system \n2406\n with X (North), Y (East), and Z (Depth) along with inclination θ (theta), azimuth α (alpha) and toolface angle γ (gamma), and coordinate systems \n2408\n of a computational framework with X (North and “i”), Y (East and “j”), and Z (Earth's core and “k”) and x\na \n(tangent to well axis), y\na \n(to right side and looking downwardly) and z\na \n(lower side).", 'Inclination can be expressed in degrees, defined as a deviation from vertical, which can be irrespective of compass direction.', 'Inclination may be measured using one or more types of sensors.', 'For example, consider one or more of a pendulum mechanism, an accelerometer, a gyroscope, etc.', 'As to azimuth, it can be expressed in degrees, defined as a compass direction of a directional survey or of a wellbore as planned or measured by a directional survey.', 'As an example, azimuth can be specified in degrees with respect to the geographic or magnetic north pole.', 'As to toolface, it can be an angle measured in a plane perpendicular to a drillstring axis that is between a reference direction on the drillstring and a fixed reference.', 'For near-vertical wells, as an example, North can be a fixed reference and the angle can be a magnetic toolface.', 'For more-deviated wells (e.g., directionally drilled wells), as an example, the top of a borehole can be a fixed reference and the angle can be the gravity toolface, or high side toolface.\n \nFIG. \n25\n shows various examples of coordinate details, including a toolface representation \n2510\n with definitions of examples of U, V and W coordinates and a toolface representation with alternative definitions of examples of U and V in U, V and W coordinates.', 'In the toolface representations \n2510\n and \n2530\n, the toolface γ (e.g., toolface angle) is illustrated.', 'As an example, an approach can include performing a well system to global geographical system transformation via a matrix T\nGLWE\n.', 'As to examples of equations for representing features in a U, V and W coordinate system, consider the following:\n \nAxial U: sin θ cos α, sin θ sin α, cos θ)\n \nLateral V=W×U=(−sin α, cos α, 0)\n \nUp W: (−cos θ cos α, −cos θ sin α, sin θ)\n \nAs mentioned, axial and lateral may be switched as indicated in the toolface representations \n2510\n and \n2530\n.', 'As to a well system to global geographical system transformation matrix T\nGLWE\n, consider the following example equations:\n \n \n \n \n \n \n \nx\n \n→\n \n \na\n \n \n=\n \n \n \n \n \nl\n \n1\n \n \n\u2062\n \n \ni\n \n→\n \n \n \n+\n \n \n \nm\n \n1\n \n \n\u2062\n \n \nj\n \n→\n \n \n \n+\n \n \n \nn\n \n1\n \n \n\u2062\n \n \nk\n \n→\n \n \n \n \n=\n \n \n \n{\n \n \n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n\u2062\n \n \n \n \n\u2062\n \ncos\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n,\n \n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n\u2062\n \n \n \n \n\u2062\n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n,\n \n \ncos\n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n \n \n}\n \n \nT\n \n \n \n \n \n \n \n \n \n \n \ny\n \n→\n \n \na\n \n \n=\n \n \n \n \n \nl\n \n2\n \n \n\u2062\n \n \ni\n \n→\n \n \n \n+\n \n \n \nm\n \n2\n \n \n\u2062\n \n \nj\n \n→\n \n \n \n+\n \n \n \nn\n \n2\n \n \n\u2062\n \n \nk\n \n→\n \n \n \n \n=\n \n \n \n \nZ\n \n→\n \n \n×\n \n \n \nx\n \n→\n \n \na\n \n \n \n \n\uf603\n \n \n \nZ\n \n→\n \n \n×\n \n \n \nx\n \n→\n \n \na\n \n \n \n\uf604\n \n \n \n \n \n \n \n \n \n \n \n \nz\n \n→\n \n \na\n \n \n=\n \n \n \n \n \nl\n \n3\n \n \n\u2062\n \n \ni\n \n→\n \n \n \n+\n \n \n \nm\n \n2\n \n \n\u2062\n \n \nj\n \n→\n \n \n \n+\n \n \n \nn\n \n3\n \n \n\u2062\n \n \nk\n \n→\n \n \n \n \n=\n \n \n \n \n \nx\n \n→\n \n \na\n \n \n×\n \n \n \n \ny\n \n→\n \n \na\n \n \n\u2062\n \n \n \n \n \n[\n \n \nT\n \nGLWE\n \n \n]\n \n \n \n=\n \n \n \n[\n \n \n \n \n \nl\n \n1\n \n \n \n \n \nl\n \n2\n \n \n \n \n \nl\n \n3\n \n \n \n \n \n \n \nm\n \nl\n \n \n \n \n \nm\n \n2\n \n \n \n \n \nm\n \n3\n \n \n \n \n \n \n \nn\n \n1\n \n \n \n \n \nn\n \n2\n \n \n \n \n \nn\n \n3\n \n \n \n \n \n]\n \n \n=\n \n \n[\n \n \n \n \n \nl\n \n1\n \n \n \n \n \n \n-\n \n \nm\n \n1\n \n \n \n \n \n1\n \n-\n \n \nn\n \n1\n \n2\n \n \n \n \n \n \n \n \n \n \n-\n \n \nn\n \n1\n \n \n \n\u2062\n \n \nl\n \n1\n \n \n \n \n \n1\n \n-\n \n \nn\n \n1\n \n2\n \n \n \n \n \n \n \n \n \n \nm\n \n1\n \n \n \n \n \n \nl\n \n1\n \n \n \n \n1\n \n-\n \n \nn\n \n1\n \n2\n \n \n \n \n \n \n \n \n \n \n-\n \n \nn\n \n1\n \n \n \n\u2062\n \n \nm\n \n1\n \n \n \n \n \n1\n \n-\n \n \nn\n \n1\n \n2\n \n \n \n \n \n \n \n \n \n \nn\n \n1\n \n \n \n \n0\n \n \n \n \n \n1\n \n-\n \n \nn\n \n1\n \n2\n \n \n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n \nAs mentioned, a method can include performing one or more coordinate transforms.', 'For example, consider the following:\n \n \n \n \n \nM\n \n=\n \n \n[\n \n \n \n \n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n\u2062\n \n \n \n \n\u2062\n \ncos\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n \n \n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n\u2062\n \n \n \n \n\u2062\n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n \n \n \ncos\n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \n-\n \ns\n \n \n\u2062\n \nin\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n \n \n \ncos\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n \n \n0\n \n \n \n \n \n \n \n-\n \ncos\n \n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n\u2062\n \n \n \n \n\u2062\n \ncos\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n \n \n \n \n-\n \ncos\n \n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n\u2062\n \n \n \n \n\u2062\n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nα\n \n \n \n \n \nsin\n \n\u2062\n \n \n \n \n\u2062\n \nθ\n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n \nP\n \n \nU\n \n,\n \nV\n \n,\n \nW\n \n \n \n=\n \n \nM\n \n×\n \n \n(\n \n \n \nP\n \n \nx\n \n,\n \ny\n \n,\n \nz\n \n \n \n-\n \n \nC\n \n \nx\n \n,\n \ny\n \n,\n \nz\n \n \n \n \n)', 'In the foregoing equations, C is the origin of the U, V and W coordinates in x, y, z values, such as for a bit position or for a measure point.', 'With reference to the transformation \n2330\n of \nFIG.', '23\n, coordinate axes for U and V are illustrated and with reference to the toolface representations \n2510\n and \n2530\n, coordinate axes for U, V and W are illustrated.', 'FIG.', '26\n shows an example of a training framework \n2610\n that can generate one or more trained agents.', 'The training framework \n2610\n can include an agent \n2611\n, an environment for training \n2612\n, an environment for IDEAS \n2613\n (e.g., a computational drilling framework), a noisy simulator \n2614\n, a reward calculator \n2615\n, a plan generator \n2616\n, an IDEAS\n2\n simulator wrapper \n2617\n, an IDEAS\n2\n configuration file \n2618\n and an IDEAS\n2\n DLL (dynamic link library) \n2619\n.', 'As shown, various interactions can occur for generating a trained agent.', 'As an example, a trained agent may be stored in a repository such that it may be selected for a particular job, for example, as explained with respect to the system \n2200\n of \nFIG.', '22\n.', 'As an example, as shown in \nFIG.', '22\n, the GUI \n2202\n can provide for access to one or more custom agents.', 'In such an example, a training framework may be customized to generate a custom agent.', 'As an example, an approach such as the domain expert approach may be utilized, as explained with respect to \nFIG.', '17\n, to define, adjust, etc., one or more aspects of a system that can generate a trained agent.', 'FIG.', '27\n shows an example of a system \n2710\n that can include a front-end and a back-end where the front-end can be implemented via a web server \n2715\n that can utilize API calls (e.g., REST API \n2716\n, etc.) to a computational framework such as a drill control framework \n2714\n that is operatively coupled to equipment of a wellsite system \n2704\n.', 'The drill control framework \n2714\n can be, for example, a software product implemented using hardware that can output advisory actions to a driller or drillers.', 'For example, an action output by an agent may be transmitted to the drill control framework \n2714\n for rendering to a display where a driller can view the display and implement the action, which may be implemented using a manual approach, a semi-automated approach, or an automated approach.', 'For example, a manual approach can involve manual setting of equipment, a semi-automated approach can include interacting with a computerized controller, and an automated approach can include automatic implementation of an action via an automated controller.', 'As shown, the system \n2710\n can include a plan component \n2711\n, an agent \n2712\n (e.g., for state inference and action generation), an environment wrapper \n2713\n that can transfer information to the framework \n2714\n (e.g., an action) and that can receive information from the framework \n2714\n (e.g., observables).', 'As shown, observables and logs can be transferred where observables can include various types of information (e.g., HD, survey location, inclination, azimuth, toolface orientation, etc.).', 'As to logs (e.g., data logs), consider a number of actual toolface settings, sliding ratios, inclinations, azimuths, etc. (e.g., four or more, etc.).', 'As to context, it can include information such as bit location.', 'As an example, the agent \n2712\n may be trained using a training framework such as the training framework \n2610\n of \nFIG.', '26\n.', 'As an example, the agent \n2712\n may be selectable using one or more GUIs such as one or more of the GUIs of \nFIG.', '22\n.', 'As explained, rewards can be utilized for training and, as shown in the example of \nFIG.', '27\n, rewards may optionally be determined for one or more purposes.', 'FIG.', '27\n also shows an example of a GUI \n2706\n, which includes a plan trajectory, a current state, actions, a target and reward totals.', 'As explained, rewards can be utilized for training (see, e.g., the reward calculator \n2615\n of \nFIG. \n26\n).', 'In the example GUI \n2706\n, reward values may be utilized for one or more other purposes.', 'In the example of the GUI \n2706\n, various actions are shown with corresponding paths to end points with corresponding reward totals.', 'As an example, in execution (e.g., simulating or real), a method can include projecting trajectories to the future and maximizing: argmax_i P(Action_i|S_t+noise, Agent_j, Simulator_k).', 'Such a process can be utilized for one or more purposes such as, for example, monitoring, risk reduction, etc.', 'As an example, such a process may be utilized for decision monitoring and stabilization of one or more drilling operations.', 'As an example, during drilling, one or more operations as to an agent may be performed such as, for example, further learning that improves the agent using information acquired during the drilling (e.g., information as to a dogleg severity, etc.).', 'As to another approach, further learning that improves the agent may be performed after reaching the target where the improved agent is utilized for drilling another borehole (e.g., or a lateral from a common borehole, etc.).', 'As an example, where multiple boreholes are drilled from a common pad, an agent may be improved progressively with each of the boreholes such that the last borehole drilled utilized a most improved agent.', 'In such an approach, improvement may be with respect to dogleg severity.', 'For example, a range of dogleg severity used to train a generation X agent may be specified for a formation (e.g., 3 to 7) where upon drilling in the formation, a next generation agent (e.g., X+1) can be trained with a narrower range of dogleg severity (e.g., 5 to 6) for the formation, which can reduce uncertainty (e.g., a more adapted agent).', 'As explained, where uncertainty is greater (e.g., a greater range of dogleg severity, etc.), an agent may take greater actions (e.g., actions that differ from a plan); whereas, with less uncertainty, an agent may take lesser actions (e.g., actions that differ less from a plan).', 'Where accuracy to a plan is a factor, lesser uncertainty can result in greater accuracy to a plan.', 'As to equipment-related uncertainty, consider acquiring information during drilling of a borehole in a formation with a particular BHA where uncertainty of behavior of the BHA may be utilized to improve an agent, which may be for further drilling of the borehole and/or for drilling a subsequent borehole.', 'As an example, an agent may be general or specific with respect to equipment (e.g., consider a mud motor specific agent, etc.).', 'As an example, where drilling commences with a first mud motor (e.g., to drill a first section of a borehole) and where the mud motor is changed to a second mud motor (e.g., to drill a second section of a borehole), a first agent may be selected for drilling using the first mud motor and a second agent may be selected for drilling using the second mud motor.', 'As an example, the system \n2710\n can be operatively coupled to the training framework \n2610\n such that learning can be performed during drilling, after reaching a target, etc.', 'As explained with respect to \nFIG.', '17\n, domain expertise may be utilized in a training process.', 'As an example, a framework can utilize a Representational State Transfer (REST) API, which is of a style that defines a set of constraints to be used for creating web services.', 'Web services that conform to the REST architectural style, termed RESTful web services, provide interoperability between computer systems on the Internet.', 'RESTful web services can allow one or more requesting systems to access and manipulate textual representations of web resources by using a uniform and predefined set of stateless operations.', 'One or more other kinds of web services may be utilized (e.g., such as SOAP web services) that may expose their own sets of operations.', 'As an example, a computational controller operatively coupled to equipment at a rigsite (e.g., a wellsite, etc.) can utilize one or more APIs to interact with a computational framework that includes an agent or agents.', 'In such an example, one or more calls may be made where, in response, one or more actions are provided (e.g., control actions for drilling).', 'In such an example, a call may be made with various types of data (e.g., observables, etc.)', 'and a response can depend at least in part on such data.', 'For example, observables may be transmitted and utilized by an agent to infer a state where an action is generated based at least in part on the inferred state and where the action can be transmitted and utilized by a controller to control drilling at a rigsite.', 'FIG.', '28\n shows an example of a sequence engine \n2800\n.', 'As shown, the sequence engine \n2800\n can include one or more interfaces \n2820\n, an agent access component \n2840\n and one or more other components \n2860\n.', 'As shown, the sequence engine \n2800\n can be operatively coupled to a planning component or system \n2812\n and/or a control component or system \n2814\n (e.g., a drill control framework, etc.).', 'As an example, the one or more interfaces \n2820\n can be or include one or more application programming interfaces (APIs) where one or more calls may be made such that the sequence engine \n2800\n performs some action, which may be for purposes of planning and/or control.', 'As an example, a call may come from one or more of the planning component or system \n2812\n and the control component or system \n2814\n.', 'As an example, a driller may utilize a computing device to make a call, which may return sequence information as to one or more of a mode or modes (e.g., sliding mode, rotating mode, etc.), toolface, survey point, etc.', 'As an example, a mode may include a combination of surface rotation and mud motor rotation.\n \nFIG.', '29\n shows an example of a method \n2900\n and an example of a system \n2990\n.', 'As shown, the method \n2900\n includes a selection block \n2910\n for, via an agent component, selecting a drilling mode from a plurality of drilling modes to drill a portion of a borehole in a geologic environment according to a borehole trajectory; a generation block \n2920\n for, via a simulation component, generating a state of the borehole in the geologic environment by simulating drilling of the borehole using the selected drilling mode; a generation block \n2930\n for, via a reward component, generating a reward using the state and the planned borehole trajectory; and, a train block \n2940\n for, using the reward, training the agent component to generate a trained agent component that operates to maximize total future rewards via agent component-based drilling actions.', 'In such an example, the agent component can be an agent and the trained agent component can be a trained agent.', 'The method \n2900\n is shown as including various computer-readable storage medium (CRM) blocks \n2911\n, \n2921\n, \n2931\n and \n2941\n that can include processor-executable instructions that can instruct a computing system, which can be a control system, to perform one or more of the actions described with respect to the method \n2900\n.', 'In the example of \nFIG.', '29\n, the system \n2990\n includes one or more information storage devices \n2991\n, one or more computers \n2992\n, one or more networks \n2995\n and instructions \n2996\n.', 'As to the one or more computers \n2992\n, each computer may include one or more processors (e.g., or processing cores) \n2993\n and memory \n2994\n for storing the instructions \n2996\n, for example, executable by at least one of the one or more processors \n2993\n (see, e.g., the blocks \n2911\n, \n2921\n, \n2931\n and \n2941\n).', 'As an example, a computer may include one or more network interfaces (e.g., wired or wireless), one or more graphics cards, a display interface (e.g., wired or wireless), etc.\n \nFIG.', '30\n shows an example of a method \n3000\n and an example of a system \n3090\n.', 'As shown, the method \n3000\n includes a reception block \n3010\n for receiving sensor data during drilling of a portion of a borehole in a geologic environment; a determination block \n3020\n for determining a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and an issuance block \n3030\n for issuing a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', 'The method \n3000\n is shown as including various computer-readable storage medium (CRM) blocks \n3011\n, \n3021\n and \n3031\n that can include processor-executable instructions that can instruct a computing system, which can be a control system, to perform one or more of the actions described with respect to the method \n3000\n.', 'In the example of \nFIG.', '30\n, the system \n3090\n includes one or more information storage devices \n3091\n, one or more computers \n3092\n, one or more networks \n3095\n and instructions \n3096\n.', 'As to the one or more computers \n3092\n, each computer may include one or more processors (e.g., or processing cores) \n3093\n and memory \n3094\n for storing the instructions \n3096\n, for example, executable by at least one of the one or more processors \n3093\n (see, e.g., the blocks \n3011\n, \n3021\n and \n3031\n).', 'As an example, a computer may include one or more network interfaces (e.g., wired or wireless), one or more graphics cards, a display interface (e.g., wired or wireless), etc.', 'As an example, the method \n2900\n and/or the method \n3000\n may be a workflow that can be implemented using one or more frameworks that may be within a framework environment.', 'As an example, the system \n2990\n and/or the system \n3090\n can include local and/or remote resources.', 'For example, consider a browser application executing on a client device as being a local resource with respect to a user of the browser application and a cloud-based computing device as being a remote resources with respect to the user.', 'In such an example, the user may interact with the client device via the browser application where information is transmitted to the cloud-based computing device (or devices) and where information may be received in response and rendered to a display operatively coupled to the client device (e.g., via services, APIs, etc.).', 'FIG.', '31\n shows an example of a system \n3100\n that can be a well construction ecosystem.', 'As shown, the system \n3100\n can include one or more instances of the sequence engine \n2800\n (SEQ Engine) and can include a rig infrastructure \n3110\n and a drill plan component \n3120\n that can generation or otherwise transmit information associated with a plan to be executed utilizing the rig infrastructure \n3110\n, for example, via a drilling operations layer \n3140\n, which includes a wellsite component \n3142\n and an offsite component \n3144\n.', 'As shown, data acquired and/or generated by the drilling operations layer \n3140\n can be transmitted to a data archiving component \n3150\n, which may be utilized, for example, for purposes of planning one or more operations (e.g., per the drilling plan component \n3120\n).', 'In the example of \nFIG. \n31\n, the sequence engine \n2800\n is shown as being implemented with respect to the drill plan component \n3120\n, the wellsite component \n3142\n and/or the offsite component \n3144\n.', 'As an example, the sequence engine \n2800\n can interact with one or more of the components in the system \n3100\n.', 'As shown, the sequence engine \n2800\n can be utilized in conjunction with the drill plan component \n3120\n.', 'In such an example, data accessed from the data archiving component \n3150\n may be utilized to assess output of the sequence engine \n2800\n or, for example, may be utilized as input to the sequence engine \n2800\n.', 'As an example, the data archiving component \n3150\n can include drilling data for one or more offset wells and/or one or more current wells pertaining to specifications for and/or operations of one or more types of bits, one or more types of mud motors, etc.', 'As an example, data may be utilized in combination with a framework such as, for example, the IDEAS framework.', 'As shown in \nFIG. \n31\n, various components of the drilling operations layer \n3140\n may utilize the sequence engine \n2800\n and/or a drilling digital plan as output by the drill plan component \n3120\n.', 'During drilling, execution data can be acquired, which may be utilized by the sequence engine \n2800\n, for example, to update one or more sequences.', 'Such execution data can be archived in the data archiving component \n3150\n, which may be archived during one or more drill operations and may be available by the drill plan component \n3120\n, for example, for re-planning, etc.', 'As an example, the system \n3100\n may be utilized for purposes of reward definition, reward adjustment, etc.', 'As an example, the system \n3100\n may be utilized for purposes of one or more safety constraints (e.g., formulation, adjustment, etc., of a safety constraint, etc.).', 'As an example, a method can include, via an agent component, selecting a drilling mode from a plurality of drilling modes to drill a portion of a borehole in a geologic environment according to a borehole trajectory; via a simulation component, generating a state of the borehole in the geologic environment by simulating drilling of the borehole using the selected drilling mode; via a reward component, generating a reward using the state and the planned borehole trajectory; and, using the reward, training the agent component (e.g., the agent) to generate a trained agent component (e.g., a trained agent) that operates to maximize total future rewards via agent component-based drilling actions (e.g., agent-based drilling actions).', 'As an example, a trained agent can include an action-value function.', 'As an example, a trained agent component can include a trained value-based network as a trained neural network.', 'As an example, a trained agent component can include weights (e.g., weights of a trained neural network, etc.).', 'In such an example, training can include computing the weights using a loss function.', 'In such an example, training can include computing the weights by optimizing the loss function via a stochastic gradient descent.', 'As an example, a method can include generating a state of a borehole in a geologic environment by generating a borehole position where, for example, generating a reward includes determining a distance between the borehole position and a position of the planned borehole trajectory.', 'As an example, a method can include generating a reward by determining if a selected drilling mode corresponds to a switch in drilling modes where, for example, generating the reward includes decreasing the reward for a switch in drilling modes.', 'As an example, generating a reward can include tracking a number of switches in drilling modes where, for example, more switches can cause a decrease in a reward.', 'As an example, a borehole trajectory can be a planned borehole trajectory or, for example, a borehole trajectory can be a random borehole trajectory.', 'As an example, a method for training an agent can include transforming coordinates of a portion of a borehole of a geologic environment from a first coordinate system to coordinates of a second coordinate system.', 'As an example, a method for implementing a trained agent for drilling can include transforming coordinates of a portion of a borehole of a geologic environment from a first coordinate system to coordinates of a second coordinate system.', 'In such examples, the second coordinate system can be a relative coordinate system, which may be local to a position such as, for example, a last measured position (LMP), a position of a portion of a drillstring (e.g., a BHA) based on a sensed position, etc.', 'As explained with respect to \nFIGS.', '23\n, \n24\n and \n25\n, a transformation can transform features of an environment from a first coordinate system to a second coordinate system that can be, for example, a 2D coordinate system (e.g., U and V) or a 3D coordinate system (e.g., U, V and W) that can be utilized to define an agent state.', 'As an example, a sensor or sensors of a drillstring can provide sensor data for an inclination angle (e.g., inclination), which may be utilized to determine (e.g., or define) an axial direction of the drillstring.', 'For example, in \nFIG.', '24\n, the Cartesian coordinate system \n2406\n in X (North), Y (East), and Z (depth) is shown with respect to a cylinder that can represent a portion of a drillstring (e.g., an end portion at the bit end) to illustrate an inclination θ (inclination angle) with respect to the depth axis (Z) and an azimuth α (azimuth angle) with respect to the North axis (X).', 'In the example of \nFIG. \n23\n, the transformed environment \n2330\n shows U and V along with X (or offset) and Y (or total vertical depth); whereas, in \nFIG.', '25\n, the transformed example toolface representations \n2510\n and \n2530\n show U, V and W. As to depth, it may be aligned with gravity (g) as shown in \nFIG.', '25\n.', 'As an example, a coordinate transform can act to encode input in a manner suitable for agent training, agent inference, agent action, etc.', 'As an example, a coordinate transform can be a processing operation that processes data (e.g., observables, etc.) for purposes of improved agent training and trained agent implementation.', 'As an example, a reward calculator can utilize a transformed coordinate system (e.g., U and V or U, V and W) for calculating one or more portions of a reward (e.g., where a reward is a sum of various portions).', 'As an example, a method can include selecting one of a plurality of drilling modes where the drilling modes can include a sliding mode and a rotary mode.', 'As an example, a plurality of drilling modes can include a sliding up mode and a sliding down mode.', 'As an example, a method can include generating a state of a borehole in a geologic environment using a multi-dimensional model, which may be a two-dimensional model of the geologic environment or a three-dimensional model of the geologic environment.', 'As an example, a method can include, via an agent component, selecting a survey interval from a plurality of survey intervals to perform a downhole survey.', 'For example, consider a method that includes generating a reward by using a selected survey interval.', 'In such an example, generating the reward can include decreasing the reward based on a distance of the selected survey interval.', 'As mentioned, more frequent surveys may result in improved data as to location but at a cost of time.', 'As an example, a trained agent can be trained to, based on received input, output at least one of a drilling mode, a toolface orientation and a survey interval.', 'As an example, a method can include introducing noise in at least one of a hole propagation model simulator (e.g., using a domain randomization technique) and a network layer (e.g., using a noisy layer technique).', 'As an example, a trained agent component can operate using inferred conditions and observable conditions.', 'For example, inferred conditions can include measured depth of a last measurement, bottom hole position, bottom hole inclination and motor yield.', 'As an example, observable conditions can include at least one of a hole depth (HD), a measured depth (MD) at a measurement point, a position at a measurement point, an inclination at a measurement point, an azimuth, a magnetic toolface, and a gravity toolface.', 'As an example, a system can include a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: via an agent component, select a drilling mode from a plurality of drilling modes to drill a portion of a borehole in a geologic environment according to a borehole trajectory; via a simulation component, generate a state of the borehole in the geologic environment by simulating drilling of the borehole using the selected drilling mode; via a reward component, generate a reward using the state and the planned borehole trajectory; and, using the reward, train the agent component to generate a trained agent component that operates to maximize total future rewards via agent-based drilling actions.', 'As an example, one or more computer-readable storage media can include computer-executable instructions executable to instruct a computing system to: via an agent component, select a drilling mode from a plurality of drilling modes to drill a portion of a borehole in a geologic environment according to a borehole trajectory; via a simulation component, generate a state of the borehole in the geologic environment by simulating drilling of the borehole using the selected drilling mode; via a reward component, generate a reward using the state and the planned borehole trajectory; and, using the reward, train the agent component to generate a trained agent component that operates to maximize total future rewards via agent-based drilling actions.', 'As an example, a method can include receiving sensor data during drilling of a portion of a borehole in a geologic environment; determining a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issuing a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', 'In such an example, the plurality of drilling modes can include a rotary drilling mode and a sliding drilling mode.', 'As an example, a plurality of drilling modes can include a sliding up drilling mode and a sliding down drilling mode.', 'As an example, a method can include determining a toolface orientation from a plurality of toolface orientations using a trained neural network and at least a portion of sensor data.', 'As to a toolface orientation, it can be a toolface angle (see, e.g., the angle gamma γ).', 'As an example, a method can include issuing a control instruction where the control instruction includes an instruction for using the determined toolface orientation.', 'As an example, a method can include determining a tool survey interval from a plurality of tool survey intervals using a trained neural network and at least a portion of sensor data.', 'In such an example, the method can include issuing a control instruction where the control instruction includes an instruction for using the determined tool survey interval (e.g., by performing a downhole tool survey, etc.).', 'As an example, a method can include issuing a control instruction for drilling an additional portion of a borehole where the additional portion corresponds to drilling a length of pipe.', 'Such a method can include drilling the additional portion of the borehole (e.g., drilling a portion for a pipe, a stand, etc.).', 'As an example, a method can include issuing an application programming interface call using at least a portion of the sensor data and receiving a determined drilling mode in response to the application programming interface call where the determined drilling mode is determined using a trained neural network.', 'In such an example, a computer at a rigsite can issue the API call via a network interface to a network interface for remote computing resources, which can provide for execution of instructions that implement the trained neural network (e.g., according to weights, etc.).', 'In such an example, the API call can include data sufficient for the trained neural network to infer a state and determine an action, which can be a drilling mode.', 'As mentioned, an agent may operate with respect to a coordinate system, which may be defined in part using sensor data such as data indicative of an inclination of a portion of a drillstring (e.g., a BHA, a bit, etc.)', 'in a borehole in a formation.', 'In such an example, an API call can include an inclination where the inclination is utilized to orient a coordinate system for an agent where a determined action may be reference with respect to that coordinate system.', 'As an example, a method can include determining a drilling mode at least in part by defining a coordinate system for a portion of a drillstring using at least a portion of sensor data.', 'In such an example, the sensor data can include an inclination of the portion of the drillstring where the coordinate system includes an axial direction defined using the inclination.', 'As an example, a coordinate system can be a two-dimensional coordinate system where a plurality of drilling modes can include a sliding up drilling mode, a sliding down drilling mode and a rotary drilling mode.', 'As an example, a coordinate system can be a three-dimensional coordinate system where a plurality of drilling modes can include a sliding drilling mode and a rotary drilling mode and where a method can include determining a toolface orientation (e.g., using a trained neural network and at least a portion of sensor data).', 'As an example, a method can include receiving sensor data during drilling of a portion of a borehole in a geologic environment by performing a survey using sensors of a drillstring that is utilized to perform the drilling where the sensors acquire the sensor data.', 'In such an example, the method can further include determining a survey interval using the trained neural network and at least a portion of the sensor data and performing a subsequent survey according to the determined survey interval using the sensors of the drillstring.', 'As an example, a method can include determining a survey interval using a trained neural network and at least a portion of sensor data and performing a survey according to the determined survey interval using sensors of a drillstring that is utilized to perform drilling.', 'As an example, a method can include receiving a planned trajectory for a borehole where the method includes determining a drilling mode based at least in part on the planned trajectory.', 'As an example, a planned trajectory can include a curved portion and a target where decisions can be made as to drilling modes to drill a borehole that is at least in part curved to reach the target (e.g., within a specified distance, etc.).', 'As an example, a controller can include an agent component that selects a drilling mode using sensor data.', 'In such an example, the drilling mode can be selected from a plurality of drilling modes, which may include one or more of a sliding mode (e.g., sliding up, sliding down, etc.), a rotary mode, a survey interval, etc.', 'As an example, a system can include a processor; memory accessible to the processor; processor-executable instructions stored in the memory and executable by the processor to instruct the system to: receive sensor data during drilling of a portion of a borehole in a geologic environment; determine a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and issue a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', 'As an example, one or more computer-readable storage media can include computer-executable instructions executable to instruct a computing system to: receive sensor data during drilling of a portion of a borehole in a geologic environment; determine a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and, issue a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', 'As an example, a method may be implemented in part using computer-readable media (CRM), for example, as a module, a block, etc. that include information such as instructions suitable for execution by one or more processors (or processor cores) to instruct a computing device or system to perform one or more actions.', 'As an example, a single medium may be configured with instructions to allow for, at least in part, performance of various actions of a method.', 'As an example, a computer-readable medium (CRM) may be a computer-readable storage medium (e.g., a non-transitory medium) that is not a carrier wave.', 'According to an embodiment, one or more computer-readable media may include computer-executable instructions to instruct a computing system to output information for controlling a process.', 'For example, such instructions may provide for output to sensing process, an injection process, drilling process, an extraction process, an extrusion process, a pumping process, a heating process, etc.', 'In some embodiments, a method or methods may be executed by a computing system.', 'FIG.', '32\n shows an example of a system \n3200\n that can include one or more computing systems \n3201\n-\n1\n, \n3201\n-\n2\n, \n3201\n-\n3\n and \n3201\n-\n4\n, which may be operatively coupled via one or more networks \n3209\n, which may include wired and/or wireless networks.', 'As an example, a system can include an individual computer system or an arrangement of distributed computer systems.', 'In the example of \nFIG.', '32\n, the computer system \n3201\n-\n1\n can include one or more modules \n3202\n, which may be or include processor-executable instructions, for example, executable to perform various tasks (e.g., receiving information, requesting information, processing information, simulation, outputting information, etc.).', 'As an example, a module may be executed independently, or in coordination with, one or more processors \n3204\n, which is (or are) operatively coupled to one or more storage media \n3206\n (e.g., via wire, wirelessly, etc.).', 'As an example, one or more of the one or more processors \n3204\n can be operatively coupled to at least one of one or more network interface \n3207\n.', 'In such an example, the computer system \n3201\n-\n1\n can transmit and/or receive information, for example, via the one or more networks \n3209\n (e.g., consider one or more of the Internet, a private network, a cellular network, a satellite network, etc.).', 'As an example, the computer system \n3201\n-\n1\n may receive from and/or transmit information to one or more other devices, which may be or include, for example, one or more of the computer systems \n3201\n-\n2\n, etc.', 'A device may be located in a physical location that differs from that of the computer system \n3201\n-\n1\n.', 'As an example, a location may be, for example, a processing facility location, a data center location (e.g., server farm, etc.), a rig location, a wellsite location, a downhole location, etc.', 'As an example, a processor may be or include a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, or another control or computing device.', 'As an example, the storage media \n3206\n may be implemented as one or more computer-readable or machine-readable storage media.', 'As an example, storage may be distributed within and/or across multiple internal and/or external enclosures of a computing system and/or additional computing systems.', 'As an example, a storage medium or storage media may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories, magnetic disks such as fixed, floppy and removable disks, other magnetic media including tape, optical media such as compact disks (CDs) or digital video disks (DVDs), BLUERAY disks, or other types of optical storage, or other types of storage devices.', 'As an example, a storage medium or media may be located in a machine running machine-readable instructions, or located at a remote site from which machine-readable instructions may be downloaded over a network for execution.', 'As an example, various components of a system such as, for example, a computer system, may be implemented in hardware, software, or a combination of both hardware and software (e.g., including firmware), including one or more signal processing and/or application specific integrated circuits.', 'As an example, a system may include a processing apparatus that may be or include a general purpose processors or application specific chips (e.g., or chipsets), such as ASICs, FPGAs, PLDs, or other appropriate devices.\n \nFIG.', '33\n shows components of a computing system \n3300\n and a networked system \n3310\n.', 'The system \n3300\n includes one or more processors \n3302\n, memory and/or storage components \n3304\n, one or more input and/or output devices \n3306\n and a bus \n3308\n.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components \n3304\n).', 'Such instructions may be read by one or more processors (e.g., the processor(s) \n3302\n) via a communication bus (e.g., the bus \n3308\n), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device \n3306\n).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.', 'According to an embodiment, components may be distributed, such as in the network system \n3310\n.', 'The network system \n3310\n includes components \n3322\n-\n1\n, \n3322\n-\n2\n, \n3322\n-\n3\n, . . .', '3322\n-N.', 'For example, the components \n3322\n-\n1\n may include the processor(s) \n3302\n while the component(s) \n3322\n-\n3\n may include memory accessible by the processor(s) \n3302\n.', 'Further, the component(s) \n3322\n-\n2\n may include an I/O device for display and optionally interaction with a method.', 'The network may be or include the Internet, an intranet, a cellular network, a satellite network, etc.', 'As an example, a device may be a mobile device that includes one or more network interfaces for communication of information.', 'For example, a mobile device may include a wireless network interface (e.g., operable via IEEE 802.11, ETSI GSM, BLUETOOTH, satellite, etc.).', 'As an example, a mobile device may include components such as a main processor, memory, a display, display graphics circuitry (e.g., optionally including touch and gesture circuitry), a SIM slot, audio/video circuitry, motion processing circuitry (e.g., accelerometer, gyroscope), wireless LAN circuitry, smart card circuitry, transmitter circuitry, GPS circuitry, and a battery.', 'As an example, a mobile device may be configured as a cell phone, a tablet, etc.', 'As an example, a method may be implemented (e.g., wholly or in part) using a mobile device.', 'As an example, a system may include one or more mobile devices.', 'As an example, a system may be a distributed environment, for example, a so-called “cloud” environment where various devices, components, etc. interact for purposes of data storage, communications, computing, etc.', 'As an example, a device or a system may include one or more components for communication of information via one or more of the Internet (e.g., where communication occurs via one or more Internet protocols), a cellular network, a satellite network, etc.', 'As an example, a method may be implemented in a distributed environment (e.g., wholly or in part as a cloud-based service).', 'As an example, information may be input from a display (e.g., consider a touchscreen), output to a display or both.', 'As an example, information may be output to a projector, a laser device, a printer, etc. such that the information may be viewed.', 'As an example, information may be output stereographically or holographically.', 'As to a printer, consider a 2D or a 3D printer.', 'As an example, a 3D printer may include one or more substances that can be output to construct a 3D object.', 'For example, data may be provided to a 3D printer to construct a 3D representation of a subterranean formation.', 'As an example, layers may be constructed in 3D (e.g., horizons, etc.), geobodies constructed in 3D, etc.', 'As an example, holes, fractures, etc., may be constructed in 3D (e.g., as positive structures, as negative structures, etc.).', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words “means for” together with an associated function.']

['1.', 'A method comprising:\nreceiving sensor data by a computing system during drilling of a portion of a borehole in a geologic environment;\nusing the computing system, determining a drilling mode from a plurality of drilling modes based on a decision of a trained neural network generated by a reinforcement learning framework, wherein the decision is based on at least a portion of the sensor data, wherein the plurality of drilling modes comprises a rotary drilling mode and a sliding drilling mode, and wherein the trained neural network embodies a penalty for the sliding drilling mode in comparison to the rotary drilling mode, a penalty for a rotary drilling mode to sliding drilling mode transition, and a reward for forward drilling; and\nusing the computing system, responsive to the determined drilling mode being different than a current drilling mode for the drilling of the portion of the borehole, transitioning the current drilling mode to the determined drilling mode for drilling an additional portion of the borehole.', '2.', 'The method of claim 1, wherein the plurality of drilling modes comprises a sliding up drilling mode and a sliding down drilling mode.', '3.', 'The method of claim 1, comprising determining a toolface orientation from a plurality of toolface orientations using the trained neural network and at least a portion of the sensor data.', '4.', 'The method of claim 3, wherein issuing the control instruction comprises issuing an instruction for using the determined toolface orientation.', '5.', 'The method of claim 1, comprising determining a tool survey interval from a plurality of tool survey intervals using the trained neural network and at least a portion of the sensor data.', '6.', 'The method of claim 5, wherein issuing the control instruction comprises issuing an instruction for using the determined tool survey interval.', '7.', 'The method of claim 1, wherein the control instruction for drilling the additional portion of the borehole corresponds to drilling a length of pipe.', '8.', 'The method of claim 1, comprising drilling the additional portion of the borehole.', '9.', 'The method of claim 1, comprising issuing an application programming interface call using at least a portion of the sensor data and receiving the drilling mode in response to the application programming interface call.', '10.', 'The method of claim 1, wherein the determining the drilling mode comprises defining a coordinate system for a portion of a drillstring using at least a portion of the sensor data.', '11.', 'The method of claim 10, wherein the sensor data comprise an inclination of the portion of the drillstring and wherein the coordinate system comprises an axial direction defined using the inclination.', '12.', 'The method of claim 10, wherein the coordinate system is a two-dimensional coordinate system and wherein the plurality of drilling modes comprises a sliding up drilling mode and a sliding down drilling mode.', '13.', 'The method of claim 10, wherein the coordinate system is a three-dimensional coordinate system, and further comprising determining a toolface orientation using the trained neural network and at least a portion of the sensor data.', '14.', 'The method of claim 1, wherein the receiving the sensor data during drilling of the portion of the borehole in the geologic environment comprises performing a survey using sensors of a drillstring that is utilized to perform the drilling wherein the sensors acquire the sensor data.', '15.', 'The method of claim 14, further comprising determining a survey interval using the trained neural network and at least a portion of the sensor data and performing a subsequent survey according to the determined survey interval using the sensors of the drillstring.', '16.', 'The method of claim 1, comprising receiving a planned trajectory for the borehole wherein the determining the drilling mode is based at least in part on the planned trajectory.', '17.', 'A system comprising:\na processor;\nmemory accessible to the processor;\nprocessor-executable instructions stored in the memory and executable by the processor to instruct the system to: receive sensor data during drilling of a portion of a borehole in a geologic environment; determine a drilling mode from a plurality of drilling modes based on a decision of a trained neural network generated by a reinforcement learning framework, wherein the decision is based on at least a portion of the sensor data, wherein the plurality of drilling modes comprises a rotary drilling mode and a sliding drilling mode, and wherein the trained neural network embodies a penalty for the sliding drilling mode in comparison to the rotary drilling mode, a penalty for a rotary drilling mode to sliding drilling mode transition, and a reward for forward drilling; and\nresponsive to the determined drilling mode being different than a current drilling mode for the drilling of the portion of the borehole, transition the current drilling mode to the determined drilling mode for drilling an additional portion of the borehole using the determined drilling mode.\n\n\n\n\n\n\n18.', 'One or more computer-readable storage media comprising computer-executable instructions executable to instruct a computing system to:\nreceive sensor data during drilling of a portion of a borehole in a geologic environment;\ndetermine a drilling mode from a plurality of drilling modes based on a decision of a trained neural network generated by a reinforcement learning framework, wherein the decision is based on at least a portion of the sensor data, wherein the plurality of drilling modes comprises a rotary drilling mode and a sliding drilling mode, and wherein the trained neural network embodies a penalty for the sliding drilling mode in comparison to the rotary drilling mode, a penalty for a rotary drilling mode to sliding drilling mode transition, and a reward for forward drilling; and\nresponsive to the determined drilling mode being different than a current drilling mode for the drilling of the portion of the borehole, transition the current drilling mode to the determined drilling mode for drilling an additional portion of the borehole using the determined drilling mode.']

['FIG. 1 illustrates examples of equipment in a geologic environment;; FIG. 2 illustrates examples of equipment and examples of hole types;; FIG.', '3 illustrates an example of a system;; FIG.', '4 illustrates an example of a wellsite system and an example of a computing system;; FIG.', '5 illustrates an example of equipment in a geologic environment;; FIG.', '6 illustrates an example of a graphical user interface;; FIG.', '7 illustrates an example of a method;; FIG. 8 illustrates examples of directional drilling equipment;; FIG.', '9 illustrates an example of a graphical user interface;; FIG.', '10 illustrates an example of a graphical user interface;; FIG.', '11 illustrates an example of a graphical user interface;; FIG.', '12 illustrates an example of a method;; FIG.', '13 illustrates an example of a system;; FIG.', '14 illustrates an example of a method;; FIG.', '15 illustrates examples of approaches to link simulation and reality;; FIG.', '16 illustrates an example of a method;; FIG.', '17 illustrates an example of a system;; FIG.', '18 illustrates an example of a system;; FIG.', '19 illustrates an example of a system;; FIG.', '20 illustrates examples of graphical user interfaces;; FIG.', '21 illustrates examples of graphical user interfaces;; FIG.', '22 illustrates an example of a system;; FIG.', '23 illustrates an example of a method;; FIG.', '24 illustrates examples of coordinate systems;; FIG.', '25 illustrates examples of representations of a drillstring toolface with respect to coordinate systems;; FIG.', '26 illustrates an example of a training framework;; FIG.', '27 illustrates an example of a system;; FIG.', '28 illustrates an example of a sequence engine;; FIG.', '29 illustrates an example of a method and an example of a system;; FIG.', '30 illustrates an example of a method and an example of a system;; FIG.', '31 illustrates an example of a system;; FIG.', '32 illustrates an example of a computing system; and; FIG.', '33 illustrates example components of a system and a networked system.; FIG.', '1 shows an example of a geologic environment 120.', 'In FIG.', '1, the geologic environment 120 may be a sedimentary basin that includes layers (e.g., stratification) that include a reservoir 121 and that may be, for example, intersected by a fault 123 (e.g., or faults).', 'As an example, the geologic environment 120 may be outfitted with any of a variety of sensors, detectors, actuators, etc.', 'For example, equipment 122 may include communication circuitry to receive and to transmit information with respect to one or more networks 125.', 'Such information may include information associated with downhole equipment 124, which may be equipment to acquire information, to assist with resource recovery, etc.', 'Other equipment 126 may be located remote from a well site and include sensing, detecting, emitting or other circuitry.', 'Such equipment may include storage and communication circuitry to store and to communicate data, instructions, etc.', 'As an example, one or more pieces of equipment may provide for measurement, collection, communication, storage, analysis, etc. of data (e.g., for one or more produced resources, etc.).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.', 'For example, FIG. 1 shows a satellite in communication with the network 125 that may be configured for communications, noting that the satellite may additionally or alternatively include circuitry for imagery (e.g., spatial, spectral, temporal, radiometric, etc.).', '; FIG. 1 also shows the geologic environment 120 as optionally including equipment 127 and 128 associated with a well that includes a substantially horizontal portion (e.g., a lateral portion) that may intersect with one or more fractures 129.', 'For example, consider a well in a shale formation that may include natural fractures, artificial fractures (e.g., hydraulic fractures) or a combination of natural and artificial fractures.', 'As an example, a well may be drilled for a reservoir that is laterally extensive.', 'In such an example, lateral variations in properties, stresses, etc. may exist where an assessment of such variations may assist with planning, operations, etc. to develop the reservoir (e.g., via fracturing, injecting, extracting, etc.).', 'As an example, the equipment 127 and/or 128 may include components, a system, systems, etc. for fracturing, seismic sensing, analysis of seismic data, assessment of one or more fractures, injection, production, etc.', 'As an example, the equipment 127 and/or 128 may provide for measurement, collection, communication, storage, analysis, etc. of data such as, for example, production data (e.g., for one or more produced resources).', 'As an example, one or more satellites may be provided for purposes of communications, data acquisition, etc.; FIG. 1 also shows an example of equipment 170 and an example of equipment 180.', 'Such equipment, which may be systems of components, may be suitable for use in the geologic environment 120.', 'While the equipment 170 and 180 are illustrated as land-based, various components may be suitable for use in an offshore system (e.g., an offshore rig, etc.).', '; FIG.', '2 shows an example of a wellsite system 200 (e.g., at a wellsite that may be onshore or offshore).', 'As shown, the wellsite system 200 can include a mud tank 201 for holding mud and other material (e.g., where mud can be a drilling fluid), a suction line 203 that serves as an inlet to a mud pump 204 for pumping mud from the mud tank 201 such that mud flows to a vibrating hose 206, a drawworks 207 for winching drill line or drill lines 212, a standpipe 208 that receives mud from the vibrating hose 206, a kelly hose 209 that receives mud from the standpipe 208, a gooseneck or goosenecks 210, a traveling block 211, a crown block 213 for carrying the traveling block 211 via the drill line or drill lines 212 (see, e.g., the crown block 173 of FIG. 1), a derrick 214 (see, e.g., the derrick 172 of FIG. 1), a kelly 218 or a top drive 240, a kelly drive bushing 219, a rotary table 220, a drill floor 221, a bell nipple 222, one or more blowout preventors (BOPs) 223, a drillstring 225, a drill bit 226, a casing head 227 and a flow pipe 228 that carries mud and other material to, for example, the mud tank 201.; FIG.', '2 also shows some examples of types of holes that may be drilled.', 'For example, consider a slant hole 272, an S-shaped hole 274, a deep inclined hole 276 and a horizontal hole 278.; FIG.', '3 shows an example of a system 300 that includes various equipment for evaluation 310, planning 320, engineering 330 and operations 340.', 'For example, a drilling workflow framework 301, a seismic-to-simulation framework 302, a technical data framework 303 and a drilling framework 304 may be implemented to perform one or more processes such as a evaluating a formation 314, evaluating a process 318, generating a trajectory 324, validating a trajectory 328, formulating constraints 334, designing equipment and/or processes based at least in part on constraints 338, performing drilling 344 and evaluating drilling and/or formation 348.; FIG.', '4 shows an example of a wellsite system 400, specifically, FIG.', '4 shows the wellsite system 400 in an approximate side view and an approximate plan view along with a block diagram of a system 470.; FIG.', '4 also shows a battery 480 that may be operatively coupled to the system 470, for example, to power the system 470.', 'As an example, the battery 480 may be a back-up battery that operates when another power supply is unavailable for powering the system 470.', 'As an example, the battery 480 may be operatively coupled to a network, which may be a cloud network.', 'As an example, the battery 480 can include smart battery circuitry and may be operatively coupled to one or more pieces of equipment via a SMBus or other type of bus.; FIG.', '5 shows a schematic diagram depicting an example of a drilling operation of a directional well in multiple sections.', 'The drilling operation depicted in FIG.', '5 includes a wellsite drilling system 500 and a field management tool 520 for managing various operations associated with drilling a bore hole 550 of a directional well 517.', 'The wellsite drilling system 500 includes various components (e.g., drillstring 512, annulus 513, bottom hole assembly (BHA) 514, kelly 515, mud pit 516, etc.).', 'As shown in the example of FIG.', '5, a target reservoir may be located away from (as opposed to directly under) the surface location of the well 517.', 'In such an example, special tools or techniques may be used to ensure that the path along the bore hole 550 reaches the particular location of the target reservoir.; FIG.', '6 shows an example of a graphical user interface (GUI) 600 that includes information associated with a well plan.', 'Specifically, the GUI 600 includes a panel 610 where surfaces representations 612 and 614 are rendered along with well trajectories where a location 616 can represent a position of a drillstring 617 along a well trajectory.', 'The GUI 600 may include one or more editing features such as an edit well plan set of features 630.', 'The GUI 600 may include information as to individuals of a team 640 that are involved, have been involved and/or are to be involved with one or more operations.', 'The GUI 600 may include information as to one or more activities 650.; FIG.', '6 also shows an example of a table 670 as a point spreadsheet that specifies information for a plurality of wells.', 'As shown in the example table 670, coordinates such as “x” and', '“y” and “depth” can be specified for various features of the wells, which can include pad parameters, spacings, toe heights, step outs, initial inclinations, kick offs, etc.; FIG.', '7 shows an example of a method 700 that utilizes drilling equipment to perform drilling operations.', 'As shown, the drilling equipment includes a rig 701, a lift system 702, a block 703, a platform 704, slips 705 and a bottom hole assembly 706.', 'As shown, the rig 701 supports the lift system 702, which provides for movement of the block 703 above the platform 704 where the slips 705 may be utilized to support a drillstring that includes the bottom hole assembly 706, which is shown as including a bit to drill into a formation to form a borehole.', '; FIG.', '8 shows an example of a drilling assembly 800 in a geologic environment 801 that includes a borehole 803 where the drilling assembly 800 (e.g., a drillstring) includes a bit 804 and a motor section 810 where the motor section 810 includes a mud motor that can drive the bit 804 (e.g., cause the bit 804 to rotate and deepen the borehole 803).', '; FIG.', '9 shows an example of a graphical user interface 900 that includes a graphic of a system 910 and a graphic of a trajectory 930 where the system 910 can perform directional drilling to drill a borehole according to the trajectory 930.', 'As shown, the trajectory 930 includes a substantially vertical section, a dogleg and a substantially lateral section (e.g., a substantially horizontal section).', 'As an example, the dogleg can be defined between a kickoff point (K) and a landing point (L), which are shown approximately as points along the trajectory 930.', 'The system 910 can be operated in various operational modes, which can include, for example, rotary drilling and sliding.; FIG.', '10 shows an example of a graphical user interface 1000 that includes various tracks for different types of operations, which include rotating, manual sliding, and automation assisted sliding according to a provided amount of surface torque.', 'As shown in the GUI 1000, comparisons can be made for rotating and sliding drilling parameters for the rotating mode and the sliding mode.', 'As shown, rate of penetration (ROP) and toolface orientation control can depend large on an ability of a system to transfer weight to the bit and counter the effects of torque and drag between rotating and sliding modes.', 'As shown, the best ROP is achieved while rotating; however, toolface varies drastically, as there is no attempt to control it (Track 3).', 'Hook load (Track 2) and weight on bit (WOB) remain fairly constant while differential pressure (Track 1) shows a slight increase as depth increases.', 'To begin manual sliding, a drilling operation can act to pull off-bottom to release trapped torque; during this time, WOB (Track 1) decreases while hook load (Track 2) increases.', 'As drilling proceeds, inconsistencies in differential pressure (e.g., difference between pressures when the bit is on-bottom versus off-bottom) indicate poor transfer of weight to the bit (Track 1).', 'Spikes of rotary torque indicate efforts to orient and maintain toolface orientation (Track 2).', 'As shown, toolface control may be poor because of trouble transferring weight to bit, which is also reflected by poor ROP (Track 3).', 'Using an automation assisted sliding mode system, a directional driller can more quickly gain toolface orientation.', 'When the WOB increased, differential pressure was consistent, demonstrating good weight transfer (Track 1).', 'In the example of FIG.', '10, weight on bit during a sliding operation is lower than during a manual sliding operation.', 'Left-right oscillation of the drillpipe is relatively constant through the slide (Track 2).', 'Average ROP is substantially higher than that attained during the manual slide, and toolface orientation is more consistent (Track 3).; FIG.', '11 shows an example of a graphical user interface 1100 that includes various types of information for construction of a well where times are rendered for corresponding actions.', 'In the example of FIG.', '11, the times are shown as an estimated time (ET) in hours and a total or cumulative time (TT), which is in days.', 'Another time may be a clean time, which can be for performing an action or actions without occurrence of non-productive time (NPT) while the estimated time (ET) can include NPT, which may be determined using one or more databases, probabilistic analysis, etc.', 'In the example of FIG.', '11, the total time (TT or cumulative time) may be a sum of the estimated time column.', 'As an example, during execution and/or replanning the GUI 1100 may be rendered and revised accordingly to reflect changes.', 'As shown in the example of FIG.', '11, the GUI 1100 can include selectable elements and/or highlightable elements.', 'As an example, an element may be highlighted responsive to a signal that indicates that an activity is currently being performed, is staged, is to be revised, etc.', 'For example, a color coding scheme may be utilized to convey information to a user via the GUI 1100.', '; FIG.', '12 shows an example of a method 1200 that can output a predicted propagation direction of a drill bit based on forces and bit characteristics.', 'The method 1200 can utilize a computational framework that includes one or more features of a framework such as, for example, the IDEAS framework (Schlumberger Limited, Houston, Tex.).', 'The IDEAS framework utilizes the finite element method (FEM) to model various physical phenomena, which can include reaction force at a bit (e.g., using a static, physics-based model).', 'The FEM utilizes a grid or grids that discretize one or more physical domains.', 'Equations such as, for example, continuity equations, are utilized to represent physical phenomena.', 'The IDEAS framework, as with other types of FEM-based approaches, provides for numerical experimentation that approximates real-physical experimentation.', 'In various instances, a framework can be a simulator that performs simulations to generation simulation results that approximate results that have occurred, are occurring or may occur in the real-world.', 'In the context of drilling, such a framework can provide for execution of scenarios that can be part of a workflow or workflows as to planning, control, etc.', 'As to control, a scenario may be based on data acquired by one or more sensors during one or more well construction operations such as, for example, directional drilling.', 'In such an approach, determinations can be made using scenario result(s) that can directly and/or indirectly control one or more aspects of directional drilling.', 'For example, consider control of sliding and/or rotating as modes of performing directional drilling.; FIG.', '13 shows an example of a system 1300 that includes an agent 1310 and an environment 1350 where the agent 1310 interacts with the environment 1350 though action (A), state (S), and reward (R).; FIG.', '14 shows an example of a method 1400 that involves a Q function approach for reinforcement learning using a deep neural network.', 'An article by Mnih et al., Human-level control through deep reinforcement learning, Nature, Vol. 518: pp.', '529-533, is incorporated by reference herein.; FIG.', '15 shows various examples of approaches for handling simulation and reality.', 'For example, in an approach 1510, a calibrated simulation aims to provide for system identification as to reality; in an approach 1530, domain adaptation is utilized to bridge a calibrated simulation with reality; and, in an approach 1550, a distribution of domain-randomized sums is utilized to encapsulate at least a portion of reality.; FIG.', '17 shows an example of a system 1700 that can be utilized for training an agent such as a deep reinforcement learning agent (DRL agent) 1710 using an environment 1730 that includes a simulator 1750 and a reward calculator 1770.', 'As an example, a trained agent can provide for automated directional drilling in a geologic environment (see, e.g., FIG.', '27, FIG.', '28, etc.).', '; FIG.', '17 also shows an example of a loop where a domain expert 1790 may be utilized that can make one or more adjustments to and/or one or more definitions for operation of the reward calculator 1770.', 'For example, feedback from the environment 1730 can cause the agent 1710 to issue an action, which can be observed (e.g., assessed, analyzed, etc.)', 'by the domain expert 1790 where, based at least in part on such observation, the reward calculator 1770 may be adjusted, further defined, etc.', 'As shown, the reward calculator 1770 can be applied to the environment 1730, as shown in the system 1700.', 'In such an approach, the agent 1710 can be further trained, honed, etc., using domain expertise (e.g., a domain expert and/or other domain expertise).', 'As an example, domain expertise may be from one or more wells that have been drilled using an agent or not using an agent.; FIG.', '18 shows an example of a system 1800 for training an agent 1810 (see, e.g., the agent 1710) in a simulated environment 1830 such as the environment 1730 of FIG.', '17.', 'As shown, the simulated environment 1830 is multidimensional and includes a lateral dimension as offset and a depth dimension as depth.', 'The simulated environment 1830 shows a trajectory where drilling can be via rotation (e.g., rotate or rotary) or via sliding (e.g., slide).', 'In the example of FIG.', '18, the agent 1810 can issue one or more control instructions that can instruction drilling equipment to operation in a particular mode, which can include a rotate mode and a slide mode (e.g., slide up or slide down).', 'In the example, above the kickoff point, the agent 1810 issues an instruction to drill in a rotate mode while at a position below the kickoff point and prior to the landing point, the agent 1810 issues an instruction to drill in a slide mode.', 'As an example, where two modes exist, an instruction can be to transition from one mode to the other (e.g., consider a binary state transition as from 0 to 1 or 1 to 0 where a rotate mode is 0 and a slide mode is 1 or vice versa).', 'As an example, where three modes exist, an instruction can be to transition from one mode to another one of the modes (e.g., consider an instruction such as −1, 0, +1 for slide down, rotary, and slide up).; FIG.', '19 shows an example of a system 1900 for training an agent 1910 (see, e.g., the agent 1710) in a simulated environment 1930 such as the environment 1730 of FIG.', '17.', 'As shown, the environment 1930 can be three-dimensional with dimensions such as total vertical depth (e.g., Z), offset in an E-W direction (e.g., X) and offset in an S-N direction (e.g., Y).', 'In the environment 1930, various surfaces are illustrate that may represent horizons and/or other structural features as may be discerned through various field operations (e.g., drilling, seismic surveys, etc.).', '; FIG.', '20 shows examples of graphical user interfaces 2010, 2030 and 2050 as to evaluation of a three-dimensional agent to drill according to a planned trajectory.', 'In the GUIs 2010, 2030 and 2050, a dashed line represents the planned trajectory while solid lines represent evaluations of the agent, which show some amount of deviations with respect to the planned trajectory.; FIG.', '21 shows various examples of graphical user interfaces 2110, 2130 and 2150 that can plot rewards as determined during training.', 'The GUI 2110 shows an accuracy reward, the GUI 2130 shows an operational reward and the GUI 2150 shows a total reward.', 'In the GUIs 2110, 2130 and 2150, various types of statistical analyses may be performed on reward data, for example, to understand how one or more definitions, adjustments, etc., may be refined.', 'For example, a portion of reward data can be selected and rendered to a display with respect to a plot such as the plot of the GUI 2010, which can provide zoom functionality.', 'In such an approach, a trajectory can be viewed in combination with reward data as to how an agent is behaving.', 'As the plot of the GUI 2010 can include data corresponding to an environment, an analysis may determine that one or more environmental parameters may be giving rise to certain actions and corresponding rewards.', 'In such an example, a reward calculator may be adjusted, redefined, etc., to account for the behavior, for example, in a manner that may depend on lithology, dogleg severity, type of equipment, etc.; FIG.', '22 shows an example of a system 2200 that includes various graphical user interfaces (GUIs) 2201, 2202 and 2203.', 'As shown, the GUI 2201 can include a geographic map with various labeled regions such as basins, plays, and prospective plays.', 'In such an example, a graphic control can be utilized to select a region and, for example, a rig or rigsite in the region.', 'As shown, a graphical control is utilized to render another graphical control with information and menu items such as trajectory file, digital well plan, and other.', 'As an example, upon receipt of a command responsive to input (e.g., a mouse click, a hover, a touch, a stylus position, a voice command, etc.), the system 2200 can access a database that includes information as to various agents where such the system 2200 can select one or more agents, optionally ranking them, for use with a project such as, for example, a particular Marcellus rig at a rigsite in the Marcellus basin.', 'In such an example, the system 2200 can tailor the selection or selections using data about the rig, the play, drillstring equipment, etc.; FIG.', '23 shows an example of a method that includes a coordinate transformation with respect to an example of an environment 2310 and an example of a transformation 2330 of the environment 2310 where a planned trajectory is shown and another trajectory is shown that represents at least some amount of an actually drilled borehole.', 'As shown, there are some deviations from the planned trajectory where an actual drilled point can be compared to a planned point where the planned point may be an intersection point.', 'In the transformation 2330, U, V coordinates are shown, where V represents an axial direction (e.g., axial direction of a bit) and where U is orthogonal to V; noting that the coordinates U and V may be represented as V and U, for example, where U is the axial direction (e.g., axial direction of a bit).;', 'FIG.', "24 shows various examples of coordinate system in space, which include a right hand Cartesian coordinate system 2402 with x, y, and z; a left hand Cartesian coordinate system 2404 with x, y, and z; a hybrid cylindrical and Cartesian coordinate system 2406 with X (North), Y (East), and Z (Depth) along with inclination θ (theta), azimuth α (alpha) and toolface angle γ (gamma), and coordinate systems 2408 of a computational framework with X (North and “i”), Y (East and “j”), and Z (Earth's core and “k”) and xa (tangent to well axis), ya (to right side and looking downwardly) and za (lower side).", '; FIG.', '25 shows various examples of coordinate details, including a toolface representation 2510 with definitions of examples of U, V and W coordinates and a toolface representation with alternative definitions of examples of U and V in U, V and W coordinates.', 'In the toolface representations 2510 and 2530, the toolface γ (e.g., toolface angle) is illustrated.', 'As an example, an approach can include performing a well system to global geographical system transformation via a matrix TGLWE.; FIG.', '26 shows an example of a training framework 2610 that can generate one or more trained agents.', 'The training framework 2610 can include an agent 2611, an environment for training 2612, an environment for IDEAS 2613 (e.g., a computational drilling framework), a noisy simulator 2614, a reward calculator 2615, a plan generator 2616, an IDEAS2 simulator wrapper 2617, an IDEAS2 configuration file 2618 and an IDEAS2 DLL (dynamic link library) 2619.', 'As shown, various interactions can occur for generating a trained agent.', 'As an example, a trained agent may be stored in a repository such that it may be selected for a particular job, for example, as explained with respect to the system 2200 of FIG.', '22.', 'As an example, as shown in FIG.', '22, the GUI 2202 can provide for access to one or more custom agents.', 'In such an example, a training framework may be customized to generate a custom agent.', 'As an example, an approach such as the domain expert approach may be utilized, as explained with respect to FIG.', '17, to define, adjust, etc., one or more aspects of a system that can generate a trained agent.;', 'FIG.', '27 shows an example of a system 2710 that can include a front-end and a back-end where the front-end can be implemented via a web server 2715 that can utilize API calls (e.g., REST API 2716, etc.) to a computational framework such as a drill control framework 2714 that is operatively coupled to equipment of a wellsite system 2704.', 'The drill control framework 2714 can be, for example, a software product implemented using hardware that can output advisory actions to a driller or drillers.', 'For example, an action output by an agent may be transmitted to the drill control framework 2714 for rendering to a display where a driller can view the display and implement the action, which may be implemented using a manual approach, a semi-automated approach, or an automated approach.', 'For example, a manual approach can involve manual setting of equipment, a semi-automated approach can include interacting with a computerized controller, and an automated approach can include automatic implementation of an action via an automated controller.; FIG.', '27 also shows an example of a GUI 2706, which includes a plan trajectory, a current state, actions, a target and reward totals.', 'As explained, rewards can be utilized for training (see, e.g., the reward calculator 2615 of FIG.', '26).', 'In the example GUI 2706, reward values may be utilized for one or more other purposes.; FIG.', '28 shows an example of a sequence engine 2800.', 'As shown, the sequence engine 2800 can include one or more interfaces 2820, an agent access component 2840 and one or more other components 2860.', 'As shown, the sequence engine 2800 can be operatively coupled to a planning component or system 2812 and/or a control component or system 2814 (e.g., a drill control framework, etc.).', 'As an example, the one or more interfaces 2820 can be or include one or more application programming interfaces (APIs) where one or more calls may be made such that the sequence engine 2800 performs some action, which may be for purposes of planning and/or control.', 'As an example, a call may come from one or more of the planning component or system 2812 and the control component or system 2814.', 'As an example, a driller may utilize a computing device to make a call, which may return sequence information as to one or more of a mode or modes (e.g., sliding mode, rotating mode, etc.), toolface, survey point, etc.', 'As an example, a mode may include a combination of surface rotation and mud motor rotation.; FIG.', '29 shows an example of a method 2900 and an example of a system 2990.', 'As shown, the method 2900 includes a selection block 2910 for, via an agent component, selecting a drilling mode from a plurality of drilling modes to drill a portion of a borehole in a geologic environment according to a borehole trajectory; a generation block 2920 for, via a simulation component, generating a state of the borehole in the geologic environment by simulating drilling of the borehole using the selected drilling mode; a generation block 2930 for, via a reward component, generating a reward using the state and the planned borehole trajectory; and, a train block 2940 for, using the reward, training the agent component to generate a trained agent component that operates to maximize total future rewards via agent component-based drilling actions.', 'In such an example, the agent component can be an agent and the trained agent component can be a trained agent.; FIG.', '30 shows an example of a method 3000 and an example of a system 3090.', 'As shown, the method 3000 includes a reception block 3010 for receiving sensor data during drilling of a portion of a borehole in a geologic environment; a determination block 3020 for determining a drilling mode from a plurality of drilling modes using a trained neural network and at least a portion of the sensor data; and an issuance block 3030 for issuing a control instruction for drilling an additional portion of the borehole using the determined drilling mode.', '; FIG.', '31 shows an example of a system 3100 that can be a well construction ecosystem.', 'As shown, the system 3100 can include one or more instances of the sequence engine 2800 (SEQ Engine) and can include a rig infrastructure 3110 and a drill plan component 3120 that can generation or otherwise transmit information associated with a plan to be executed utilizing the rig infrastructure 3110, for example, via a drilling operations layer 3140, which includes a wellsite component 3142 and an offsite component 3144.', 'As shown, data acquired and/or generated by the drilling operations layer 3140 can be transmitted to a data archiving component 3150, which may be utilized, for example, for purposes of planning one or more operations (e.g., per the drilling plan component 3120).', '; FIG.', '33 shows components of a computing system 3300 and a networked system 3310.', 'The system 3300 includes one or more processors 3302, memory and/or storage components 3304, one or more input and/or output devices 3306 and a bus 3308.', 'According to an embodiment, instructions may be stored in one or more computer-readable media (e.g., memory/storage components 3304).', 'Such instructions may be read by one or more processors (e.g., the processor(s) 3302) via a communication bus (e.g., the bus 3308), which may be wired or wireless.', 'The one or more processors may execute such instructions to implement (wholly or in part) one or more attributes (e.g., as part of a method).', 'A user may view output from and interact with a process via an I/O device (e.g., the device 3306).', 'According to an embodiment, a computer-readable medium may be a storage component such as a physical memory storage device, for example, a chip, a chip on a package, a memory card, etc.']

US11930598

Three dimensional printed resistor for downhole applications

Dec 14, 2022

Swapna Arun Kumar, Srinand Karuppoor

Schlumberger Technology Corporation

Tan et al., A review of printed passive electronic components through fully additive manufacturing methods, Virtual and Physical Prototyping, vol. 11, Issue 4, pp. 1-18, Aug. 2016.; Office Action issued in U.S. Appl. No. 16/599,540 dated Jun. 24, 2020 (8 pages).; Office Action issued in U.S. Appl. No. 16/599,540 dated Jan. 12, 2021, 12 pages.; Office Action issued in U.S. Appl. No. 16/599,540 dated May 28, 2021, 11 pages.; Office Action issued in U.S. Appl. No. 16/599,540 dated Jan. 31, 2022, 10 pages.; Office Action issued in U.S. Appl. No. 16/599,554 dated Mar. 2, 2022, 29 pages.; Office Action issued in U.S. Appl. No. 16/599,540, dated Apr. 6, 2022, 12 pages.

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Foreign Citations not found.

['Aspects of the disclosure relate to apparatus and methods for producing a downhole electrical component, having steps of providing a non-conductive polymer substrate, establishing an active area on the non-conductive polymer substrate, patterning the active area on the non-conductive polymer substrate with a conductive material through an additive manufacturing process and incorporating the patterned non-conductive polymer substrate into a final arrangement.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE TO RELATED APPLICATIONS', 'The present application is a Divisional of U.S. application Ser.', 'No. 16/599,554, filed on Oct. 11, 2019, which is incorporated in its entirety by reference herein.\n \nSTATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR', 'DEVELOPMENT\n \nNone.\n \nFIELD OF THE DISCLOSURE\n \nAspects of the disclosure relate to electrical components.', 'More specifically, aspects of the disclosure relate to electrical components for downhole applications.', 'BACKGROUND INFORMATION\n \nComposite film resistors are manufactured with film material printed on a screen or deposited on a ceramic substrate.', 'A composite assembly is end terminated with an inner electrode and a plating material to facilitate assembly of the resistors on a printed circuit board.', 'Conventional film resistors are made from a conductive metal oxide paste.', 'Such conventional film resistors are satisfactory for low wattage values.', 'Other types of resistors are made from wire that is wound by specialized machines.', 'These specialized machines are made to prepare one type of resistor.', 'No capability of alterations to a pre-made resistor configuration may be made.', 'While the technology of creating these conventional apparatus is known, these types of resistors have several drawbacks.', 'Often, in the case of film resistors, these resistors fail at downhole conditions with exposure to high temperatures.', 'Downhole environments are also prone to producing high shocks for components placed in the environment.', 'Downhole environments may vary according to the location of a wellbore.', 'In some areas, geothermal hot spots exist, thus components must be able to be configured to resist these increased temperatures.', 'In some wellbores, localized overpressure conditions may exist, thus pressures may be higher within some wellbores than others.', 'As these environments can widely vary, designers for downhole components may specifically tailor a downhole electrical tool and/or components for the anticipated conditions.', 'Designing a downhole tool for an environmental condition much harsher than anticipated may be cost prohibitive as special precautions taken may be expensive to produce.', 'There is a need, therefore, to produce components such that changes may be incorporated into the component into a quick basis and minimizes the costs for production of the components.', 'Production of conventional circuit boards and devices also have a negative environmental impact.', 'Circuit boards are manufactured using multiple steps.', 'These steps include using chemicals with solvents and acids to create traces in board materials.', 'As the design becomes more complex, the amount of chemicals used increases, exposing manufacturers to regulations and environmental compliance concerns.', 'As reduction of the use of chemicals can be beneficial from an economic standpoint, there is a need to provide for production of electrical components without the need for the use of chemicals.', 'There is a need to produce electrical components such that the components are not only fit for a particular purpose but may also be altered at the direction of a designer to allow for varying capabilities of the electrical component produce.', 'There is a need to provide a three dimensional (3D) resistor that is capable of withstanding anticipated temperature and shock conditions of a downhole environment.', 'There is a further need to provide a method of making a three dimensional resistor that is capable of withstanding anticipated temperature and shock conditions of the downhole environment.', 'There is a still further need to provide an economical alternative to conventional resistor apparatus that allows for quick prototyping.', 'There is a still further need to provide a quickly scalable apparatus to more accurately tighten or loosen arrangements that are currently operated by manual closure methods.', 'There is a further need to provide a method and apparatus to close fluid end units that are safer for workers than conventional closure methods and apparatuses.', 'There is a further need to produce electrical components wherein such production minimizes impacts to the environment.', 'SUMMARY\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized below, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted that the drawings illustrate only typical embodiments of this disclosure, and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments without specific recitation.', 'Accordingly, the following summary provides just a few aspects of the description and should not be used to limit the described embodiments to a single concept.', 'In one embodiment, a method for producing a downhole electrical component is disclosed.', 'The method may comprise providing a non-conductive polymer substrate.', 'The method may also provide for establishing an active area on the non-conductive polymer substrate.', 'The method may also provide for patterning the active area on the non-conductive polymer substrate with a conductive material through an additive manufacturing process.', 'The method may also provide for incorporating the patterned non-conductive polymer substrate into a final arrangement.', 'In one non-limiting embodiment, an arrangement is disclosed.', 'The arrangement may comprise a substrate having at least two areas, wherein a first of the two areas is an active area and a second of the two areas is a passive area.', 'The arrangement may also comprise at least one resistive pattern placed in a surface of the active area, the at least one resistive pattern placed onto the substrate through an additive manufacturing process.', 'The arrangement may also comprise a first connection pad connected to the at least one resistive pattern placed in the surface of the active area.', 'The arrangement may also comprise a second connection pad connected to the at least one resistive pattern placed in the surface of the active area.', 'In another non-limiting embodiment, a method for producing a downhole electrical component is disclosed.', 'The method may comprise providing a non-conductive polymer substrate to a three dimensional printing apparatus and defining an active area on the non-conductive polymer substrate, wherein the active area is a portion of a surface of the non-conductive polymer substrate to receive a three dimensional printing.', 'The method may further comprise printing in the active area on the non-conductive polymer substrate with a conductive material to achieve a predesigned configuration in the active area of the non-conductive polymer substrate.', 'The method may further comprise incorporating the patterned non-conductive polymer substrate into a final arrangement.', 'Other aspects and advantages will become apparent from the following description and the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nSo that the manner in which the above recited features of the present disclosure can be understood in detail, a more particular description of the disclosure, briefly summarized above, may be had by reference to embodiments, some of which are illustrated in the drawings.', 'It is to be noted, however, that the appended drawings illustrate only typical embodiments of this disclosure and are therefore not to be considered limiting of its scope, for the disclosure may admit to other equally effective embodiments.\n \nFIG.', '1\n is a side perspective view of a three (3) dimensional printed resistor.\n \nFIG.', '2\n is a method of making a downhole electrical component in accordance with an example embodiment of the disclosure.\n \nFIG.', '3\n is a second method of making a downhole electrical component in accordance with one example embodiment of the disclosure.\n \nFIG.', '4\n is a film type resistor in accordance with an example embodiment of the disclosure.', 'To facilitate understanding, identical reference numerals have been used, where possible, to designate identical elements that are common to the figures (“FIGS”).', 'It is contemplated that elements disclosed in one embodiment may be beneficially utilized on other embodiments without specific recitation.', 'DETAILED DESCRIPTION', 'In the following, reference is made to embodiments of the disclosure.', 'It should be understood, however, that the disclosure is not limited to specific described embodiments.', 'Instead, any combination of the following features and elements, whether related to different embodiments or not, is contemplated to implement and practice the disclosure.', 'Furthermore, although embodiments of the disclosure may achieve advantages over other possible solutions and/or over the prior art, whether or not a particular advantage is achieved by a given embodiment is not limiting of the disclosure.', 'Thus, the following aspects, features, embodiments, and advantages are merely illustrative and are not considered elements or limitations of the claims except where explicitly recited in a claim.', 'Likewise, reference to “the disclosure” shall not be construed as a generalization of any inventive subject matter disclosed herein and shall not be considered to be an element or limitation of the claims except where explicitly recited in a claim.', 'Some embodiments will now be described with reference to the figures.', 'Like elements in the various figures will be referenced with like numbers for consistency.', 'In the following description, numerous details are set forth to provide an understanding of various embodiments and/or features.', 'It will be understood, however, by those skilled in the art, that some embodiments may be practiced without many of these details and that numerous variations or modifications from the described embodiments are possible.', 'As used herein, the terms “above” and “below”, “up” and “down”, “upper” and “lower”, “upwardly” and “downwardly”, and other like terms indicating relative positions above or below a given point are used in this description to more clearly describe certain embodiments.', 'Aspects of the disclosure relate to three (3) dimensional printing.', 'More specifically, aspects of the disclosure relate to creating electrical components using three dimensional printing to allow rapid prototyping of electrical components used in a downhole environment.', 'The three dimensional printing, commonly called additive manufacturing, can quickly replicate a design present in a design drawing.', 'The three dimensional printing may be quickly altered to allow for changes in the overall design to occur.', 'These changes can be, for example, creating a larger version of a design previously created.', 'In other non-limiting embodiments, a smaller version of a design may be created.', 'In still other embodiments, different materials may be used to create the traces within a substrate, thus altering the overall capability of the electrical component.', 'In one embodiment, a trace may use a conductive copper alloy on the substrate.', 'In other embodiments, a conductive silver alloy may be used on the substrate.', 'In a still further embodiment, a gold alloy may be used on the substrate.', 'In other embodiments, different traces may use different materials, thus silver may be used in some traces, while copper may be used within other traces.', 'Other alterations may be made to designs to impact the overall capability of a resistor.', 'In some embodiments, a specific trace may be expanded in scope or reduced in scope to decrease or increase the resistance of the resistor.', 'In still other embodiments, additional traces may be added to change the properties of the resistor.', 'The oil and gas industry has consistently tried to produce components that may withstand pressures, temperatures, shock and vibration regimes in the downhole environments that are encountered.', 'In some embodiments, the pressure that may be experienced by downhole components may exceed 30,000 pounds per square inch.', 'Temperatures may exceed 200° Celsius C. As these values may occur simultaneously, electrical components experiencing such values may either decrease in efficiency or stop functioning altogether.', 'Some electrical components used are related to safety devices to prevent environmental problems from occurring.', 'In some embodiments, electrical signals are used to trigger closure valves to “seal in” a well to prevent contents of the well from erupting.', 'Such functions are vital and must be performed in a consistent and reliable manner when required.', 'While conventionally made components can provide such functionality, such components are expensive to design and manufacture.', 'Embodiments of the disclosure herein provide an alternative method for producing electrical components that are configured to withstand the rigors of downhole environments.', 'Methods used for production of the components may be altered to provide for quick prototyping, reducing the time for production of components.', 'In some embodiments, film resistors may be made from a metal film.', 'Such metal film resistors may have better temperature stability than other conventional carbon based units.', 'Such metal film resistors may also have lower noise properties and may be used in high frequency applications.', 'In other embodiments, methods and apparatus produced are related to thick film resistors.', 'Such thick film resistors are manufactured by placing a conductive paste of ceramic and metal, called CERMET, onto a substrate.', 'In some embodiments, the substrate may be an alumina ceramic substrate.', 'Referring to \nFIG.', '1\n, a perspective view of a three (3) dimensional printed resistor \n100\n is illustrated.', 'In the illustrated embodiment, a substrate \n102\n is provided.', 'The substrate \n102\n is configured with a thickness \n106\n, a length \n108\n and a depth \n110\n.', 'The substrate, in one embodiment, is a non-conductive polymer and an active area is where a resistive pattern \n112\n is provided.', 'The substrate \n102\n can be a standalone material which could be then assembled on a conventional printed circuit board or a three (3) dimensional printed circuit board (PCB).', 'The resistive pattern \n112\n can be laid as a distributed pattern or clustered pattern to get the required resistance value while keeping parasitic losses to a minimum.', 'In the illustrated embodiment, the resistive pattern \n112\n is configured to extend from a first pad \n104\n or connection to a second pad \n114\n or connection.', 'The amount of the length of travel may depend upon the amount of resistance necessary for the resistor \n100\n.', 'In other embodiments, a second resistor may be located upon the same substrate \n102\n.', 'Thus, resistors may be placed in parallel to one another to achieve different resistances necessary for operation.', 'As will be understood, different materials may be used in creating each of the individual resistors.', 'As an example, the resistive pattern \n112\n in the first resistor may be constructed of copper, while a second resistive pattern may be made in silver.', 'In these embodiments, pads \n104\n, \n114\n may be shared between different resistors.', 'In other embodiments, each resistor \n100\n may be configured with a discrete starting pad and ending pad.', 'As will be understood by a person skilled in the art, the pads \n104\n, \n114\n may be configured to interface with a PCB (“printed circuit board”) that may house other electrical components.', 'In still other embodiments, while the resistive pattern \n112\n and pads \n104\n, \n114\n are located on a top surface \n120\n of the substrate \n102\n, other configurations may include providing a resistive pattern on a bottom surface \n122\n of the substrate \n102\n.', 'In such embodiments, additive manufacturing, three dimensional printing, may be used on both the top surface \n120\n and bottom surface \n122\n.', 'Such printing may be done sequentially or may be done in parallel, if fast production is necessary.', 'In some embodiments, powder bed fusion techniques (“PBF”) may be used.', 'In this type of additive manufacturing process, an array of materials may be used.', 'Geometrical complexity may be high.', 'For example, a resistor may be created upon a substrate in a complex fashion.', 'In some embodiments, selective laser sintering may be used, wherein a laser is used to melt a substrate or powder to a desired format.', 'In other embodiments, electron beam melting may be used to produce an additive manufacturing component.', 'In another non-limiting embodiment, a laminated object manufacturing technique may be used to both cut and join shapes together.', 'A 3D printed resistor for downhole applications will be designed to fit the application conditions (in terms of power requirements, value, size, tolerance) with ease of assembly (an integrated design or stand-alone).', 'The 3D printing is also configured to facilitate quick prototyping of the resistor to avoid long lead times experienced for conventional manufacturing.', 'Referring to \nFIG.', '2\n, a method \n200\n for producing a three dimensional printed resistor for downhole applications is illustrated.', 'At \n202\n, the method may provide for providing a non-conductive polymer substrate.', 'At \n204\n, the method may continue with establishing an active area on the non-conductive polymer substrate provided.', 'At \n206\n, the method may continue with patterning an active area using an additive manufacturing process.', 'At \n208\n, the method may proceed with incorporating the patterned substrate into a final arrangement.', 'The final arrangement may be, for example, a conventional printed circuit board or a 3D printed circuit board.', 'Referring to \nFIG.', '3\n, a second method \n300\n for producing a downhole electrical component is disclosed, comprising, at \n302\n, providing a non-conductive polymer substrate to a three dimensional printing apparatus.', 'The method may also provide, at \n304\n, for defining an active area on the non-conductive polymer substrate, wherein the active area is a portion of a surface of the non-conductive polymer substrate to receive a three dimensional printing.', 'The method may further provide, at \n306\n, for printing in the active area on the non-conductive polymer substrate with a conductive material to achieve a predesigned configuration in the active area of the non-conductive polymer substrate.', 'The method may also provide, at \n308\n, for incorporating the patterned non-conductive polymer substrate into a final arrangement.', 'In each method for \nFIG. \n2\n and \nFIG.', '3\n, the printed active area may rolled and encapsulated in an insulating material.', 'In these arrangements, a first pad \n104\n may be connected to a connecting lead.', 'In a furtherance of the arrangement, a second pad \n114\n may be connected to a different connecting lead as described below.', 'Referring to \nFIG.', '4\n, a film resistor \n400\n is illustrated wherein components of the resistor \n400\n may be constructed by additive manufacturing, three dimensional printing.', 'The film resistor \n400\n is configured with a first end \n402\n and a second end \n404\n.', 'The first end \n402\n and the second end \n404\n are connecting leads that are used to connect the resistor to other components of a electrical system, such as a PCB board.', 'The thin resistive film \n410\n produced by the methods in \nFIG.', '2\n or \nFIG.', '3\n is wound in a spiral groove \n408\n configuration such that a portion of the resistive pattern contacts both the first end \n402\n and the second end \n404\n.', 'An insulating material, such as a ceramic, may be spread over an exterior of the film resistor \n400\n, such that the only conductive portions of the film resistor \n400\n are the first end \n402\n and the second end \n404\n for connection to electrical apparatus.', 'The first step of development is to identify the requirements and develop the prototypes with known materials.', 'The prototype parts will be tested for the downhole conditions including high temperature as well as a shock test.', 'The second step is to identify the different material sets to improve the performance (for example, resistivity, power rating) and develop multiple prototypes.', 'In the embodiments illustrated, the methods and apparatus provide a three (3) dimensional printed resistor that is capable of withstanding anticipated temperature and shock conditions of a downhole environment.', 'This apparatus may withstand 30,000 psi and 200° C. By using additive manufacturing techniques, conventional film resistors may be replaced with newly designed resistors created by 3D printing.', 'By choosing the right material sets, designs can achieve the optimum precision and achieve a temperature coefficient of resistor (“RCE”) required for downhole applications.', 'Additive manufacturing facilities may use different thickness and depth of substrates, allowing for greater flexibility compared to conventional apparatus.', 'In other embodiments, the methods may provide an economical alternative to conventional resistor apparatus that allows for quick prototyping.', 'Excessive winding of materials that are commonplace in manufacturing of conventional resistors is avoided altogether.', 'As the manufacturing can be controlled by high precision computers and lasers, alterations to designs may be achieved with minimal delay.', 'Conventional resistor alterations require extensive mechanical reworking of machines used in the winding process.', 'As the production of components is quickly scalable, multiple production lines can be controlled through a single computer, rather than having multiple mechanical machines used in winding a single type of resistor.', 'There is a further need to produce electrical components, wherein such production minimizes impacts to the environment.', 'In an embodiment, a method for producing a downhole electrical component is disclosed.', 'The method may comprise providing a non-conductive polymer substrate, establishing an active area on the non-conductive polymer substrate, patterning the active area on the non-conductive polymer substrate with a conductive material through an additive manufacturing process, and incorporating the patterned non-conductive polymer substrate into a final arrangement.', 'In another embodiment, the method may be performed wherein the patterning the active area is performed as a distributed pattern.', 'In another embodiment, the method may be performed wherein the patterning the active area is performed as a clustered pattern.', 'In another embodiment, the method may be performed wherein the patterning the active area on the non-conductive polymer substrate includes creating at least two connection pads.', 'In another embodiment, the method may be performed wherein the final arrangement is a printed circuit board.', 'In another embodiment, the method may be performed wherein the final arrangement is a three dimensional printed circuit board.', 'In another embodiment, the method may be performed wherein the additive manufacturing process incorporates at least one powder bed fusion technique.', 'In another embodiment, the method may be performed wherein the additive manufacturing process incorporates a selective laser sintering.', 'In one embodiment, an arrangement is disclosed.', 'The arrangement may comprise a substrate having at least two areas, wherein a first of the two areas is an active area and a second of the two areas is a passive area.', 'The arrangement may also comprise at least one resistive pattern placed in a surface of the active area, the at least one resistive pattern placed onto the substrate through an additive manufacturing process.', 'The arrangement may also comprise a first connection pad connected to the at least one resistive pattern placed in the surface of the active area.', 'The arrangement may also comprise a second connection pad connected to the at least one resistive pattern placed in the surface of the active area.', 'In another embodiment, the arrangement may be configured wherein the resistive pattern is made of a pattern created with a metallic component one of on and within the substrate.', 'In a still further embodiment, the arrangement may be configured wherein the substrate is non-conductive polymer.', 'In another embodiment, the arrangement may be configured wherein the resistive pattern is a distributed pattern.', 'In another embodiment, the arrangement may be configured wherein the resistive pattern is a clustered pattern.', 'In another embodiment, a method for producing a downhole electrical component is disclosed.', 'The method may comprise providing a non-conductive polymer substrate to a three dimensional printing apparatus and defining an active area on the non-conductive polymer substrate, wherein the active area is a portion of a surface of the non-conductive polymer substrate to receive a three dimensional printing.', 'The method may further comprise printing in the active area on the non-conductive polymer substrate with a conductive material to achieve a predesigned configuration in the active area of the non-conductive polymer substrate.', 'The method may further comprise incorporating the patterned non-conductive polymer substrate into a final arrangement.', 'In another non-limiting embodiment, the method may be performed wherein the printing in the active area involves creating a distributed pattern.', 'In another non-limiting embodiment, the method may be performed wherein the printing in the active area involves creating a clustered pattern.', 'In another non-limiting embodiment, the method may be performed wherein the incorporating the patterned non-conductive polymer substrate into the final arrangement comprises winding the film resistor such that a first pad of the film resistor contacts a first end connecting lead, connecting a portion the first pad of the film resistor to the first end connecting lead and connecting a portion of a second pad of the film resistor to a second end connecting lead.', 'In another non-limiting embodiment, the method may further comprise coating at least a portion of the wound film resistor with an insulating material.', 'In another non-limiting embodiment, the method may further comprise marking an outside surface of the insulating material with a code signifying a resistance between the first end connecting lead and the second end connecting lead.', 'In another example embodiment, the method may further comprise curing the insulating material.', 'While embodiments have been described herein, those skilled in the art, having benefit of this disclosure, will appreciate that other embodiments are envisioned that do not depart from the inventive scope.', 'Accordingly, the scope of the present claims or any subsequent claims shall not be unduly limited by the description of the embodiments described herein.']

['1.', 'A method for producing a downhole electrical component, comprising:\nproviding a non-conductive polymer substrate;\nestablishing an active area on the non-conductive polymer substrate;\npatterning the active area on the non-conductive polymer substrate with one or more conductive materials through an additive manufacturing process to form a patterned non-conductive polymer substrate comprising a first resistive pattern, a second resistive pattern, a first connection pad, and a second connection pad, wherein a first end of each of the first and second resistive patterns is connected to the first connection pad and a second end of each of the first and second resistive patterns is connected to the second connection pad; and\nincorporating the patterned non-conductive polymer substrate into a final arrangement.', '2.', 'The method according to claim 1, wherein the patterning the active area is performed as a distributed pattern.', '3.', 'The method according to claim 1, wherein the patterning the active area is performed as a clustered pattern.', '4.', 'The method according to claim 1, wherein the final arrangement is a printed circuit board.', '5.', 'The method according to claim 1, wherein the final arrangement is a three dimensional printed circuit board.', '6.', 'The method according to claim 1, wherein the additive manufacturing process incorporates at least one powder bed fusion technique.', '7.', 'The method according to claim 1, wherein the additive manufacturing process incorporates a selective laser sintering.\n\n\n\n\n\n\n8.', 'A method for producing a downhole electrical component, comprising:\nproviding a non-conductive polymer substrate;\nestablishing an active area on the non-conductive polymer substrate;\npatterning the active area on the non-conductive polymer substrate with one or more conductive materials through an additive manufacturing process to form a patterned non-conductive polymer substrate comprising a first resistive pattern and a second resistive pattern, wherein the first resistive pattern is formed on a top of the non-conductive polymer substrate and the second resistive pattern is formed on a bottom of the non-conductive polymer substrate, and wherein the first and second resistive patterns are formed at the same time with respect to one another; and\nincorporating the patterned non-conductive polymer substrate into a final arrangement.', '9.', 'The method according to claim 8, wherein the first and second resistive patterns are formed from different conductive materials.', '10.', 'The method according to claim 8, wherein the first resistive pattern is formed from copper and the second resistive pattern is formed from silver.', '11.', 'The method according to claim 8, wherein the first and second resistive patterns are formed from a same conductive material.', '12.', 'The method according to claim 8, wherein the final arrangement is a three dimensional printed circuit board.', '13.', 'The method according to claim 8, further comprising spreading an insulating material over the first and second resistive patterns.\n\n\n\n\n\n\n14.', 'The method according to claim 13, further comprising curing the insulating material.', '15.', 'The method according to claim 1, wherein the first and second resistive patterns are formed from different conductive materials.', '16.', 'The method according to claim 1, wherein the first resistive pattern is formed from copper and the second resistive pattern is formed from silver.', '17.', 'The method according to claim 1, wherein the first and second resistive patterns are formed from a same conductive material.', '18.', 'The method according to claim 1, further comprising spreading an insulating material over the first and second resistive patterns.\n\n\n\n\n\n\n19.', 'The method according to claim 18, further comprising curing the insulating material.']

['FIG.', '1 is a side perspective view of a three (3) dimensional printed resistor.; FIG.', '2 is a method of making a downhole electrical component in accordance with an example embodiment of the disclosure.', '; FIG.', '3 is a second method of making a downhole electrical component in accordance with one example embodiment of the disclosure.', '; FIG.', '4 is a film type resistor in accordance with an example embodiment of the disclosure.']

US11668172

Remote manifold valve and pump pairing technique for a multi-pump system

Jul 21, 2016

Manuel Alfonso Bobadilla Larios, Nan Mu

Schlumberger Technology Corporation

International Search Report and Written Opinion issued in International Patent Appl. No. PCT/US2016/043217 dated Nov. 3, 2016; 14 pages.; International Search Report and Written Opinion issued in International Patent Appl. No. PCT/US2016/021336 dated Jun. 2, 2016; 18 pages.; Exam Report issued in Canadian Patent Application No. 2978910 dated Jun. 7, 2022, 5 pages.

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2013133874; September 2013; WO; 2014158806; October 2014; WO

['A technique for remote pairing of pumps and manifold valves at an oilfield.', 'The technique takes advantage of a control unit having remote capability of opening and closing manifold valves.', 'The control unit may also be in simultaneous communication with an individual sensor for each pump.', 'Thus, unique protocols of valve opening and closing at the manifold in conjunction with monitoring of fluid-based detections by the unit may be used to establish pairing between specific pumps and manifold valves.', 'Similarly, the system may also be inspected for leaks at particular locations through unique valve opening and closing sequences in conjunction with fluid monitoring.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE\n \nThe present document is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/195,104, filed Jul. 21, 2015, which is incorporated herein by reference in its entirety.', 'BACKGROUND\n \nExploring, drilling and completing hydrocarbon and other wells are generally complicated, time consuming and ultimately very expensive endeavors.', 'As a result, oilfield efforts are often largely focused on techniques for maximizing recovery from each and every well.', 'Whether the focus is on drilling, unique architecture, or step by step interventions directed at well fracturing, the techniques have become quite developed over the years.', 'One such operation at the well site directed at enhancing hydrocarbon recovery from the well is referred to as a stimulation application.', 'Generally, in conjunction with fracturing, a stimulation application is one in which a large amount of proppant, often a type of sand, is directed downhole at high pressure along with large volumes of water.', 'So, for example, downhole well perforations into a formation adjacent the well which have been formed by fracturing may be further opened and/or reinforced for sake of recovery therefrom.', 'For effectiveness, the slurry of proppant and water that is utilized during stimulation is often supplied downhole at considerable rates and pressures.', 'For example, it would not be uncommon for the slurry to be pumped at more than 60-1000 barrels per minute (BPM) at pressures exceeding 10,000 PSI.', 'Thus, in order to ensure that a sufficient volume, rate and pressure of the slurry is delivered during the stimulation application, a host of positive displacement pumps are often positioned at the oilfield for sake of driving the stimulation application.', 'Specifically, each one of several pumps may be fluidly linked to a manifold which coordinates the overall delivery of the slurry fluid downhole.', 'The manifold, often referred to as a “missile”, may be directly fluidly linked to each pump as well as mixer from which the slurry is obtained.', 'In this manner, the manifold may distribute the slurry to each pump from the mixer and then receive the slurry back from each pump at greater pressures for directing downhole for stimulation.', 'As a practical matter, the overall fluid linking between the manifold and each individual pump may become a bit complex.', 'For example, the manifold will often include ten different stations at which different valves are located for the linking.', 'More specifically, each station generally includes a high pressure intake valve for regulating the receipt of the high pressure fluid slurry from a given pump.', 'Once more, the same station also includes at least one low pressure outflow valve for regulating the delivery of the slurry from the mixer to the corresponding pump in the first place.', 'In fact, it is most likely that each station will include multiple low pressure outflow valves of this type.', 'Thus, the volume of slurry out of the manifold may be increased even though the outflow rate may be comparatively lower than that being supplied back to the manifold from the pumps.', 'Additionally, the extra low pressure outflow valve also allows for some added flexibility.', 'For example, in larger operations, one manifold may be linked to another via tubing running between outflow valves of adjacent manifolds.', 'Regardless the particular system setup, the end result is that a complex web of tubing generally ends up running between a variety of different pumps at the oilfield and one or more centrally located manifolds.', 'From an operator or personnel perspective, the result is a large worksite that includes a hazardous central high pressure manifold area with multitudes of tubing running in various directions to and from up to ten high pressure pumps or more.', 'This environment is particularly challenging for on-site personnel when, over the course of natural operations, there becomes the need to turn a valve at the manifold on or off, for example, to take a pump off-line for repair or for any other reason.', 'For example, in a conventional system, shutting off any valve requires that personnel manually access the valve within the hazardous high pressure zone around the manifold.', 'Furthermore, as noted, a morass of tubing may be found running to and from the manifold to various pumps.', 'Thus, properly identifying and reaching the appropriate station and valve location on the manifold for a given pump may be a challenge in and of itself.', 'This may be particularly true over time where different pumps have been brought on and off line over the course of natural operations.', 'Ultimately, the scene around the manifold may look more like the back of an old home stereo system than an organized worksite of readily traceable tubings between pumps and manifold station locations.', 'Over the years, efforts have been undertaken to reduce the complexity and improve safety for the personnel which may need to access the valves at the manifold as described.', 'For example, in addition to enhanced focus on labeling and tracing of different tubing between each pump and station location at the manifold, some systems now include a pneumatically controlled manifold that allows the valves to be remotely open or closed.', 'Thus, personnel need not directly interface with each valve right at the hazardous location of the manifold.', 'Unfortunately, however, remotely turning manifold valves on or off does not fully address the matter.', 'Specifically, there remains the complexity associated with turning the correct valve on or off.', 'For example, where a pump is to be taken off line but an improper, non-corresponding, high pressure valve at the manifold is misidentified for turning off, the result may be catastrophic.', 'That is, this mis-pairing could result in the pump actually linked to the valve continuing to pump at very high pressures against a now closed valve.', 'A potentially resulting blowout would likely be hazardous beyond the immediate vicinity of the manifold and certainly result in substantial equipment damage and a costly shutdown of operations.', 'SUMMARY\n \nA method of remotely pairing high and low pressure valves at a manifold with individual pumps of a multi-pump system at an oilfield.', 'The method includes opening all high pressure valves of the manifold and then sequentially opening low pressure valves at the manifold, one-by-one.', 'Thus, as a responsive fluid-based detection, such as fluid flow, presents in a pump of the multi-pump system, it may be recorded as identifying a pairing between that pump and the correspondingly opened low pressure valve.', 'Once the low pressure valves and pumps are paired, the valves may again be closed and this same type of fluid-based detection sequence applied to high pressure valves one-by-one at the manifold in relation to the individual pumps.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a schematic overview depiction of stimulation system at an oilfield employing an embodiment of a pairing technique for pumps and a manifold thereof.\n \nFIG.', '2\n is a side view of the manifold of \nFIG.', '1\n with stations accommodating valve locations for pairing with the pumps of \nFIG.', '1\n.', 'FIG.', '3\nA\n is an enlarged side view of a pump of \nFIG.', '1\n for circulating a stimulation slurry from the manifold and back thereto at an increased pressure.', 'FIG.', '3\nB\n is an enlarged cross-sectional view of a portion of the pump of \nFIG.', '3\nA\n revealing a sensor therein for the pairing technique of \nFIG.', '1\n.', 'FIG.', '4\nA\n is a flow-chart summarizing an embodiment of a leak-detection technique for pump evaluation and subsequent paring.\n \nFIG.', '4\nB\n is a flow-chart summarizing an embodiment of utilizing a paring technique to identify pump and valve location couplings for the system of \nFIG.', '1\n.', 'FIG.', '5\n is a schematic overview depiction of the system at the oilfield of \nFIG.', '1\n in operation after employing a pairing technique for a stimulation application.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of the present disclosure.', 'However, it will be understood by those skilled in the art that the embodiments described may be practiced without these particular details.', 'Further, numerous variations or modifications may be employed which remain contemplated by the embodiments as specifically described.', 'Embodiments are described with reference to certain embodiments of stimulation operations at an oilfield.', 'Specifically, pumps, a manifold and other equipment are referenced for taking advantage of pairing techniques for performing stimulation applications.', 'However, other types of operations may benefit from the embodiments of pairing techniques detailed herein.', 'For example, such techniques may be employed for supporting fracturing or other related downhole operations supported by multiple high pressure pumps.', 'Indeed, so long as pairing techniques are utilized which allow for both manually remote and substantially assured pairing between valve locations at the manifold and specific pumps, appreciable benefit may be realized.', 'Referring now to \nFIG.', '1\n, a schematic overview depiction of stimulation system \n100\n is shown at an oilfield \n175\n.', 'As described further herein, the system \n100\n employs an embodiment of a pairing technique for a plurality of different pumps \n140\n-\n149\n and a manifold \n160\n.', 'That is, each pump \n140\n-\n149\n may be independently hooked up to the manifold \n160\n in a hydraulic fashion.', 'More specifically, with added reference to \nFIG.', '2\n, the manifold \n160\n may be outfitted with a plurality of different stations \n230\n-\n234\n, whereat hydraulic lines running to and from each pump \n140\n-\n149\n may be secured.', 'Thus, “pairing” or identifying which pump \n140\n-\n149\n is hydraulically coupled to which station \n230\n-\n234\n may be of substantial benefit, for example when a pump \n140\n-\n149\n is to be disconnected from the system \n100\n.', 'That is, in this example, proper pairing would allow for closure of the appropriate valve at the appropriate station \n230\n-\n234\n to maintain integrity of the system \n100\n while the corresponding pump \n140\n-\n149\n is taken off line.', 'As depicted, the pumps \n140\n-\n149\n are each part of a mobile pump truck unit.', 'Thus, once properly disconnected, a pump \n140\n-\n149\n may be driven away and perhaps replaced by another such mobile pump if necessary.', 'As indicated, the embodiment of \nFIG.', '1\n illustrates a typical layout for a stimulation or hydraulic fracturing system \n100\n at an oilfield \n175\n.', 'Apart from the unique pairing techniques referenced above and detailed further below, the system \n100\n includes common equipment for such operations.', 'Specifically, a mixer \n122\n is provided that supplies a low pressure slurry to the manifold \n160\n for eventual use in a stimulation application in the well \n180\n.', 'In the embodiment shown, the well \n180\n is outfitted with casing \n185\n and may have been previously perforated and now ripe for stimulation.', 'Regardless, the slurry is initially provided to the manifold \n160\n over a line \n128\n at comparatively low pressure, generally below about 100 PSI.', 'However, for sake of the application, the slurry will be pressurized by the pumps \n140\n-\n149\n before being returned to the manifold \n160\n at high pressure, for the application.', 'Specifically, pressures of between about 7,500 PSI and 15,000 PSI or more may be seen at the line \n165\n running to the well \n180\n for the stimulation application.', 'The mixer \n122\n is used to combine separate slurry components.', 'Specifically, water from tanks \n121\n is combined with proppant from a proppant truck \n125\n.', 'The proppant may be sand of particular size and other specified characteristics for the application.', 'Additionally, other material additives may be combined with the slurry such as gel materials from a gel tank \n120\n.', 'From an operators perspective, this mixing, as well as operation of the pumps \n140\n-\n149\n, manifold \n160\n and other system equipment may be regulated from a control unit \n110\n having suitable processing and electronic control over such equipment.', 'Indeed, as detailed further below, the control unit \n110\n may be outfitted with a capacity for remotely opening and closing the valves of the manifold \n160\n as needed, for example, when putting a pump \n140\n-\n149\n on or off-line.', 'Continuing with reference to \nFIG.', '1\n, for a variety of reasons, the physical hydraulic linkages \n130\n-\n139\n between the pumps \n140\n-\n149\n and the manifold \n160\n may be a bit of a complex web.', 'For example, the hydraulic hookup between each pump \n140\n-\n149\n and the manifold \n160\n involves separate lines running to each pump \n140\n-\n149\n from the manifold \n160\n as well as lines running from each pump \n140\n-\n149\n and back to the manifold \n160\n.', 'This is because, as noted above, low pressure “slurry” fluid that is supplied to the manifold \n160\n from the mixer \n122\n is initially routed to the pumps \n140\n-\n149\n for pressurization.', 'The slurry is then routed back to the manifold \n160\n under much greater pressures for delivery to the well \n180\n as part of the noted stimulation application.', 'Once more, as described below, the low pressure slurry that is provided to each pump \n140\n-\n149\n may generally be routed from more than one low pressure location at each given station \n230\n-\n234\n (e.g. see \n260\n, \n270\n of \nFIG.', '2\n).', 'In fact, with further added reference to \nFIG.', '2\n, there is generally no particular requirement that a given pump \n140\n-\n149\n utilize the same station \n230\n-\n234\n for both its low pressure and high pressure hydraulic hookups.', 'Continuing with reference to \nFIG.', '1\n, for ease of illustration, the physical hydraulic linkages between the pumps \n140\n-\n149\n and the manifold \n160\n are depicted as sets of arrows \n130\n-\n139\n running toward and away from each pump.', 'Specifically, an arrow running toward a given pump \n140\n-\n149\n represents a low pressure hookup for slurry in need of pressurization.', 'Alternatively, an arrow running away from this pump \n140\n-\n149\n represents a high pressure hookup for slurry ready to be delivered to the well \n180\n from the manifold \n160\n.', 'However, while these physical hydraulic linkages \n130\n-\n139\n are depicted in a simplified manner for sake of illustration at \nFIG.', '1\n, the reality is that these linkages \n130\n-\n139\n may constitute a complex web of lines running about the oilfield \n175\n as noted above.', 'As a result, even setting aside potential safety issues, the ability to manually trace lines from each pump \n140\n-\n149\n to specific manifold locations may not be practical, particularly in terms of the amount of time that might be required.', 'Thus, the reliable pairing techniques detailed herein may be of substantial benefit.', 'Pairing a given pump \n140\n-\n149\n with a particular high or low pressure manifold location may take less than about \n5\n minutes through the techniques detailed herein.', 'As detailed further below, this is due to real-time pressure and/or flow information regarding each individual pump \n140\n-\n149\n being made available to the control unit \n110\n in combination with remote control over valves at the manifold \n160\n.', 'This allows for unique sequences of valve control to be exercised in combination with operating individual pumps \n140\n-\n149\n in order to remotely gamer pairing information.', 'Indeed, as also detailed below, specific sequencing of valve control may also be utilized for sake of leak detection in advance of pairing determinations.', 'Referring now to \nFIG.', '2\n, a side view of the manifold \n160\n of \nFIG.', '1\n is shown.', 'From this vantage point, five stations \n230\n-\n234\n, of the ten total, are visible with the other five being at the opposite side of the manifold \n160\n (e.g. see \nFIG.', '5\n).', 'Ideally, the rear station \n230\n would align with the first pump \n140\n and linkages \n130\n at the oilfield \n175\n of \nFIG.', '1\n.', 'Similarly, the fifth, foremost station \n234\n would align with the fifth pump \n144\n and linkages \n134\n as shown at the oilfield \n175\n.', 'However, as detailed above, this is not always the case.', 'Thus, a unique remote pairing technique may be undertaken to ascertain exactly which stations \n230\n-\n234\n and valve locations \n260\n-\n264\n, \n270\n-\n274\n, \n280\n-\n284\n are truly linked to which pumps \n140\n-\n149\n.', 'This pairing information may be stored at the control unit \n110\n and called upon as needed, for example, as pumps \n140\n-\n149\n are removed or added to the system \n100\n.', 'Apart from bleed-off devices \n290\n-\n294\n and other features, as alluded to above, each station \n230\n-\n234\n may include a few different valve locations \n260\n-\n264\n, \n270\n-\n274\n, \n280\n-\n284\n for hydraulic communication with the pumps \n140\n-\n149\n of \nFIG.', '1\n.', 'Specifically, each station \n230\n-\n234\n includes a high pressure valve location \n280\n-\n284\n.', 'These locations directly couple a high pressure valve of the manifold \n160\n with the pressurized slurry from a pump \n140\n-\n149\n at the oilfield \n175\n of \nFIG.', '1\n.', 'Thus, the manifold \n160\n may be filled with pressurized slurry for a stimulation application as described above.', 'However, in the embodiment shown, each station \n230\n-\n234\n is also outfitted with multiple low pressure valve locations \n260\n-\n264\n and \n270\n-\n274\n.', 'Each of these valve locations are equipped to couple a low pressure valve of the manifold \n160\n with a pump \n140\n-\n149\n to supply low pressure slurry thereto.', 'By convention, the low pressure valve locations \n270\n-\n274\n at the bottom portion of the stations \n230\n-\n234\n are more likely to be utilized.', 'However, this is not required.', 'For example, upper low pressure valve locations \n260\n-\n264\n may be utilized when a bottom valve location \n270\n-\n274\n is defective, occupied by hydraulic linkup to another manifold, or for a variety of other reasons.', 'Regardless the particulars, the presence of multiple low pressure valve locations \n260\n-\n264\n, \n270\n-\n274\n at each station \n230\n-\n234\n adds to the sophisticated nature of the pairing between the pumps \n140\n-\n149\n and the manifold \n160\n.', 'In spite of the potential complexity of the myriad of potential hydraulic hookups between the pumps \n140\n-\n149\n and the manifold stations \n230\n-\n234\n, in the embodiments of \nFIGS. \n1\n and \n2\n, each pump \n140\n-\n149\n is outfitted with a sensor.', 'Specifically, as shown in \nFIG. \n3\nB\n, detailed below, each pump \n140\n-\n149\n is outfitted with a sensor \n340\n which provides real-time information to the control unit \n110\n.', 'Specifically, fluid flow within each pump \n140\n-\n149\n may be tracked in combination with information regarding open and closed valves at each station \n230\n-\n234\n of the manifold.', 'That is, as detailed further below, unique sequences of remote valve opening and closing in combination with fluid monitoring may be engaged in by the control unit \n110\n to attain and store pairing information.', 'Of course, fluid flow may be measured a host of other ways from different locations including with combined readings, for example, from a flowmeter of the mixer \n122\n combined with a pressure transducer at each pump \n140\n-\n149\n (see \nFIG.', '1\n).', 'Referring now to \nFIGS.', '3\nA and \n3\nB\n, with added reference to \nFIGS.', '1\n and \n2\n, the operation of a pump \n140\n is described.', 'Specifically, \nFIG.', '3\nA\n depicts an enlarged side view of a pump \n140\n of \nFIG.', '1\n.', 'As detailed above, the pump \n140\n is configured for circulating a stimulation slurry from the manifold \n160\n and back thereto at an increased pressure.', 'FIG.', '3\nB\n is an enlarged cross-sectional view of a portion of the pump of \nFIG.', '3\nA\n revealing the noted sensor \n340\n therein.', 'As indicated above, this sensor \n340\n, in combination with opening and closing of valve locations \n260\n-\n264\n, \n270\n-\n274\n, \n280\n-\n284\n may be utilized to carry out embodiments of pairing techniques.', 'Continuing with particular reference to \nFIG.', '3\nA\n, the pump \n140\n is a positive displacement pump fully capable of generating sufficient pressure for a stimulation or fracturing application.', 'For example, as noted above, the pump \n140\n may take a stimulation slurry from the manifold \n160\n at a pressure of less than about 100 PSI up to 7,500 PSI or more on route back to the manifold \n160\n for the application.', 'This is achieved by routing the low pressure slurry to a fluid housing \n367\n of the pump \n140\n for pressurization.', 'Specifically, an engine \n325\n of the pump \n140\n may power a driveline mechanism \n375\n to rotate a crankshaft \n365\n and effect the pressure increase in the adjacent fluid housing \n367\n.', 'With additional reference to \nFIG.', '3\nB\n, the pressure increase in the fluid housing \n367\n may translate to an increased flow rate detected by a sensor \n340\n during operation of the system.', 'Specifically, as low pressure slurry moves past an intake valve \n355\n and into the housing \n367\n it is pressurized via a plunger \n379\n of the driveline mechanism \n375\n.', 'Thus, as the pressurized fluid moves past an outlet valve \n350\n and into the space \n345\n for return to the manifold \n160\n, fluid flow may be detected by the noted sensor \n340\n.', 'As shown in the embodiments of \nFIGS.', '3\nA and \n3\nB\n, this space \n345\n is in communication with a discharge pipe \n330\n back to a high pressure valve location \n280\n-\n284\n of one of the stations \n230\n-\n234\n of the manifold \n160\n.', 'Thus, fluid flow detected from this space \n345\n via the sensor \n340\n may be interpreted by the control unit \n110\n of \nFIG.', '1\n in combination with valve information at the stations \n230\n-\n234\n to establish pairing as detailed below.', 'Referring now to \nFIGS.', '4\nA and \n4\nB\n, with added reference to \nFIG.', '1\n, flow-charts summarizing embodiments of leak detection and paring technique to identify pump and valve location couplings for the system of \nFIG.', '1\n are shown.', 'As alluded to above, the techniques involve utilizing the control unit \n110\n to monitor the presence or absence of pump fluid flow while opening and closing valve locations at the manifold \n160\n.', 'Thus, it is not only possible to ensure that there are no leaks in the system \n100\n but indeed, checking for leaks may help to ensure proper pairing between each pumps \n140\n-\n149\n and the appropriate high pressure valve locations.', 'With specific reference to \nFIG.', '4\nA\n, in order to begin both leak detection and pairing, the pumps \n140\n-\n149\n as well as the overall lines or linkages (e.g. \n130\n-\n139\n) may be primed, though this may not be essential.', 'In one embodiment, a circulating fluid flow corresponding to about 8-10 bpm at more than about 60 PSI may be seen in this regard.', 'The high pressure valve locations may be closed at the manifold \n160\n as indicated at \n420\n with the sensor at each pump \n140\n-\n149\n being monitored by the control unit \n110\n.', 'In this way, if a substantial pressure drop is detected at one of the pumps \n140\n-\n149\n as indicated at \n430\n, the pump \n140\n-\n149\n operations may be temporarily aborted to address the issue at the outset.', 'However, for the pumps \n140\n-\n149\n where no substantial fluid flow is detected as noted at \n440\n, the leak check may continue on the low pressure side of things.', 'Specifically, as indicated at \n445\n, all low pressure valve locations may be closed at the manifold \n160\n.', 'With all of the high pressure valve locations already closed as noted above, this means that the detection of a substantial fluid flow at any of the pumps \n140\n-\n149\n now is a result of a leak at the low pressure side.', 'This may result in taking immediate remedial measures or in recording the leak and allowing continued flow therethrough as desired until a later time.', 'Referring specifically now to \nFIG.', '4\nB\n, with added reference to \nFIG.', '4\nA\n, with all pumps \n140\n-\n149\n and linkages \n130\n-\n139\n to the manifold \n160\n now considered “leak-free”, pairing may now take place in a reliable manner.', 'Specifically, for all remaining pumps \n140\n-\n149\n that did not display a substantial fluid flow as indicated at \n460\n, pairing begins by opening all high pressure valves and then sequentially opening all low pressure valve locations one-by-one as indicated at \n465\n.', 'Thus, when a given pump displays a corresponding fluid flow in response to a low pressure valve opening as noted at \n465\n, it may be recorded as paired thereto (see \n470\n).', 'Further, as each low pressure valve location is paired and recorded as such, they may be closed as indicated at \n472\n for sake of subsequent pairings.', 'As indicated, in one embodiment, sensor detection may be configured to account for fluid flow as indicative of pairing.', 'Though, other forms of fluid-based detections may also be utilized.', 'Regardless, this process may proceed until each pump \n140\n-\n149\n is assigned or paired with a particular low pressure valve location at the manifold \n160\n.', 'With all valves of the manifold \n160\n closed, the low pressure valves may be temporarily opened to trap fluid within each pump sufficient for subsequent detections (see \n474\n).', 'Specifically, the high pressure valve locations may now be opened sequentially, one-by-one as indicated at \n475\n.', 'Thus, each pump that displays a corresponding fluid-based detection from trapped fluid, in response to a high pressure valve opening may be recorded as paired thereto (see \n480\n).', 'Again, in this embodiment, the fluid-based detection may be one of fluid flow.', 'However, other types of fluid detections are again possible.', 'Regardless, all of the pairings between pumps \n140\n-\n149\n and the particular valve locations at the manifold \n160\n may now be complete.', 'Once pairing is complete, there may still be a desire to add additional pumps to the overall system \n100\n (see \nFIG.', '1\n).', 'While this pairing may not be as complex given that the pumps being added are likely comparatively fewer in number than those already in operation at the system \n100\n, verifying pairing information for these pumps may still be valuable and relatively straight forward.', 'For example, the high pressure and low pressure valve locations for all of the already known pairings of the other pumps may be closed off and removed from the pairing process.', 'Then, as to the remaining unverified new pairings to be confirmed, the pairing process may begin anew as indicated at \n465\n, by sequentially opening low pressure valve locations one-by-one (e.g. for the unverified low pressure valve locations only).', 'The process may then continue as indicated at \n470\n-\n480\n as applied to the remaining unverified valve locations as well in order to complete the pairing process.', 'Of course, added levels of sophistication may also be brought to bear on the techniques detailed above.', 'For example, as described above, the stations of the manifold \n160\n may be equipped with multiple low pressure valve locations \n260\n-\n264\n, \n270\n-\n274\n as depicted at \nFIG.', '2\n.', 'Thus, as a time saving, optimization measure, the pairing that begins by sequentially opening the low pressure valve locations as indicated at \n465\n may be preceded by a step as shown at \n462\n that divides these valve locations into their respective groups (i.e. the upper low pressure valves \n260\n-\n264\n and the bottom low pressure valves \n270\n-\n274\n).', 'More specifically, before checking each low pressure valve location sequentially on an individual basis, the upper low pressure valves \n260\n may all simultaneously be opened by the control unit \n110\n of \nFIG.', '1\n (see \n463\n).', 'If, as is often the case, no fluid-based detection changes are induced at any of the pumps \n140\n-\n149\n because none of the upper low pressure valves \n260\n-\n264\n are actually being utilized by the pumps \n140\n-\n149\n, then these valves may be closed and no sequential opening for sake of pairing need be undertaken (see \n464\n).', 'Instead, sequential opening of the bottom low pressure valves \n270\n-\n274\n may take place as indicated at \n465\n followed by recording the resultant pairing as indicated at \n470\n.', 'The above described concept of dividing the low pressure valve locations \n260\n-\n264\n, \n270\n-\n274\n into separate groupings for sake of time savings may be taken further, where more than one manifold \n160\n is utilized.', 'For example, in many cases a manifold \n160\n as shown at \nFIGS. \n1\n and \n2\n may be linked to one or more additional manifolds in a daisy chain fashion.', 'This is generally achieved by hydraulically linking a low pressure valve of one manifold to that of another.', 'Regardless, in advance of paring by sequentially opening low pressure valve locations as indicated at \n465\n, the low pressure valve locations \n260\n-\n264\n, \n270\n-\n274\n of each manifold may be divided before pairing.', 'Specifically, all of the upper low pressure valves \n260\n-\n264\n of one manifold may be simultaneously opened.', 'If no fluid-based detection changes result at any of the pumps \n140\n-\n149\n, these valves may be closed off with no further pairing steps applied thereto.', 'Indeed, this same procedure may be repeated at each manifold before any pairing takes place.', 'Thus, the operator may be able to effectively eliminate half of the low pressure valves from actually being checked for pairing.', 'As a result, a considerable amount of time may be saved over the course of the pairing process.', 'Referring now to \nFIG.', '5\n, a schematic overview depiction of the system \n100\n at the oilfield \n175\n of \nFIG.', '1\n is shown in operation after employing a pairing technique for a stimulation application.', 'In this depiction, the other side of the manifold \n160\n is shown in contrast to the side visible in \nFIG.', '2\n.', 'Thus, the other stations \n535\n-\n539\n are apparent.', 'Therefore, an additional five more pumps may be coupled to the manifold \n160\n.', 'In the embodiment shown, the pressurized slurry from the manifold \n160\n is directed over the line \n165\n running to the well \n180\n.', 'The well \n180\n traverses various formation layers \n190\n, \n590\n, \n595\n.', 'However, due to prior perforating or other well architecture, the application may be directed at a particular region \n575\n to encourage hydrocarbon production therefrom.', 'Regardless, with a control unit \n110\n available for both remotely opening and closing all of the valves at the stations \n535\n-\n539\n (and \n230\n-\n234\n of \nFIG.', '2\n) and correspondingly tracking pump fluid-flow detections, pairing may be achieved as depicted in \nFIG.', '4\nB\n.', 'As a result, a safe and efficient stimulation application may be run as depicted in \nFIG.', '5\n.', 'Embodiments described above take more complete advantage of the possibility of remotely turning manifold valves off or on.', 'Specifically, in addition to merely removing personnel from the immediate vicinity of hazardously pressurized manifolds in order to tum valves off or on, operators are substantially assured of which particular valves are to be properly turned off or on.', 'So, for example, where a pump is to be put on or taken off line, operators are assured as to which particular valves of the manifold are to be correspondingly opened or closed.', 'In this manner, hazards such as leaving a high pressure pump operating against an erroneously closed manifold valve may be avoided.', 'This is achieved through use of the remote pairing techniques detailed herein.', 'The preceding description has been presented with reference to presently preferred embodiments.', 'Persons skilled in the art and technology to which these embodiments pertain will appreciate that alterations and changes in the described structures and methods of operation may be practiced without meaningfully departing from the principle, and scope of these embodiments.', 'For example, while a specifically located sensor is referenced herein for acquiring fluid flow readings, the sensor may be positioned in other locations or a different sensor type utilized.', 'Specifically, a flow meter, water transducer, suction pressure sensor or different type of pressure sensor may be utilized.', 'Furthermore, as a matter of practicality, while the pairing techniques detailed hereinabove may take place while pumps are in an idle state, this is not necessarily required.', 'Along these lines, the foregoing description should not be read as pertaining only to the precise structures and techniques described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.']

['1.', 'A method of remotely pairing high pressure valves and low pressure valves at a manifold with pumps of a multi-pump system circulating a slurry at an oilfield, the method comprising:\nremotely opening all high pressure valves of the manifold;\nafter opening all the high pressure valves, sequentially remotely opening low pressure valves at the manifold including: simultaneously opening a selected number of multiple low pressure valves at the manifold after closing all valves and before opening a given low pressure valve, the selected number of the multiple low pressure valves being fewer than a total of the low pressure valves at the manifold; confirming an absence of any responsive pressure increase in any pump of the multi-pump system; and upon confirming the absence of any responsive pressure increase in any pump of the multi-pump system, removing the selected number of the multiple low pressure valves from consideration as remaining low pressure valves for pairing, thereby reducing a time to remotely pair the valves of the multi-pump system;\nidentifying a responsive fluid-based detection in a pump of the multi-pump system via at least one sensor located to monitor for a dedicated fluid flow to the pump upon opening the given low pressure valve, the dedicated fluid flow indicating fluid flowing directly from the given low pressure valve to the identified pump rather than to other pumps of the multi-pump system, thus establishing a pairing between the given low pressure valve and the identified pump;\nidentifying responsive fluid-based detections at remaining pumps of the multi-pump system to identify individual pairings between the remaining low pressure valves and pumps; and\nrecording the pairing between each of the identified pumps and the each of the given low pressure valves at a control unit at the oilfield, the pairing enabling each of the pumps to be individually and remotely connected to the multi-pump system by opening the paired valves and pumps, wherein the recorded pairing enables the control unit to close the appropriate paired valves when disconnecting a pump from the multi-pump system when the multi-pump system is operating, thereby maintaining operational integrity of the operating multi-pump system by enabling the multi-pump system to remain operational while the pump is being disconnected from the multi-pump system.', '2.', 'The method of claim 1 wherein maintaining comprises ensuring that a pump is not operating against an erroneously closed valve.', '3.', 'The method of claim 1 wherein the multiple low pressure valves are about half of the low pressure valves at the manifold.', '4.', 'The method of claim 3 wherein the manifold comprises stations each having a high pressure valve and two low pressure valves, the multiple low pressure valves comprising one of the two low pressure valves from each of the stations.', '5.', 'The method of claim 1 further comprising:\nclosing all valves at the manifold;\nopening a selected one of the high pressure valves at the manifold;\nidentifying a responsive fluid-based detection in a pump of the multi-pump system; and\nrecording the identifying of the detection as a pairing between the pump and the selected opened high pressure valve at the control unit at the oilfield.', '6.', 'The method of claim 5 further comprising sequentially opening remaining high pressure valves at the manifold and identifying responsive fluid-based detections at remaining pumps of the multi-pump system to identify individual pairings between the remaining high pressure valves and pumps, the identified individual pairings between the high pressure valves and pumps recorded at the control unit.', '7.', 'The method of claim 6 further comprising performing an application in a well at the oilfield with the slurry.', '8.', 'The method of claim 7 wherein the application is one of a stimulation application and a fracturing application.', '9.', 'The method of claim 7 further comprising:\nemploying the control unit to close identified high pressure and low pressure valves at the manifold; and\ntaking a given pump of the multi-pump system off-line from the application, the given pump identified by the control unit as paired to the identified high pressure and low pressure valves.', '10.', 'The method of claim 7 further comprising:\nadding another pump to the multi-pump system for the application, the adding including hydraulically coupling the added pump to additional high pressure and low pressure valves at the manifold; and\nverifying pairing between the additional high pressure and low pressure valves at the manifold to the added pump, the verifying accounting for the identified individual pairings recorded at the control unit.', '11.', 'A multi-pump manifold system for circulating a slurry at an oilfield, the system comprising:\na manifold for obtaining a slurry;\na plurality of pumps hydraulically coupled to low pressure valves at the manifold for obtaining low pressure slurry therefrom, the pumps hydraulically coupled to high pressure valves at the manifold for returning high pressure slurry to the manifold;\na control unit coupled to the manifold for directing opening and closing of the high and low pressure valves thereat, the control unit communicatively coupled to each of the plurality of pumps for obtaining fluid-based information therefrom; and\na processor of the control unit for pairing each of the plurality of the pumps to individual high and low pressure valves at the manifold based on fluid-based information obtained from a plurality of sensors positioned to monitor whether fluid flow occurs during the opening and closing of the valves by the control unit, the pairing being determined upon receiving data from individual sensors of the plurality of sensors indicating a dedicated flow from a specific low pressure valve of the low pressure valves to a specific pump of the plurality of pumps rather than to other pumps of the plurality of pumps, thus establishing and recording a pairing between the specific low pressure valve and the specific pump, the pairing enabling each of the pumps to be remotely connected to the multi-pump manifold system by opening the appropriate recorded paired valves associated with the appropriate pumps, wherein the recorded pairing enables the control unit to close the appropriate paired valves when disconnecting a first pump from the multi-pump manifold system when the multi-pump manifold system is operating, thereby maintaining operational integrity of the operating multi-pump system by enabling the remaining pumps of multi-pump system to remain operational while the first pump is being disconnected from the multi-pump system; wherein monitoring whether fluid flow occurs during the opening and closing of the valves by the control unit comprises: simultaneously opening a selected number of multiple low pressure valves after closing all valves and before opening the specific low pressure valve, the selected number of the multiple low pressure valves being fewer than a total of the low pressure; confirming an absence of any responsive pressure increase in any pump of the multi-pump system; and upon confirming the absence of any responsive pressure increase in any pump of the multi-pump system, removing the selected number of the multiple low pressure valves from consideration as remaining low pressure valves for pairing, thereby reducing a time to remotely pair the valves of the multi-pump system.\n\n\n\n\n\n\n12.', 'The system of claim 11 wherein the processor is further configured to determine leak information based on fluid flow information obtained during the opening and closing of the valves by the control unit.', '13.', 'The system of claim 11 further comprising one of a flowmeter, a water transducer and a suction pressure sensor disposed within each pump of the plurality to provide the fluid-based information.\n\n\n\n\n\n\n14.', 'The system of claim 11 wherein the manifold is a first manifold, the system further comprising a second manifold hydraulically coupled to the first manifold for obtaining low pressure slurry therefrom and hydraulically coupled to pumps of the plurality for circulating slurry therebetween.', '15.', 'The system of claim 11 further comprising a mixer to provide the slurry to the low pressure slurry to the manifold from water and proppant sources.\n\n\n\n\n\n\n16.', 'The system of claim 11 wherein the low pressure slurry is at a pressure less than about 300 PSI and the high pressure slurry is at a pressure greater than about 3,000 PSI.']

['FIG.', '1 is a schematic overview depiction of stimulation system at an oilfield employing an embodiment of a pairing technique for pumps and a manifold thereof.; FIG.', '2 is a side view of the manifold of FIG.', '1 with stations accommodating valve locations for pairing with the pumps of FIG.', '1.; FIG.', '3A is an enlarged side view of a pump of FIG.', '1 for circulating a stimulation slurry from the manifold and back thereto at an increased pressure.', '; FIG.', '3B is an enlarged cross-sectional view of a portion of the pump of FIG.', '3A revealing a sensor therein for the pairing technique of FIG.', '1.; FIG.', '4A is a flow-chart summarizing an embodiment of a leak-detection technique for pump evaluation and subsequent paring.; FIG.', '4B is a flow-chart summarizing an embodiment of utilizing a paring technique to identify pump and valve location couplings for the system of FIG.', '1.; FIG. 5 is a schematic overview depiction of the system at the oilfield of FIG.', '1 in operation after employing a pairing technique for a stimulation application.']

US11913326

Downhole communication systems

Oct 29, 2020

Steven Hough, Edward Richards

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion in International Patent Application No. PCT/US2020/057972, dated Feb. 2, 2022, 12 pages.

4386422; May 31, 1983; Mumby; 7975392; July 12, 2011; Spaulding; 20030209365; November 13, 2003; Downton; 20080204270; August 28, 2008; Aiello; 20100157735; June 24, 2010; Allan; 20100307828; December 9, 2010; Hutin; 20120032560; February 9, 2012; Ochoa; 20160265351; September 15, 2016; Gajji et al.; 20170284195; October 5, 2017; White et al.; 20170359633; December 14, 2017; White et al.

2014190442; December 2014; WO; 2017156107; September 2017; WO

['A system for downhole communication includes a roll stabilized platform and a mud pulse generator in communication with the roll stabilized platform.', 'The mud pulse generator generates pressure pulses in a pattern that includes encoded data.', 'A receiver receives the pressure pulses and the encoded data is decoded.', 'The receiver is located at any location capable of receiving pressure pulses.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application claims the benefit of, and priority to, U.S. Patent Application No. 62/928,377, filed on Oct. 31, 2019 and titled “DOWNHOLE COMMUNICATION SYSTEMS” which application is incorporated herein by this reference in its entirety.', 'BACKGROUND\n \nDownhole drilling tools often rotate to drill, ream, or otherwise degrade material in a downhole environment.', 'Many downhole drilling tools include sections that rotate independently of each other.', 'For example, roll stabilized platforms are often held rotationally stable with respect to a borehole wall, and used in directional drilling applications to provide a reference for an operator on the surface, or a downhole control unit, to direct the bit on a desired trajectory (e.g., to direct the azimuth and/or inclination of the bit).', 'The roll stabilized platform may collect data, such as measurements from sensors, which may be beneficial to communicate from the roll stabilized platform to other portions of a drilling system.', 'SUMMARY', 'In some embodiments, a downhole communication system includes a roll stabilized platform and a mud pulse generator in communication with the roll stabilized platform.', 'The system includes a receiver configured to receive a pressure pulse generated by the mud pulse generator.', 'In some embodiments, a method for downhole communication includes generating pressure pulses in a pattern using a mud pulse generator in communication with a roll stabilized platform.', 'The pattern includes encoded data.', 'The method further includes receiving the pressure pulses at a receiver and decoding the encoded data from the pattern.', 'In some embodiments, a method for downhole communication includes generating a first set of pressure pulses using a mud pulse generator in communication with a roll stabilized platform.', 'The first set of pressure pulses are generated in a first pattern having a first frequency and received at a first receiver.', 'A second set of pressure pulses may be generated at a downhole tool in a second pattern having a second frequency.', 'The second set of pressure pulses may be received at a second receiver.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Additional features and advantages of embodiments of the disclosure will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by the practice of such embodiments.', 'The features and advantages of such embodiments may be realized and obtained by means of the instruments and combinations particularly pointed out in the appended claims.', 'These and other features will become more fully apparent from the following description and appended claims, or may be learned by the practice of such embodiments as set forth hereinafter.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'In order to describe the manner in which the above-recited and other features of the disclosure can be obtained, a more particular description will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings.', 'For better understanding, the like elements have been designated by like reference numbers throughout the various accompanying figures.', 'While some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale.', 'Understanding that the drawings depict some example embodiments, the embodiments will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:\n \nFIG.', '1\n is a drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n1\n is a cross-sectional view of a downhole connection, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n2\n is another cross-sectional view of the downhole connection of \nFIG.', '2\n-\n1\n, according to at least one embodiment of the present disclosure;\n \nFIG.', '3\n is a cross-sectional view of a downhole connection, according to at least one embodiment of the present disclosure;\n \nFIG.', '4\n is a cross-sectional view of a downhole telemetry system, according to at least one embodiment of the present disclosure;\n \nFIG.', '5\n is a cross-sectional view of another downhole telemetry system, according to at least one embodiment of the present disclosure;\n \nFIG.', '6\n is a cross-sectional view of yet another downhole telemetry system, according to at least one embodiment of the present disclosure;\n \nFIG.', '7\n is a schematic of a communication system, according to at least one embodiment of the present disclosure;\n \nFIG.', '8\n is a schematic of another communication system, according to at least one embodiment of the present disclosure;\n \nFIG.', '9\n is a schematic of yet another communication system, according to at least one embodiment of the present disclosure;\n \nFIG.', '10\n is a method chart of a method for downhole communication, according to at least one embodiment of the present disclosure; and\n \nFIG.', '11\n is a method chart of another method for downhole communication, according to at least one embodiment of the present disclosure.', 'DETAILED DESCRIPTION', 'This disclosure generally relates to devices, systems, and methods for communicating information between a roll stabilized platform and other portions of a drilling system. \nFIG.', '1\n shows one example of a drilling system \n100\n for drilling an earth formation \n101\n to form a wellbore \n102\n.', 'The drilling system \n100\n includes a drill rig \n103\n used to turn a drilling tool assembly \n104\n which extends downward into the wellbore \n102\n.', 'The drilling tool assembly \n104\n may include a drill string \n105\n, a bottomhole assembly (“BHA”) \n106\n, and a bit \n110\n, attached to the downhole end of drill string \n105\n.', 'The drill string \n105\n may include several joints of drill pipe \n108\n connected end-to-end through tool joints \n109\n.', 'The drill string \n105\n transmits drilling fluid through a central bore and transmits rotational power from the drill rig \n103\n to the BHA \n106\n.', 'In some embodiments, the drill string \n105\n may further include additional components such as subs, pup joints, etc.', 'The drill pipe \n108\n provides a hydraulic passage through which drilling fluid is pumped from the surface.', 'The drilling fluid discharges through selected-size nozzles, jets, or other orifices in the bit \n110\n for the purposes of cooling the bit \n110\n and cutting structures thereon, and for lifting cuttings out of the wellbore \n102\n as it is being drilled.', 'The BHA \n106\n may include the bit \n110\n or other components.', 'An example BHA \n106\n may include additional or other components (e.g., coupled between to the drill string \n105\n and the bit \n110\n).', 'Examples of additional BHA components include drill collars, stabilizers, measurement-while-drilling (MWD) tools, logging-while-drilling (LWD) tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'The BHA \n106\n may further include a rotary steerable system (RSS).', 'The RSS may include directional drilling tools that change a direction of the bit \n110\n, and thereby the trajectory of the wellbore.', 'At least a portion of the RSS may maintain a geostationary position relative to an absolute reference frame, such as gravity, magnetic north, and/or true north.', 'Using measurements obtained with the geostationary position, the RSS may locate the bit \n110\n, change the course of the bit \n110\n, and direct the directional drilling tools on a projected trajectory.', 'In some embodiments, at least a portion of the RSS may be roll stabilized and may not rotate with the drill collar.', 'In such embodiments, such a portion of the RSS may be geostationary or may be controlled in such a way so as to control the direction of the drill string.', 'In general, the drilling system \n100\n may include other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves).', 'Additional components included in the drilling system \n100\n may be considered a part of the drilling tool assembly \n104\n, the drill string \n105\n, or a part of the BHA \n106\n depending on their locations in the drilling system \n100\n.', 'The bit \n110\n in the BHA \n106\n may be any type of bit suitable for degrading downhole materials.', 'For instance, the bit \n110\n may be a drill bit suitable for drilling the earth formation \n101\n.', 'Example types of drill bits used for drilling earth formations are fixed-cutter or drag bits.', 'In other embodiments, the bit \n110\n may be a mill used for removing metal, composite, elastomer, other materials downhole, or combinations thereof.', 'For instance, the bit \n110\n may be used with a whipstock to mill into casing \n107\n lining the wellbore \n102\n.', 'The bit \n110\n may also be a junk mill used to mill away tools, plugs, cement, other materials within the wellbore \n102\n, or combinations thereof.', 'Swarf or other cuttings formed by use of a mill may be lifted to surface, or may be allowed to fall downhole.', 'Conventionally, communication between two subs that rotate at different rotational rates may be performed via a physical connection, such as a slip ring or other rotating physical connection known in the art.', 'Alternatively, an electromagnetic signal may be wirelessly transmitted between two subs rotating at different rotational rates.', 'However, slip rings and the like may be prone to wear, erosion, jamming, clogging, and combinations of the foregoing.', 'Furthermore, electromagnetic signals are short range and potentially unreliable, especially in downhole environments, where downhole equipment, drilling fluid, rock formation, and other factors interfere with electromagnetic communication.\n \nFIG.', '2\n-\n1\n is a representation of a downhole connection \n212\n, according to at least one embodiment of the present disclosure.', 'The downhole connection \n212\n may include a rotating member \n214\n and an independently rotating member \n216\n.', 'The rotating member \n214\n and the independently rotating member \n216\n may be rotationally independent of each other.', 'For example, the rotating member \n214\n may include a downhole sub \n218\n that rotates in synch with the collar (e.g., at the drill rig \n103\n of \nFIG.', '1\n) and/or the drill bit (e.g., the bit \n110\n of \nFIG.', '1\n).', 'In some embodiments, the downhole sub \n218\n may be a drill pipe (e.g., the drill string \n105\n of \nFIG.', '1\n).', 'In other embodiments, the downhole sub \n218\n may be a downhole tool, or a portion of the BHA (e.g., the BHA \n106\n of \nFIG.', '1\n).', 'The independently rotating member \n216\n may include an independently rotating platform \n220\n.', 'The independently rotating platform \n220\n may rotate at a different rotational rate than the downhole sub \n218\n.', 'For example, the independently rotating platform \n220\n may be a roll stabilized system, such as a roll stabilized control unit of a rotary steerable system.', 'In other examples, the independently rotating platform \n220\n may be the rotor of a mud motor.', 'In still other examples, the independently rotating platform may be any other downhole element rotationally independent of the downhole sub \n218\n.', 'In further examples, the independently rotating member may be a non-rotating sleeve on a rotary steerable system.', 'In some examples, the rotating member \n214\n may rotate with a first rotational rate and the independently rotating platform \n220\n may rotate with a second rotational rate.', 'In some embodiments, the first rotational rate may be the same as the second rotational rate.', 'In other embodiments, the first rotational rate may be different from the second rotational rate.', 'For example, the second rotational rate may be less than (i.e., with a lower RPM than) the first rotational rate.', 'In some embodiments, the first rotational rate and the second rotational rate may be in the same direction (e.g., clockwise or counterclockwise).', 'In other embodiments, the first rotational rate and the second rotational rate may be in opposite directions (e.g., clockwise or counterclockwise).', 'In some embodiments, the second rotational rate may be zero with respect to an external frame of reference, such as gravity, magnetic north, grid north, true north, or the formation.', 'In other examples, the second rotational rate may be greater than (i.e., with a higher RPM than) the first rotational rate.', 'In some embodiments, the first rotational rate may be zero or approximately zero.', 'Therefore, the rotating member may not rotate relative to an external frame of reference.', 'The independently rotating member may be driven by a downhole motor, such as a mud motor.', 'In this manner, the independently rotating member may rotate with respect to both the rotating member and an external frame of reference.', 'The independently rotating platform \n220\n may be connected to a solenoid \n222\n.', 'The solenoid \n222\n may be rotationally fixed to the independently rotating platform \n220\n.', 'In other words, the solenoid \n222\n may rotate with the same rotational rate as the independently rotating platform \n220\n.', 'In some embodiments, the solenoid \n222\n may be located at the uphole end \n224\n of the independently rotating platform \n220\n.', 'For example, the independently rotating platform \n220\n may include an extension \n226\n that extends uphole past a body of the independently rotating platform (not shown).', 'In other embodiments, the extension \n226\n may extend downhole from the independently rotating platform \n220\n, and the downhole sub \n218\n may be downhole of the independently rotating platform \n220\n.', 'The solenoid \n222\n may be connected to the extension \n226\n with any type of connection, such as a threaded connection, a reverse-threaded connection, a bolted connection, a weld, a braze, an interference fit, a friction fit, or any other connection.', 'The rotating member \n214\n may include a magnetic conductor \n228\n.', 'In some embodiments, the magnetic conductor \n228\n may be rotationally fixed to the rotating member \n214\n.', 'The magnetic conductor \n228\n may be rotationally and/or longitudinally movable with respect to or relative to the solenoid \n222\n.', 'The solenoid \n222\n includes a central bore \n230\n.', 'In some embodiments, the central bore \n230\n may have an opening \n232\n having a non-uniform diameter relative to the rest of the central bore \n230\n.', 'The magnetic conductor \n228\n may include an end \n234\n shaped complementarily to the opening \n232\n.', 'In some embodiments, the magnetic conductor \n228\n may move longitudinally in and out of the opening \n232\n.', 'In some embodiments, the magnetic conductor \n228\n may be manufactured from a magnetic material.', 'For example, the magnetic conductor \n228\n may be manufactured from a steel alloy, a nickel alloy, or another type of magnetic material, such as a rare-earth magnet (e.g., neodymium or samarium alloy magnets).', 'A gap \n236\n may be present between the solenoid \n222\n and the magnetic conductor \n228\n.', 'The gap \n236\n may maintain a gap distance \n237\n, or an open gap distance, between the solenoid \n222\n and the magnetic conductor \n228\n during operation of the solenoid \n222\n.', 'In this manner, the magnetic conductor \n228\n and the solenoid \n222\n may not contact.', 'Preventing the solenoid \n222\n and the magnetic conductor \n228\n from contacting may reduce the number of physical connections between the rotating member \n214\n and the independently rotating member \n216\n.', 'This may reduce wear and therefore increase the life of the solenoid \n222\n and/or the magnetic conductor \n228\n.', 'Furthermore, this may improve reliability of the system, because the solenoid \n222\n and the magnetic conductor \n228\n may not get stuck or clog with respect to each other.', 'Still further, this may reduce drag torque on the magnetic conductor \n228\n.', 'In at least one embodiment, the gap \n236\n may allow for lateral clearance if the downhole connection is bent or curved in a deviated borehole.', 'Furthermore, the gap \n236\n may allow for thermal expansion and/or protection from contact during vibration or other movement of the solenoid \n222\n and the magnetic conductor \n228\n relative to each other.', 'In some embodiments, the gap \n236\n may be filled with air, such as standard atmospheric air.', 'Filling the gap \n236\n with air may reduce the force required to move the magnetic conductor \n228\n and/or may increase and/or maximize how far the magnetic field is conducted with the magnetic conductor \n228\n.', 'In other embodiments, the gap \n236\n may be filled with another gas or gas mixture, including an inert gas such as nitrogen.', 'In still other embodiments, the gap \n236\n may include a vacuum or a near-vacuum.', 'In yet other embodiments, the gap \n236\n may be filled with a fluid, such as a water based fluid, an oil based fluid, drilling mud, or other fluid.', 'In at least one embodiment, filling the gap \n236\n with a fluid may help to maintain an operating temperature of the solenoid \n222\n.', 'In some embodiments, the gap distance \n237\n may be in a range having an upper value and a lower value, or upper and lower values including any of 0.1 mm, 0.5 mm, 1 mm, 2 mm, 3 mm, 4 mm, 5 mm, 6 mm, 7 mm, 8 mm, 9 mm, 10 mm, or any value therebetween.', 'For example, the gap distance \n237\n may be greater than 0.1 mm.', 'In other examples, the gap distance \n237\n may be less than 10 mm.', 'In yet other examples, the gap distance \n237\n may be any value in a range between 0.1 mm and 10 mm.', 'In at least one embodiment, it may be critical that the gap distance \n237\n is between 0.1 mm and 10 mm.', 'The gap distance \n237\n may be sized such that a magnetic flux may flow through the magnetic conductor \n228\n and such that the magnetic conductor \n228\n may be magnetically attracted to the solenoid \n222\n when the solenoid \n222\n is activated.', 'The rotating member \n214\n may include a solenoid housing \n238\n.', 'The solenoid housing \n238\n may extend around the solenoid \n222\n.', 'In some embodiments, the solenoid housing \n238\n may extend past a bottom portion \n239\n of the solenoid \n222\n and engage the extension \n226\n.', 'The solenoid housing \n238\n may engage the extension \n226\n with a rotational connection, such as a bearing including a seal.', 'In this manner, the gap \n236\n may extend around a portion or all of an outer surface of the solenoid \n222\n, with the solenoid housing \n238\n sealing the gap to prevent the gas or fluid from escaping.', 'In other words, the gap \n236\n may be a part of a solenoid chamber \n240\n, which extends around the solenoid and the magnetic conductor \n228\n.', 'In other embodiments, the solenoid housing \n238\n may engage the solenoid \n222\n at any location along the outer surface of the solenoid \n222\n.', 'A moving member \n242\n (e.g., actuating member) may be a part of an actuation valve \n244\n.', 'The actuation valve \n244\n may include a flow restrictor \n246\n and a flow path \n248\n. \nFIG.', '2\n-\n1\n shows the downhole connection \n212\n in a first position, with the moving member \n242\n extended away from the solenoid \n222\n in a moving member first position.', 'In the first position, the flow restrictor \n246\n blocks the entrance \n250\n to the flow path \n248\n.', 'In this manner, a fluid flow into the flow path \n248\n is reduced or stopped when the downhole connection \n212\n is in the first position.', 'In some embodiments, the magnetic conductor \n228\n may move relative to the solenoid \n222\n with the moving member \n242\n.', 'In some embodiments, the moving member \n242\n and a portion of the flow restrictor shaft \n246\n may be contained within a pressure housing that isolates the moveable member from the pressure at the flow path \n248\n.', 'In the position shown in \nFIG.', '2\n-\n1\n, there is an actuator gap \n241\n between the magnetic conductor \n228\n and the moving member \n242\n.', 'In some embodiments, the actuator gap \n241\n may be in a range having an upper value and a lower value, or upper and lower values including any of 0.1 mm, 0.5 mm, 1 mm, 2 mm, 3 mm, 4 mm, 5 mm, 6 mm, 7 mm, 8 mm, 9 mm, 10 mm, or any value therebetween.', 'For example, the actuator gap \n241\n may be greater than 0.1 mm.', 'In other examples, the actuator gap \n241\n may be less than 10 mm.', 'In yet other examples, the actuator gap \n241\n may be any value in a range between 0.1 mm and 10 mm.', 'In at least one embodiment, it may be critical that the actuator gap \n241\n is between 0.1 mm and 10 mm.', 'The actuator gap \n241\n may be sized such that a magnetic flux may flow through the magnetic conductor \n228\n and such that the magnetic conductor \n228\n may be magnetically attracted to the solenoid \n222\n when the solenoid \n222\n is activated.', 'FIG.', '2\n-\n2\n shows the downhole connection \n212\n in a second position, with the moving member \n242\n in the moving member second position.', 'In the moving member second position, the moving member \n242\n may be located in the opening \n232\n such that it is closer to the solenoid \n222\n than in the moving member first position (i.e., closer to the extension \n226\n of the independently rotating platform \n220\n, or to a downhole end \n251\n of the solenoid \n222\n).', 'Because the magnetic conductor \n228\n does not move during actuation of the solenoid, the gap \n236\n may be remain the same or approximately the same between the magnetic conductor \n228\n and the solenoid \n222\n in the moving member second position as in the moving member first position.', 'Thus, the magnetic conductor \n228\n and the solenoid \n222\n may not contact when the moving member \n242\n is in the moving member second first position or the moving member second position.', 'In other words, the magnetic conductor \n228\n and the solenoid \n222\n may not come into physical or mechanical contact in the first position of the downhole connection \n212\n or the second position of the downhole connection \n212\n.', 'In this manner, there may always be a non-zero distance between the magnetic conductor \n228\n and the solenoid \n222\n.', 'As previously discussed, the magnetic conductor \n228\n may remain fixed relative to the solenoid \n222\n, meaning that as the solenoid \n222\n is activated, the magnetic conductor \n228\n may not move, and the gap distance \n237\n may be the same as the second gap distance \n237\n-\n2\n.', 'The moving member \n242\n may have a second gap between the moving member \n242\n and the magnetic conductor \n228\n.', 'The moving member \n242\n may be magnetically attracted to the magnetic field of the activated solenoid \n222\n.', 'Thus, when the solenoid \n222\n is activated, the moving member \n242\n may move toward the solenoid \n222\n, while the magnetic conductor \n228\n remains at a fixed distance relative to the solenoid \n222\n.', 'In some embodiments, when the moving member \n242\n is moved toward the magnetic conductor \n228\n, the second gap may be completely closed, or, in other words, the moving member \n242\n may contact the magnetic conductor \n228\n when the solenoid \n222\n is activated.', 'In some embodiments, the moving member \n242\n may move approximately ⅓ or greater of a diameter of the diameter of the actuation valve \n244\n.', 'As discussed above, the gap \n236\n may reduce the number of rotational connections between the rotating member \n214\n and the independently rotating member \n216\n.', 'This may reduce the complexity of the BHA (e.g., BHA \n106\n of \nFIG. \n1\n), reduce wear on components of the downhole connection \n212\n, and reduce the cost of the BHA.', 'In some embodiments, the gap \n236\n may make the downhole connection \n212\n a frictionless or a low-friction connection because contact points between the rotating member \n214\n and the independently rotating member \n216\n are limited.', 'Moving the moving member \n242\n toward the solenoid \n222\n may remove the flow restrictor \n246\n from the entrance \n250\n of the flow path \n248\n.', 'This may allow fluid to enter the flow path \n248\n.', 'In this manner, the actuation valve \n244\n may be opened in the downhole connection \n212\n second position, or when the moving member \n242\n is in the moving member second position.', 'Similarly, the actuation valve \n244\n may be closed in the downhole connection \n212\n first position (e.g., the position depicted in \nFIG.', '2\n-\n1\n), or when the moving member \n242\n is in the moving member first position (as shown in \nFIG.', '2\n-\n1\n).', 'In some embodiments, the solenoid \n222\n may be deactivated when the downhole connection \n212\n is in the first position.', 'Thus, when the solenoid \n222\n is activated, the moving member \n242\n may be drawn toward the solenoid \n222\n.', 'This may remove the flow restrictor \n246\n from the entrance \n250\n of the flow path \n248\n.', 'In this manner, the solenoid \n222\n is activated when the downhole connection \n212\n is in the second position.', 'Thus, activating the solenoid \n222\n may actuate the moving member \n242\n, which may actuate or open the actuation valve \n244\n.', 'After the solenoid \n222\n is deactivated, a resilient member (not shown) may provide a return force to move or urge the moving member \n242\n back from the moving member second position to the moving member first position.', 'The resilient member may include a hydraulic or pneumatic piston, a coil spring, a wave spring, a Belleville washer, or the like.', 'Therefore, by activating and deactivating the solenoid \n222\n, the actuation valve \n244\n may be activated and de-activated.', 'In this case, the standard, or unpowered, position of the downhole connection \n212\n may be the first position, or with the actuation valve \n244\n closed.', 'In other embodiments, the solenoid \n222\n may be deactivated when the downhole connection \n212\n is in the second position.', 'Thus, when the solenoid \n222\n is activated, the moving member \n242\n may be repelled from the solenoid \n222\n.', 'This may move the moving member \n242\n, thereby inserting the flow restrictor \n246\n into the entrance \n250\n of the flow path \n248\n.', 'In this manner, the solenoid \n222\n is activated when the downhole connection \n212\n is in the first position.', 'After the solenoid \n222\n is deactivated, a resilient member (not shown) may provide a return force to move or urge the moving member \n242\n back from the moving member first position to the moving member second position.', 'The resilient member may include a hydraulic or pneumatic piston, a spring, a Belleville washer, or the like.', 'Therefore, by activating and deactivating the solenoid \n222\n, the actuation valve \n244\n may be activated and de-activated.', 'In this case, the standard, or unpowered, position of the downhole connection \n212\n may be the second position, or with the actuation valve \n244\n open.', 'In some embodiments, hydraulic pressure from the actuation valve \n244\n may provide the return force to return the moving member \n242\n from the moving member first position to the moving member second position or from the moving member second position to the moving member first position.', 'In this case, the magnetic field provided by the solenoid \n222\n attracts or repels the moving member \n242\n with sufficient force to overcome the hydraulic pressure.', 'In some embodiments, the moving member \n242\n may have a stroke length, which may be the difference in longitudinal length between the moving member first position and the moving member second position.', 'In other words, the stroke length may be the difference between the actuator gap (e.g., actuator gap \n241\n of \nFIG.', '2\n-\n1\n) and the second gap distance (e.g., no gap as shown in \nFIG.', '2\n-\n2\n).', 'In some embodiments, the stroke length may be the minimum necessary to open and close the actuation valve \n244\n.', 'In some embodiments, the stroke length may be in a range having an upper value and a lower value, or upper and lower values including any of 1 mm, 2 mm, 3 mm, 4 mm, 5 mm, 6 mm, 7 mm, 8 mm, 9 mm, 10 mm, 12 mm, 14 mm, 16 mm, or any value therebetween.', 'For example, the stroke length may be greater than 3 mm.', 'In other examples, the stroke length may be less than 20 mm.', 'In yet other examples, stroke length may be any value in a range between 1 mm and 10 mm, or in a range between 1.5 mm and 4 mm.', 'In some embodiments, the stroke length may be ⅓ or greater of a diameter of the actuation valve \n244\n.', 'By selectively activating and deactivating the solenoid \n222\n, the independently rotating platform \n220\n may communicate information from the independently rotating member \n216\n to the rotating member \n214\n.', 'This information may be encoded into a pattern represented by controlling the length of time during which the solenoid \n222\n is activated and deactivated, the frequency of the activations and deactivations, or any known communication pattern.', 'As discussed above, activating and deactivating the solenoid \n222\n may cause the moving member \n242\n to move from the moving member first position to the moving member second position.', 'In some embodiments, a sensor connected to the rotating member \n214\n may sense the movement of the moving member \n242\n.', 'A control unit, or a computing system, may then decode the information from the pattern of movement of the moving member \n242\n.', 'In some embodiments, a signal between the independently rotating member \n216\n and the rotating member \n214\n may be transmitted as fast as the moving member \n242\n may be actuated and de-actuated.', 'In other embodiments, the actuation valve \n244\n may activate a downhole tool, which may facilitate communication with other portions of the wellbore and/or the surface.', 'For example, the downhole tool may be mud pulse telemetry system, and the actuation valve \n244\n may activate mud pulses in the mud pulse telemetry system.', 'In some embodiments, sensors sensing the movement of the actuation member and the actuation valve \n244\n may to communicate information from the independently rotating member \n216\n to the rotating member \n214\n.\n \nFIG.', '3\n is a representation of an embodiment of a downhole telemetry system \n352\n.', 'The downhole telemetry system \n352\n may include at least some of the same features and characteristics as the connections described in relation to \nFIG.', '2\n-\n1\n and \nFIG.', '2\n-\n2\n.', 'In some embodiments, the downhole telemetry system \n352\n may include a rotating member \n314\n and an independently rotating member \n316\n.', 'The independently rotating member \n316\n may include a roll stabilized platform \n320\n.', 'An extension \n326\n from the uphole end of the roll stabilized platform \n320\n may be connected to a solenoid \n322\n.', 'A magnetic conductor \n328\n may be offset from the solenoid \n322\n.', 'The magnetic conductor \n328\n may be connected to an actuation valve \n344\n, the actuation valve \n344\n including a flow restrictor \n346\n that may restrict flow to a flow path \n348\n based on the position of a moving member \n342\n.', 'In some embodiments, the roll stabilized platform \n320\n may be (or may be a part of) a measuring while drilling (MWD) tool, a logging while drilling (LWD) tool, a rotary steerable system (e.g., a rotary steerable control unit), or any combination of the foregoing.', 'The roll stabilized platform \n320\n may include a platform control unit \n360\n.', 'The platform control unit \n360\n may be in electronic communication with the solenoid \n322\n.', 'The platform control unit \n360\n may control the activation of the solenoid \n322\n.', 'In other words, the platform control unit \n360\n may direct electric current to the solenoid \n322\n to activate or deactivate the solenoid \n322\n.', 'The platform control unit \n360\n may encode data into a pattern.', 'For example, the platform control unit \n360\n may encode data by activating and/or deactivating the solenoid \n322\n in the pattern.', 'Therefore, the platform control unit \n360\n may communicate or transmit information by activating and/or deactivating the solenoid \n322\n in the pattern, the pattern including the encoded data.', 'As the solenoid \n322\n is activated and/or deactivated, the actuation valve \n344\n may be opened and/or closed.', 'The flow path \n348\n may be in fluid communication with a mud pulse generator \n356\n.', 'When the actuation valve \n344\n is open, fluid may flow through the flow path \n348\n, which may actuate the mud pulse generator \n356\n.', 'In this manner, the mud pulse generator \n356\n may be in communication with the roll stabilized platform \n320\n.', 'In other words, the roll stabilized platform \n320\n may communicate information to the mud pulse generator \n356\n by activating and/or deactivating the solenoid \n322\n in the pattern.', 'This may allow the roll stabilized platform \n320\n to communicate information with elements of a drilling system that do not rotate at the same rate as the roll stabilized platform.', 'In some embodiments, a flow restrictor \n357\n in the mud pulse generator \n356\n has a high pressure position and a low pressure position.', 'When the flow restrictor \n357\n is in the high pressure position, drilling fluid flowing through the mud pulse generator \n356\n is restricted, which increases the hydraulic pressure of the drilling fluid.', 'When the flow restrictor \n357\n is in the low pressure position, drilling fluid flowing through the mud pulse generator \n356\n is relatively unrestricted, which decreases the hydraulic pressure of the drilling fluid.', 'Therefore, by changing the flow restrictor \n357\n between the high pressure position and the low pressure position, the hydraulic pressure of the drilling fluid may be changed, which may result in a “pressure pulse.”', 'It should be understood that the mud pulse generator \n356\n shown in \nFIG.', '3\n is simply one sample embodiment of a mud-pulse generator.', 'Other mud pulse generators (e.g., a siren type mud pulse generator), using flow restrictors \n357\n having different shapes and/or located in different positions (such as in the wall \n359\n) may also be used in embodiments of the present disclosure.', 'When the actuation valve \n344\n is open, fluid flowing through the flow path \n348\n may actuate the mud pulse generator \n356\n, changing the flow restrictor \n357\n from the low pressure position to the high pressure position.', 'Similarly, when the actuation valve \n344\n is closed, the mud pulse generator \n356\n may be de-actuated, and the flow restrictor \n357\n may change from the high pressure position to the low pressure position.', 'Therefore, when the solenoid \n322\n is activated, the mud pulse generator \n356\n may increase the pressure of the drilling fluid, and when the solenoid \n322\n is deactivated, the mud pulse generator \n356\n may decrease the pressure of the drilling fluid.', 'Thus, pressure pulses may be generated by activating and deactivating the solenoid \n322\n.', 'Because the actuation valve \n344\n actuates and de-actuates the mud pulse generator \n356\n, the actuation valve \n344\n may be a pilot valve for the mud pulse generator \n356\n.', 'In some embodiments, the power to actuate the solenoid \n322\n is located on the roll stabilized platform \n320\n.', 'Because the actuation valve \n344\n may be a pilot valve for the mud pulse generator \n356\n, the mud pulse generator \n356\n may not need an independent power source.', 'Therefore, the mud pulse generator \n356\n may be completely mechanical, or completely hydraulically operated, without an electronic control unit.', 'In some embodiments, the mud pulse generator \n356\n may have no other actuation mechanism, and may be actuated only by the actuation valve \n344\n.', 'In other embodiments, a sensor on the rotating member \n314\n may sense the actuation and de-actuation of the moving member \n342\n, and an electronic control unit on the mud pulse generator \n356\n may actuate the mud pulse generator.', 'In this manner, the platform control unit \n360\n may communicate information and/or data from the independently rotating member \n316\n to any location that is capable of receiving and receiving pressure pulses and interpreting the encoded data.', 'In some embodiments, the platform control unit \n360\n may communicate information and/or data from the independently rotating member \n316\n to a pressure pulse receiver located at a surface location.', 'In the same or other embodiments, the platform control unit \n360\n may communicate information and/or data from the independently rotating member \n316\n to a pressure pulse receiver located at a downhole tool.', 'Thus, the platform control unit \n360\n may communicate information over relatively short ranges (e.g., 0-50 feet) up to and including relatively long ranges (e.g., the entire length of the borehole or over 8,000 feet).', 'In at least one embodiment, the roll stabilized platform \n320\n may include at least one platform sensor \n358\n in electronic communication with the platform control unit \n360\n.', 'The at least one platform sensor \n358\n may be located on an MWD tool or an LWD tool, or the at least one platform sensor \n358\n may be located on another aspect of the roll stabilized platform.', 'The at least one platform sensor \n358\n may include any type of sensor, such as a directional sensor (e.g., azimuth and/or inclination), a gravimetric sensor, a gamma ray sensor, an accelerometer, a gyroscope, a resistivity sensor, a tool status sensor, (e.g., strain gauge or resistivity array) any other sensor, or combinations thereof.', 'The at least one platform sensor \n358\n may take a measurement.', 'The platform control unit \n360\n may then encode the measurement into a pattern and activate the solenoid \n322\n in the pattern.', 'In this manner, the mud pulse generator \n356\n may transmit the measurement as pressure pulses in the pattern.', 'Thus, the measurement may be communicated to any location that can receive and decode pressure pulses with a mud pulse receiver.', 'In some embodiments, the platform control unit \n360\n may control actuation of the mud pulse generator \n356\n based on a set of predetermined drilling conditions, such as wellbore depth, inclination, formation characteristics (e.g., rock type, rock hardness, and porosity), other drilling conditions, or combinations thereof.', 'In some embodiments, the at least one platform sensor \n358\n may take a measurement, and, based at least in part on the measurement, the platform control unit \n360\n may actuate or de-actuate the actuation valve \n344\n and therefore the mud pulse generator \n356\n.\n \nFIG.', '4\n is a representation of a downhole telemetry system \n452\n, according to at least one embodiment of the present disclosure.', 'The downhole telemetry system \n452\n may include at least some of the same features and characteristics as the downhole telemetry systems and connections described in relation to \nFIG.', '2\n-\n1\n through \nFIG.', '3\n.', 'In some embodiments, the downhole telemetry system \n452\n may include a rotating member \n414\n and an independently rotating member \n416\n.', 'The independently rotating member \n416\n may include a roll stabilized platform \n420\n.', 'An extension \n426\n from the uphole end of the roll stabilized platform \n420\n may be connected to a solenoid \n422\n.', 'A magnetic conductor \n428\n may be offset from the solenoid \n422\n and a moving member \n442\n may be offset from the magnetic conductor \n428\n.', 'The magnetic conductor \n428\n may be connected to an actuation valve \n444\n, the actuation valve \n444\n actuating a mud pulse generator \n456\n.', 'Therefore, the actuation valve \n444\n may be a pilot valve for the mud pulse generator \n456\n.', 'In this manner, the roll stabilized platform \n420\n may be in communication with the mud pulse generator \n456\n.', 'In other words, the roll stabilized platform \n420\n may activate and/or deactivate the solenoid \n422\n in the pattern, thereby actuating and/or de-actuating the actuation valve \n444\n.', 'This may allow the roll stabilized platform \n420\n to communicate information to the mud pulse generator \n456\n.', 'This may further allow the roll stabilized platform \n420\n to communicate information with elements of a drilling system that do not rotate at the same rate as the roll stabilized platform.', 'In some embodiments, a receiver \n462\n may be configured to detect the pressure pulses generated by the mud pulse generator \n456\n.', 'In some embodiments, the receiver \n462\n may be any sensor or tool that is capable of detecting a change in drilling pressure caused by pressure pulses, such as pressure pulses generated by the mud pulse generator \n456\n.', 'In at least one embodiment, the receiver \n462\n may be configured to detect a change in drilling pressure caused by pressure pulses propagated from a surface location.', 'Therefore, the receiver \n462\n may be configured to detect any change in drilling pressure, regardless of its source.', 'In some embodiments, the receiver \n462\n may directly measure pressure of a drilling fluid with a pressure sensor, such as a piston, a diaphragm, a strain gauge, a piezoelectric pressure sensor, an optical fiber, a pressure transducer, a pressure transmitter, or any combination of the foregoing.', 'In the same or other embodiments, the receiver \n462\n may indirectly measure pressure of the drilling fluid.', 'For example, the receiver \n462\n may measure a property of a drilling fluid dependent on the pressure, such as volumetric flow rate or fluid velocity.', 'In other examples, the receiver \n462\n may measure the rotational rate of a turbine or other rotating element whose rotation depends on the velocity and volumetric flow rate of the drilling fluid (which depend on the drilling pressure).', 'Therefore, the receiver \n462\n may be any device configured to detect or measure a change in drilling fluid pressure.', 'In some embodiments, the receiver \n462\n may be located on a downhole tool \n455\n.', 'For example, the downhole tool \n455\n may be an MWD tool or an LWD tool.', 'In other examples, the downhole tool \n455\n may be an expandable downhole tool, such as an underreamer, a section mill, or a stabilizer.', 'In yet other embodiments, the downhole tool \n455\n may be a power generation unit, such as a mud motor or a turbine motor.', 'In still other embodiments, the downhole tool \n455\n may be any tool or sub used on a BHA or in a downhole environment.', 'In further embodiments, the multiple receivers \n462\n may be located on multiple components (e.g., an MWD tool, an LWD tool, an expandable downhole tool, a power generation unit, other tools and/or subs, or combinations thereof) of the downhole tool \n455\n.', 'In some embodiments, the downhole telemetry system \n452\n may be located immediately downhole of the downhole tool \n455\n.', 'In other words, the downhole tool \n455\n may be directly connected to the downhole telemetry system \n452\n via a mechanical connection, such as a standard threaded pipe connection.', 'In other embodiments, the downhole tool \n455\n may be located further away from the downhole telemetry system \n452\n.', 'For example, the downhole tool \n455\n may be one of a plurality of downhole tools, and one or more other downhole tools of the plurality of downhole tools may be located between the downhole tool \n455\n and the downhole telemetry system \n452\n.', 'In the same or other examples, one or more tubular members may be located between the downhole tool \n455\n and the downhole telemetry system \n452\n.', 'The downhole tool \n455\n may include a downhole tool control unit \n464\n.', 'The downhole tool control unit \n464\n may be in electronic communication with the receiver \n462\n.', 'In other words, the receiver \n462\n may transmit the pressure measurements (or associated measurements) to the downhole tool control unit \n464\n.', 'The downhole tool control unit \n464\n may identify the pattern of the pressure pulses.', 'After identifying the pattern of the pressure pulses, the downhole tool control unit \n464\n may decode the information or the data from the pattern.', 'In this manner, the downhole telemetry system \n452\n may communicate information from the roll stabilized platform \n420\n to the downhole tool \n455\n.', 'Therefore, the information from the roll stabilized platform \n420\n may be communicated to any downhole tool \n455\n that includes a receiver \n462\n.', 'In some embodiments, the downhole tool control unit \n464\n may process the information decoded from the pressure pulses received by the receiver \n462\n.', 'For example, the information may be a platform measurement measured by a platform sensor \n458\n.', 'A platform control unit \n460\n may encode the platform measurement into a pattern, and the platform control unit \n460\n may activate and deactivate the solenoid \n422\n in the pattern, which may actuate the mud pulse generator \n456\n in the pattern.', 'Thus, the pattern received by the receiver \n462\n and decoded by the downhole tool control unit \n464\n may be the platform measurement.', 'In some embodiments, the platform sensor \n458\n may be any sensor used in downhole tools.', 'For example, the platform sensor \n458\n may be a trajectory sensor (azimuth and/or inclination), a gamma sensor, a resistivity sensor, a tool status sensor (e.g., vibration, strain gauge, temperature), or any other type of sensor.', 'The downhole tool control unit \n464\n may then process the platform measurement.', 'For example, the downhole tool control unit \n464\n may compare the platform measurement to a tool measurement taken by a downhole tool sensor \n466\n.', 'In some embodiments, the platform measurement and the tool measurement may be different measurements.', 'In other embodiments, the platform measurement and the tool measurement may be similar measurements.', 'For example, the platform measurement and the tool measurement may both be trajectory measurements (azimuth and/or inclination).', 'In other examples, the platform measurement and the tool measurement may both be resistivity measurements.', 'The roll stabilized platform \n420\n may be located closer to the bit than the downhole tool \n455\n.', 'Therefore, the platform sensor \n458\n may be closer to the bit than the downhole tool sensor \n466\n.', 'Measurements taken closer to the bit may be more accurate, or at least more representative of conditions at the bit, than measurements taken further away from the bit.', 'Therefore, a difference in conditions between the platform sensor \n458\n and the downhole tool sensor \n466\n may be analyzed.', 'In some embodiments, this difference in conditions may provide the downhole tool control unit \n464\n, or an operator at the surface, with an indication of how fast drilling conditions are changing.', 'For example, a difference in gamma measurements may indicate if the formation has changed, or if the bit is wandering out of a target formation.', 'In other examples, a difference in resistivity may indicate a change in downhole fluid properties, such as if a downhole water or oil reservoir is encountered.', 'In still other examples, a difference in vibration of different locations of a BHA may indicate how a BHA is performing, and provide feedback that may be used during the design of other BHAs.', 'A sensor distance \n468\n may be the distance between the platform sensor \n458\n and the downhole tool sensor \n466\n.', 'The downhole tool control unit \n464\n may use the sensor distance \n468\n to analyze the platform measurement.', 'For example, a platform measurement measuring trajectory (azimuth and/or inclination) may be compared to tool measurement measuring trajectory (azimuth and/or inclination).', 'A trajectory difference over the sensor distance \n468\n may be used to determine the immediate or real-time curvature of the borehole.', 'This curvature information may help prevent the need to wait for the downhole tool sensor \n466\n to travel the sensor distance \n468\n.', 'Therefore, the downhole tool control unit \n464\n and/or an operator may have more current or up-to-date information based at least in part on the information from the platform sensor \n458\n.', 'In some embodiments, the downhole tool control unit \n464\n may change one or more drilling parameters based on the platform measurement.', 'For example, if the platform measurement indicates that the bit has reached a target depth or a target formation, then the downhole tool control unit \n464\n may signal for an expandable tool, such as a section mill or an underreamer, to expand.', 'In other examples, if the platform measurement indicates that the bit is vibrating excessively or experiencing a greater weight on bit than is desired, the downhole tool control unit \n464\n may send a signal indicating that the rotational rate or the weight on bit should be reduced.', 'In still other examples, if the platform measurement indicates that the bit has wandered off a planned trajectory, the downhole tool control unit \n464\n may signal for a rotary steerable system to change the trajectory of the drill bit.', 'In yet other examples, the downhole tool \n455\n may be an expandable tool, and the downhole tool control unit \n464\n may modify an extension of the expandable blades based at least in part on the information decoded from the pressure pulses.', 'FIG.', '5\n is a representation of a drilling system \n500\n, according to at least one embodiment of the present disclosure.', 'The drilling system \n500\n may include at least some of the same features and characteristics as the downhole telemetry systems and connections described in relation to \nFIG.', '2\n-\n1\n through \nFIG.', '4\n.', 'The drilling system \n500\n may include a drill rig \n503\n located at a surface location that operate a BHA \n506\n connected to the downhole end of a drill string \n505\n.', 'The drill string \n505\n may include several joints of pipe \n508\n connected end-to-end through tool joints \n509\n.', 'The BHA \n506\n may include the bit \n510\n or other components.', 'Examples of additional BHA components include drill collars, stabilizers, MWD tools, LWD tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'The BHA \n506\n may include a mud pulse telemetry system \n552\n.', 'The mud pulse telemetry system \n552\n may include a roll stabilized platform \n520\n above the bit \n510\n.', 'The roll stabilized platform \n520\n may include a platform sensor \n560\n.', 'The roll stabilized platform \n520\n may rotate at a different rotational rate than the rest of the BHA \n506\n, including the bit \n510\n.', 'For example, the roll stabilized platform \n520\n may be a roll stabilized rotary steerable system.', 'The roll stabilized platform \n520\n may include a solenoid that may cause a moving member to actuate a mud pulse generator \n556\n adjacent to the roll stabilized platform \n520\n.', 'Actuating the mud pulse generator \n556\n may cause a change in pressure of drilling fluid flowing through the BHA \n506\n and the drill string \n505\n.', 'In this manner, pressure pulses in the drilling fluid may be generated, activated by the roll stabilized platform \n520\n and actuated by the mud pulse generator \n556\n.', 'As discussed above, the pressure pulses may be generated in a pattern that includes encoded data.', 'The encoded data may include measurements taken at the sensor \n558\n, or any other data.', 'The pressure pulses may be transmitted through the drilling fluid to the surface.', 'The pressure pulses may be transmitted to a stand pipe \n570\n.', 'The stand pipe \n570\n may refer generally to the pipes leading from a drilling fluid pump \n571\n to the drill string \n505\n at the drill rig \n503\n.', 'The pressure in the stand pipe \n570\n may be measured at a receiver \n562\n.', 'The receiver \n562\n may be any receiver known in the art used to measure fluid pressure.', 'The receiver \n562\n may include a processor that decodes the pattern and retrieves the information from the pattern in the pressure pulses.', 'In this manner, information may be communicated from the roll stabilized platform \n520\n to the surface.', 'In other words, information may be communicated from the roll stabilized platform \n520\n to a receiver \n562\n, the receiver \n562\n being a surface receiver.', 'As discussed above, measurements taken closer to the bit \n510\n, such as at the sensor \n558\n on the roll stabilized platform \n520\n, may be more accurate or more representative of current drilling conditions than measurements taken further from the bit \n510\n.', 'Therefore, communicating information from the roll stabilized platform \n520\n to the surface may provide an operator with more accurate and/or representative information.', 'The operator may make changes in response to the data or information decoded from the pressure pulses.', 'More accurate and/or representative information may allow the operator to make those changes sooner, or to make changes more specifically suited to measured drilling conditions.', 'This may provide many benefits, including, but not limited to, improving the rate of penetration, reducing the cost of the borehole, lengthening equipment life, improving well production, or any combination of the foregoing.\n \nFIG.', '6\n is a representation of a drilling system \n600\n, according to at least one embodiment of the present disclosure.', 'The drilling system \n600\n may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to \nFIG.', '2\n-\n1\n through \nFIG.', '5\n.', 'The drilling system \n600\n may include a drill rig \n603\n located at a surface location that operate a BHA \n606\n connected to the downhole end of a drill string \n605\n.', 'The drill string \n605\n may include several joints of pipe \n608\n connected end-to-end through tool joints \n609\n.', 'The BHA \n606\n may include the bit \n610\n or other components.', 'Examples of additional BHA components include drill collars, stabilizers, MWD tools, LWD tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'The BHA \n606\n may include a mud pulse telemetry system.', 'The mud pulse telemetry system may include a roll stabilized platform \n620\n above the bit \n610\n.', 'The roll stabilized platform \n620\n may include a platform sensor \n658\n.', 'The roll stabilized platform \n620\n may rotate at a different rotational rate than the rest of the BHA \n606\n, including the bit \n610\n.', 'For example, the roll stabilized platform \n620\n may be a roll stabilized rotary steerable system.', 'The roll stabilized platform \n620\n may include a solenoid that may cause a moving member to actuate a mud pulse generator \n656\n adjacent to the roll stabilized platform \n620\n.', 'Actuating the mud pulse generator \n656\n may cause a change in pressure of drilling fluid flowing through the BHA \n606\n and the drill string \n605\n.', 'In this manner, pressure pulses in the drilling fluid may be generated, activated by the roll stabilized platform \n620\n and actuated by the mud pulse generator \n656\n.', 'As discussed above, the pressure pulses may be generated in a pattern that includes encoded data.', 'The encoded data may include measurements taken at the platform sensor \n658\n, or any other data.', 'The drilling system \n600\n may further include a downhole tool \n655\n.', 'The downhole tool may be located on the BHA \n606\n, or uphole of the BHA \n606\n in the drill string \n605\n.', 'The downhole tool \n655\n may include a downhole tool receiver \n662\n-\n1\n, the downhole tool receiver \n662\n-\n1\n being configured to receive the pressure pulses.', 'A downhole tool control unit \n664\n may decode the pattern of the pressure pulses, thereby receiving the encoded information or data communicated from the roll stabilized platform \n620\n.', 'In this manner, the roll stabilized platform \n620\n may communicate information to a downhole tool \n655\n.', 'Furthermore, the pressure pulses may be transmitted through the drilling fluid to the surface.', 'The pressure pulses may be transmitted to a stand pipe \n670\n.', 'The stand pipe \n670\n may refer generally to the pipes leading from a drilling fluid pump \n671\n to the drill string \n605\n at the drill rig \n603\n.', 'The pressure in the stand pipe \n670\n may be measured at a surface receiver \n662\n-\n2\n.', 'The surface receiver \n662\n-\n2\n may be any receiver known in the art used to measure fluid pressure.', 'A processor in electronic communication with the surface receiver \n662\n-\n2\n may decode the pattern and retrieve the information from the pattern in the pressure pulses.', 'Therefore, in some embodiments, both the downhole tool receiver \n662\n-\n1\n and the surface receiver \n662\n-\n2\n may receive the pressure pulses, and decode the pattern to receive the information encoded in the pattern.', 'In other embodiments, only one of the downhole tool receiver \n662\n-\n1\n or the surface receiver \n662\n-\n2\n may decode the information encoded in the pattern.', 'For example, the pressure pulses may include a leading pattern at the beginning of the pattern.', 'The leading pattern may indicate that the pressure pulses originated from the roll stabilized platform \n620\n.', 'The downhole tool control unit \n664\n or a surface control unit \n672\n may decode the leading pattern.', 'Instructions in the downhole tool control unit \n664\n or the surface control unit \n672\n may indicate that the remainder of the pattern should be disregarded, so that the downhole tool control unit \n664\n or the surface control unit \n672\n do not decode the remainder of the pattern.', 'In at least one embodiment, the downhole tool \n655\n may include a downhole tool mud pulse telemetry system.', 'The downhole tool mud pulse telemetry system may be capable of generating pressure pulses to transmit to the surface.', 'In some embodiments, the downhole tool \n655\n may operate the mud pulse generator \n656\n independent of the roll stabilized platform \n620\n.', 'After receipt of pressure pulses (e.g., from the roll stabilized platform \n620\n), the downhole tool \n655\n may process the information from the roll stabilized platform \n620\n with the downhole tool control unit \n664\n.', 'For example, the roll stabilized platform \n620\n may measure a measurement with the platform sensor \n658\n, encode it into a pattern with the platform control unit \n660\n, and actuate the mud pulse generator \n656\n in the pattern.', 'The downhole tool receiver \n662\n-\n1\n may receive the pulse pattern and the downhole tool control unit \n664\n may decode the pattern, thereby retrieving the measurement from the platform sensor \n658\n.', 'The downhole tool control unit \n664\n may then process the measurement, and combine the measurement with other information and instruct a mud pulse generator to send the information to the surface.', 'Therefore, downhole tool \n655\n may relay information from the roll stabilized platform \n620\n to the surface receiver \n662\n-\n2\n.\n \nFIG.', '7\n is a representation of a communication system \n773\n, according to at least one embodiment of the present disclosure.', 'The communication system \n773\n may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to \nFIG.', '2\n-\n1\n through \nFIG.', '6\n.', 'The communication system \n773\n may include a downhole mud pulse telemetry system \n774\n, including a roll stabilized platform \n775\n and a rotating member \n776\n.', 'The roll stabilized platform \n775\n may include a platform control unit \n777\n and a solenoid \n778\n.', 'The rotating member may include an actuator \n779\n and a mud pulse generator \n780\n.', 'The platform control unit \n777\n may activate the solenoid \n778\n, which may actuate the actuator \n779\n.', 'The solenoid \n778\n and the actuator \n779\n may be rotating at different rotational rates.', 'Thus, the mud pulse telemetry system \n774\n allows for communication between elements that rotate at different rotational rates.', 'The actuator \n779\n may actuate a mud pulse generator \n780\n.', 'The mud pulse generator \n780\n may generate a pressure pulse in a drilling fluid every time the actuator is activated.', 'The platform control unit \n777\n may activate the solenoid \n778\n in a pattern, the pattern including encoded data \n781\n.', 'Therefore, the mud pulse generator \n780\n may communicate encoded data \n781\n based on the activation of the solenoid \n778\n.', 'The encoded data \n781\n may be distributed or communicated to one or more receivers \n782\n.', 'For example, the communication system \n773\n may include 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, or more (i.e., “n”) receivers.', 'The one or more receivers \n782\n may be located at any location that is capable of receiving the pressure pulses including the encoded data \n781\n.', 'For example, a first receiver may be located at a location along the drill string, such as at an MWD or an LWD.', 'A second receiver may be located at a second location along the drill string, such as at a downhole tool.', 'A third receiver may be located at a surface location, such as at a stand pipe.', 'In other examples, a single receiver \n782\n may be located on a downhole tool or at a surface location.', 'FIG.', '8\n is a representation of a communication system \n873\n, according to at least one embodiment of the present disclosure.', 'The communication system \n873\n may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to \nFIG.', '2\n-\n1\n through \nFIG.', '7\n.', 'In the embodiment shown, the roll stabilized platform \n875\n may include one or more sensors \n883\n.', 'The one or more sensors \n883\n may measure a measurement.', 'The platform control unit \n877\n may encode the measurement into a pattern and activate the solenoid \n878\n in the pattern.', 'The solenoid \n878\n may then actuate the actuator \n879\n and therefore the mud pulse generator \n880\n in the pattern.', 'In this manner, the mud pulse telemetry system \n874\n may communicate encoded data \n881\n measured on a roll stabilized platform \n875\n to a rotating member \n876\n.', 'The encoded data \n881\n may be transmitted as pressure pulses to a drilling system \n884\n.', 'A receiver \n882\n may receive the pressure pulses.', 'A processor \n885\n in electronic communication with the receiver \n882\n may decode the encoded data \n881\n using a decoding module \n886\n.', 'The decoding module \n886\n may decode the encoded data \n881\n using any technique used for decoding encoded pressure pulses.', 'The processor may include an analysis module \n887\n which may then analyze the decoded measurement.', 'In some embodiments, the processor \n885\n may change a drilling parameter of a downhole tool based on the encoded data \n881\n.', 'For example, the downhole tool may be an expandable downhole tool, and the processor \n885\n may instruct the downhole tool to expand or retract expandable blades of the expandable tool based at least in part on the encoded data \n881\n.', 'The extent of the expansion or retraction of expandable blades may be changed based at least in part on the encoded data \n881\n.', 'For example, the formation information may include an indication of the hardness of the formation.', 'A harder formation may require stabilizer blades to be expanded further, or for a greater force used in expansion of the stabilizer blades, to adequately stabilize the BHA.', 'Therefore, in some embodiments, the processor \n885\n may instruct a stabilizer to increase the force of expansion of the stabilizer blades.', 'In other examples, the processor \n885\n may instruct a tool sensor to take a tool measurement based on an analysis of the encoded data \n881\n.', 'In some embodiments, the encoded data \n881\n may include instructions for a downhole tool.', 'The instructions may be instructions to change at least one drilling parameter of a downhole tool.', 'For example, the instructions may be instructions for an MWD or an LWD to take a measurement.', 'In other examples, the instructions may instruct the downhole tool to expand expandable blades.', 'In still other examples, the instructions may instruct any downhole tool to change any drilling parameter.', 'In some embodiments, the drilling system \n884\n may be any aspect of a downhole drilling system (e.g., drilling system \n100\n of \nFIG.', '1\n).', 'For example, the receiver \n882\n may be located at a surface location, such as at a standpipe.', 'In other examples, the receiver \n882\n may be located at a downhole location, such as at an MWD, an expandable tool, or other downhole tool.', 'In some embodiments, the receiver \n882\n and the processor \n885\n may be located in different locations.', "For example, the receiver \n882\n may be located at a standpipe at the surface, but the processor \n885\n may be located at an operator's workstation, with the processor \n885\n in wired or wireless communication with the receiver \n882\n.", 'In other examples, the receiver \n882\n may be located on a first downhole tool and the processor \n885\n may be located on a second downhole tool, the first and second downhole tools being in electronic communication.', 'In still other examples, the receiver \n882\n may be located at a downhole location and the processor \n885\n may be located at the surface.', 'FIG.', '9\n is a representation of a communication system \n973\n, according to at least one embodiment of the present disclosure.', 'The communication system \n973\n may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to \nFIG.', '2\n-\n1\n through \nFIG.', '8\n.', 'The mud pulse telemetry system \n974\n may communicate information from the roll stabilized platform \n975\n to the rotating member \n976\n by using a control unit \n977\n to activate the solenoid \n978\n, which actuates the actuator \n979\n.', 'This may cause the mud pulse generator \n980\n to generate a series of pressure pulses in a drilling fluid.', 'The pressure pulses may propagate through the drilling fluid everywhere the drilling fluid is present.', 'The pressure pulses may include a first set of encoded data \n981\n-\n1\n, such as a platform measurement from the platform sensor \n983\n.', 'A drilling system \n984\n may receive the pressure pulses at a first receiver \n982\n-\n1\n.', 'In some embodiments, the first receiver \n982\n-\n1\n may be located on a downhole tool, such as an MWD, an expandable tool, or another downhole tool.', 'The drilling system \n984\n may include a processor \n985\n that may decode the first set of encoded data \n981\n-\n1\n using a decoding module \n986\n.', 'The decoded data may be analyzed with the analysis module \n987\n.', 'The drilling system \n984\n may further include a tool sensor \n988\n.', 'The tool sensor \n988\n may collect tool measurements and communicate them to the processor \n985\n.', 'The tool measurements may be the same, complementary, or different measurements than the platform measurements from the platform sensor \n983\n.', 'The analysis module \n987\n of the processor may analyze the tool measurements.', 'In some embodiments, the tool measurements may be analyzed simultaneously with, combined with, or compared to the platform measurements.', 'In other embodiments, the tool measurements may be analyzed independently of the platform measurements.', 'The drilling system \n984\n may further include a drilling system mud pulse generator \n989\n.', 'In some embodiments, the drilling system mud pulse generator \n989\n may be the same as the mud pulse generator \n980\n on the rotating member \n976\n, and the processor \n985\n may have independent control over the mud pulse generator \n989\n and in some embodiments may also have independent control over the mud pulse generator \n980\n.', 'In other embodiments, the drilling system mud pulse generator \n989\n may be different from the mud pulse generator \n980\n on the rotating member \n976\n.', 'The processor \n985\n may actuate the drilling system mud pulse generator \n989\n in a pattern encoding a second set of encoded data \n981\n-\n2\n.', 'In some embodiments, the second set of encoded data \n981\n-\n2\n may include data decoded from the first set of encoded data \n981\n-\n1\n.', 'For example, the second set of encoded data \n981\n-\n2\n may include the platform measurement, a summary of several platform measurements, an analysis of the platform measurement, or a comparison of the platform measurement with the tool measurement, or any combination of the foregoing.', 'In other embodiments, the second set of encoded data \n981\n-\n2\n may include other information, such as the tool measurement.', 'In still other embodiments, the second set of encoded data \n981\n-\n2\n may include a combination of data decoded from the first set of encoded data \n981\n-\n1\n and other information, such as analysis by the analysis module \n987\n, the tool measurement, or any combination of the foregoing.', 'The communication system \n973\n may further include a second receiver \n982\n-\n2\n.', 'The second receiver \n982\n-\n2\n may be located at a different location than the first receiver \n982\n-\n1\n.', 'For example, the first receiver \n982\n-\n1\n may be located on a downhole tool, and the second receiver \n982\n-\n2\n may be located at a surface location.', 'In some embodiments, pressure pulses including the first set of encoded data \n981\n-\n1\n may be received at both the first receiver \n982\n-\n1\n and the second receiver \n982\n-\n2\n.', 'Furthermore, the pressure pulses including the second set of encoded data \n981\n-\n2\n may be received at the second receiver \n982\n-\n2\n.', 'In this manner, both the mud pulse telemetry system \n974\n and the drilling system \n984\n may independently communicate with the surface (via the second receiver \n982\n-\n2\n).', 'In other embodiments, the first receiver \n982\n-\n1\n and the second receiver \n982\n-\n2\n may both be located at a surface location, or may both be surface receivers.', 'In some embodiments, the mud pulse telemetry system \n974\n and the drilling system \n984\n may generate pressure pulses at the same frequency.', 'In other words, the first set of encoded data \n981\n-\n1\n may be encoded and transmitted as a first set of pressure pulses in a first pattern having a first frequency, and the second set of encoded data \n981\n-\n2\n is encoded and transmitted as a second set of pressure pulses in a second pattern having a second frequency, the first frequency and the second frequency being the same.', 'If the first and the second frequency are the same, then the first set of pressure pulses and the second set of pressure pulses may not be transmitted at the same time without loss of information.', "In other words, some or all of the first set of encoded data \n981\n-\n1\n may be lost in the second set of encoded data \n981\n-\n2\n, some or all of the second set of encoded data \n981\n-\n2\n may be lost in the first set of encoded data \n981\n-\n1\n, or some or all of both the first set of encoded data \n981\n-\n1\n and the second set of encoded data \n981\n-\n2\n may be lost in each other's signals.", 'In other words, the first set of pressure pulses may not overlap the second set of pressure pulses without loss of data.', 'To prevent overlap of the first set of pressure pulses with the second set of pressure pulses, the drilling system \n984\n may wait for an end of the first set of pressure pulses before beginning to generate or transmit the second set of pressure pulses.', 'In some embodiments, the drilling system \n984\n may wait for a gap in the first set of pressure pulses before beginning to generate or transmit the second set of pressure pulses.', 'For example, the drilling system \n984\n may wait for a gap in pressure pulses of a predetermined length.', 'After the gap in pressure pulses has extended for the predetermined length, the drilling system may determine that the first set of pressure pulses has ended, and begin generating or transmitting the second set of pressure pulses.', 'In some embodiments, the drilling system \n984\n may begin the second set of pressure pulses with an identifying pattern, indicating that the drilling system \n984\n is generating the pressure pulses.', 'In some embodiments, the drilling system \n984\n may wait for an “end-code” at the end of the first set of pressure pulses.', 'The end-code may also be called a “handshake.”', 'An end-code may be a unique pattern of pressure pulses that signals an end to the transmission of the first set of encoded data \n981\n-\n1\n.', 'When the decoding module \n986\n decodes the end-code, the analysis module \n987\n may interpret the end-code to determine that the first set of pressure pulses has been completely transmitted, or that all of the first set of encoded data \n981\n-\n1\n has been received.', 'The processor \n985\n may then actuate the drilling system mud pulse generator \n989\n in the second pattern.', 'In this manner, the processor \n985\n may reduce or prevent overlap between the first set of pressure pulses and the second set of pressure pulses.', 'It should be understood that while embodiments of the system have been described as having a receiver on the drilling system \n984\n, each of the above embodiments could include a telemetry system \n974\n (e.g., the roll stabilized platform described above) also having a receiver (or the telemetry system \n974\n could have a receiver instead of the drilling system \n984\n).', 'In such embodiments, the roll stabilized platform \n975\n could include a receiver that listens for mud pulses or otherwise senses changes in flow from the drilling system \n984\n mud pulse generator \n989\n.', 'Those signals could be decoded and used as described above with respect to receivers.', 'In addition, the telemetry system \n974\n receiver could wait for a gap, listen for an end-code or handshake, as described above, and then could transmit mud pulses using mud pulse generator \n980\n so as to prevent overlap of mud pulse signals.', 'As such, the telemetry system \n974\n and the drilling system \n984\n could both receive and transmit signals and could communicate cooperatively to prevent overlap of signals that would prevent the loss of signal.', 'In some embodiments, the mud pulse telemetry system \n974\n and the drilling system \n984\n may generate pressure pulses at different frequencies.', 'In other words, the first frequency may be different from the second frequency.', 'In some embodiments, the first set of pressure pulses may have a higher frequency than the second set of pressure pulses.', 'In other embodiments, the second set of pressure pulses may have a lower frequency than the first set of pressure pulses.', 'In this manner, the mud pulse telemetry system \n974\n may transmit the first set of encoded data \n981\n-\n1\n at the same time that the drilling system \n984\n transmits the second set of encoded data \n981\n-\n2\n.', 'In other words, generating the first set of pressure pulses may overlap in time generating the second set of pressure pulses.', 'The second receiver \n982\n-\n2\n may receive the overlapping (or simultaneously transmitted) first set of pressure pulses and second set of pressure pulses.', 'A processor (not shown) in electronic communication with the second receiver \n982\n-\n2\n may then decode the first set of encoded data \n981\n-\n1\n and the second set of encoded data \n981\n-\n2\n.', 'In some embodiments, the drilling system \n984\n may receive the first set of encoded data \n981\n-\n1\n at the same time that it is generating or transmitting the second set of encoded data \n981\n-\n2\n.\n \nFIG.', '10\n is a method chart representing a method \n1090\n for downhole communication.', 'The method may include generating pressure pulses in a pattern using a mud pulse generator in communication with a roll stabilized platform at \n1091\n.', 'The mud pulse generator may be in communication with the roll stabilized platform by a downhole connection.', 'The downhole connection may include a solenoid on the roll stabilized platform.', 'Activating and deactivating the solenoid may actuate and de-actuate an actuation valve for the mud pulse generator.', 'By activating and/or deactivating the solenoid in a pattern, the roll stabilized platform may communicate information to the mud pulse generator.', 'The pattern may include encoded data, such as a measurement or instructions to change a drilling parameter of a downhole tool.', 'The pressure pulses may be generated by actuating the pressure pulse generator using a solenoid on the roll stabilized platform that moves an actuator on a rotating platform.', 'The method \n1090\n may further include measuring a measurement at the roll stabilized platform with a sensor, the encoded data including the measurement.', 'The pressure pulses may be received at a receiver at \n1092\n.', 'The pressure pulses may be received at a surface location or at a downhole tool.', 'The encoded data may then be decoded from the pattern at \n1093\n.', 'A processor in electronic communication with the receiver may perform the decoding.', 'The decoded information may include instructions, and the processor may execute the instructions.', 'For example, the processor may change a drilling parameter of a downhole tool based on the instructions in the decoded data.', 'In other examples, the processor may instruct a sensor to take a measurement based on the decoded data or instructions included in the encoded data.\n \nFIG.', '11\n is a method chart of a method \n1190\n for downhole communication.', 'The method \n1190\n may include generating a first set of pressure pulses in a first pattern with a first frequency using a pressure pulse generator in communication with a roll stabilized platform at \n1191\n.', 'The mud pulse generator may be in communication with the roll stabilized platform by a downhole connection.', 'The downhole connection may include a solenoid on the roll stabilized platform.', 'Activating and deactivating the solenoid may actuate and de-actuate an actuation valve for the mud pulse generator.', 'By activating and/or deactivating the solenoid in a pattern, the roll stabilized platform may communicate information to the mud pulse generator.', 'The first pattern may include a first set of encoded data, or in other words, information may be encoded into the first pattern.', 'The method \n1190\n may further include receiving the first set of pressure pulses at a first receiver at \n1194\n.', 'Receiving the first set of pressure pulses may include receiving the first set of pressure pulses at a surface location or at a downhole tool, or, in other words, the first receiver may be located at a surface location or at a downhole tool.', 'The method may further include decoding the first set of encoded data with a processor in electronic communication with the first receiver.', 'The method \n1190\n may include generating a second set of pressure pulses in a second pattern with a second frequency at a downhole tool at \n1195\n.', 'The second pattern may include a second set of encoded data.', 'The method \n1190\n may further include receiving the second set of pressure pulses at a second receiver at \n1196\n.', 'Receiving the second set of pressure pulses may include receiving the second set of pressure pulses at a surface location or at the downhole tool, or, in other words, the second receiver may be located at a surface location or at the downhole tool.', 'The method may further include decoding the second set of encoded data with a processor in electronic communication with the second receiver.', 'In some embodiments, the method \n1190\n may include incorporating the first set of encoded data from the first set of pressure pulses into a second set of encoded data encoded into the second set of pressure pulses.', 'In some embodiments, the first frequency and the second frequency may be the same.', 'In this manner, the method \n1190\n may include waiting for an end of the first set of pressure pulses before generating the second set of pressure pulses at the downhole tool.', 'This may include signaling the end of the first set of pressure pulses with an end-code at the end of the first set of pressure pulses.', 'In other embodiments, the first frequency and the second frequency may be different.', 'In this manner, generating the first set of pressure pulses may at least partially temporally overlap, or at least partially overlap in time, generating the second set of pressure pulses.', 'Therefore, receiving the second set of pressure pulses at the second receiver may include receiving the first set of pressure pulses at the second receiver.', 'In other words, receiving the second set of pressure pulses may include simultaneously receiving the first set of pressure pulses and the second set of pressure pulses at the second receiver without losing any of the first set of encoded data or the second set of encoded data.', 'In some embodiments, the first receiver and the second receiver may be the same.', 'For example, the downhole tool may not include a receiver, but may include a mud pulse generator.', 'Therefore, the first set of pressure pulses may be generated at a roll stabilized platform and the second set of pressure pulses may be generated at different downhole tool.', 'The first set of pressure pulses may have a different frequency than the second set of pressure pulses.', 'Thus, a single receiver, or only one receiver, may receive both the first set of pressure pulses and the second set of pressure pulses.', 'In some embodiments, the single receiver may be located at a surface location.', 'In other embodiments, the single receiver may be located at a downhole location.', 'The embodiments of the communication system have been primarily described with reference to wellbore drilling operations; the communication systems described herein may be used in applications other than the drilling of a wellbore.', 'In other embodiments, communication systems according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources.', 'For instance, communication systems of the present disclosure may be used in a borehole used for placement of utility lines.', 'Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.', 'One or more specific embodiments of the present disclosure are described herein.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'It should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'The scope of the disclosure is, therefore, indicated by the appended claims rather than by the foregoing description.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.']

['1.', 'A downhole communication system, comprising:\na roll stabilized platform;\na mud pulse generator;\na pilot valve including a moving member rotatable relative to the roll stabilized platform, wherein the moving member is movable from a first position to a second position to open a flow path to the mud pulse generator;\na solenoid;\na conductor attracted to the solenoid when the solenoid is activated;\na first gap between the solenoid and the conductor;\na second gap between the conductor and the moving member; and\na receiver configured to receive a pressure pulse generated by the mud pulse generator.', '2.', 'The downhole communication system of claim 1, the receiver being located on a downhole tool.', '3.', 'The downhole communication system of claim 2, the receiver being located on a measuring while drilling (“MWD”) sub.', '4.', 'The downhole communication system of claim 1, the receiver including a plurality of receivers.', '5.', 'The downhole communication system of claim 1, the roll stabilized platform including a rotary steerable system.', '6.', 'The downhole communication system of claim 1, the roll stabilized platform controlling the mud pulse generator.', '7.', 'The downhole communication system of claim 1, wherein the second gap is present between the conductor and the moving member when the moving member is in the second position.', '8.', 'A method for downhole communication, the method comprising:\ngenerating a first set of pressure pulses using a mud pulse generator in communication with a roll stabilized platform, the first set of pressure pulses being generated in a first pattern having a first frequency, wherein generating the first set of pressure pulses includes the roll stabilized platform actuating a pilot valve for the mud pulse generator, wherein actuating the pilot valve includes actuating a moving member connected to the pilot valve, the moving member rotating at a different rotational rate than the roll stabilized platform;\nreceiving the first set of pressure pulses at a first receiver;\ngenerating a second set of pressure pulses at a downhole tool, the second set of pressure pulses being generated in a second pattern having a second frequency; and\nreceiving the second set of pressure pulses at a second receiver.', '9.', 'The method of claim 8, wherein actuating the pilot valve includes activating a solenoid rotationally fixed to the roll stabilized platform.', '10.', 'The method of claim 8, further comprising:\nincorporating a first set of encoded data encoded into the first set of pressure pulses; and\nincorporating a second set of encoded data encoded into the second set of pressure pulses at the downhole tool.\n\n\n\n\n\n\n11.', 'The method of claim 8, further comprising measuring a measurement on the roll stabilized platform, and wherein the first set of pressure pulses being generated in the first pattern includes encoding the measurement into the first pattern.', '12.', 'The method of claim 11, the first receiver being located on the downhole tool, and further comprising changing at least one drilling parameter based on the measurement.', '13.', 'The method of claim 8, the first frequency being different than the second frequency.', '14.', 'The method of claim 8, wherein generating the second set of pressure pulses at the downhole tool includes generating the second set of pressure pulses with the mud pulse generator.', '15.', 'The method of claim 8, further comprising rotating the downhole tool at a different rotational rate than the roll stabilized platform.']

['FIG.', '1 is a drilling system, according to at least one embodiment of the present disclosure;; FIG.', '2-1 is a cross-sectional view of a downhole connection, according to at least one embodiment of the present disclosure;; FIG.', '2-2 is another cross-sectional view of the downhole connection of FIG.', '2-1, according to at least one embodiment of the present disclosure;; FIG. 3 is a cross-sectional view of a downhole connection, according to at least one embodiment of the present disclosure;; FIG.', '4 is a cross-sectional view of a downhole telemetry system, according to at least one embodiment of the present disclosure;; FIG.', '5 is a cross-sectional view of another downhole telemetry system, according to at least one embodiment of the present disclosure;; FIG.', '6 is a cross-sectional view of yet another downhole telemetry system, according to at least one embodiment of the present disclosure;; FIG. 7 is a schematic of a communication system, according to at least one embodiment of the present disclosure;; FIG. 8 is a schematic of another communication system, according to at least one embodiment of the present disclosure;; FIG.', '9 is a schematic of yet another communication system, according to at least one embodiment of the present disclosure;; FIG.', '10 is a method chart of a method for downhole communication, according to at least one embodiment of the present disclosure; and; FIG.', '11 is a method chart of another method for downhole communication, according to at least one embodiment of the present disclosure.; FIG.', '2-1 is a representation of a downhole connection 212, according to at least one embodiment of the present disclosure.', 'The downhole connection 212 may include a rotating member 214 and an independently rotating member 216.', 'The rotating member 214 and the independently rotating member 216 may be rotationally independent of each other.', 'For example, the rotating member 214 may include a downhole sub 218 that rotates in synch with the collar (e.g., at the drill rig 103 of FIG. 1) and/or the drill bit (e.g., the bit 110 of FIG. 1).', 'In some embodiments, the downhole sub 218 may be a drill pipe (e.g., the drill string 105 of FIG.', '1).', 'In other embodiments, the downhole sub 218 may be a downhole tool, or a portion of the BHA (e.g., the BHA 106 of FIG. 1).; FIG.', '2-2 shows the downhole connection 212 in a second position, with the moving member 242 in the moving member second position.', 'In the moving member second position, the moving member 242 may be located in the opening 232 such that it is closer to the solenoid 222 than in the moving member first position (i.e., closer to the extension 226 of the independently rotating platform 220, or to a downhole end 251 of the solenoid 222).; FIG. 3 is a representation of an embodiment of a downhole telemetry system 352.', 'The downhole telemetry system 352 may include at least some of the same features and characteristics as the connections described in relation to FIG.', '2-1 and FIG.', '2-2.', 'In some embodiments, the downhole telemetry system 352 may include a rotating member 314 and an independently rotating member 316.', 'The independently rotating member 316 may include a roll stabilized platform 320.', 'An extension 326 from the uphole end of the roll stabilized platform 320 may be connected to a solenoid 322.', 'A magnetic conductor 328 may be offset from the solenoid 322.', 'The magnetic conductor 328 may be connected to an actuation valve 344, the actuation valve 344 including a flow restrictor 346 that may restrict flow to a flow path 348 based on the position of a moving member 342.; FIG.', '4 is a representation of a downhole telemetry system 452, according to at least one embodiment of the present disclosure.', 'The downhole telemetry system 452 may include at least some of the same features and characteristics as the downhole telemetry systems and connections described in relation to FIG.', '2-1 through FIG.', '3.', 'In some embodiments, the downhole telemetry system 452 may include a rotating member 414 and an independently rotating member 416.', 'The independently rotating member 416 may include a roll stabilized platform 420.', 'An extension 426 from the uphole end of the roll stabilized platform 420 may be connected to a solenoid 422.', 'A magnetic conductor 428 may be offset from the solenoid 422 and a moving member 442 may be offset from the magnetic conductor 428.', 'The magnetic conductor 428 may be connected to an actuation valve 444, the actuation valve 444 actuating a mud pulse generator 456.', 'Therefore, the actuation valve 444 may be a pilot valve for the mud pulse generator 456.', 'In this manner, the roll stabilized platform 420 may be in communication with the mud pulse generator 456.', 'In other words, the roll stabilized platform 420 may activate and/or deactivate the solenoid 422 in the pattern, thereby actuating and/or de-actuating the actuation valve 444.', 'This may allow the roll stabilized platform 420 to communicate information to the mud pulse generator 456.', 'This may further allow the roll stabilized platform 420 to communicate information with elements of a drilling system that do not rotate at the same rate as the roll stabilized platform.; FIG.', '5 is a representation of a drilling system 500, according to at least one embodiment of the present disclosure.', 'The drilling system 500 may include at least some of the same features and characteristics as the downhole telemetry systems and connections described in relation to FIG.', '2-1 through FIG.', '4.', 'The drilling system 500 may include a drill rig 503 located at a surface location that operate a BHA 506 connected to the downhole end of a drill string 505.; FIG.', '6 is a representation of a drilling system 600, according to at least one embodiment of the present disclosure.', 'The drilling system 600 may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to FIG.', '2-1 through FIG.', '5.', 'The drilling system 600 may include a drill rig 603 located at a surface location that operate a BHA 606 connected to the downhole end of a drill string 605.; FIG.', '7 is a representation of a communication system 773, according to at least one embodiment of the present disclosure.', 'The communication system 773 may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to FIG.', '2-1 through FIG.', '6.', 'The communication system 773 may include a downhole mud pulse telemetry system 774, including a roll stabilized platform 775 and a rotating member 776.', 'The roll stabilized platform 775 may include a platform control unit 777 and a solenoid 778.', 'The rotating member may include an actuator 779 and a mud pulse generator 780.; FIG.', '8 is a representation of a communication system 873, according to at least one embodiment of the present disclosure.', 'The communication system 873 may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to FIG.', '2-1 through FIG.', '7.', 'In the embodiment shown, the roll stabilized platform 875 may include one or more sensors 883.', 'The one or more sensors 883 may measure a measurement.', 'The platform control unit 877 may encode the measurement into a pattern and activate the solenoid 878 in the pattern.', 'The solenoid 878 may then actuate the actuator 879', 'and therefore the mud pulse generator 880 in the pattern.', 'In this manner, the mud pulse telemetry system 874 may communicate encoded data 881 measured on a roll stabilized platform 875 to a rotating member 876.; FIG.', '9 is a representation of a communication system 973, according to at least one embodiment of the present disclosure.', 'The communication system 973 may include at least some of the same features and characteristics as the drilling systems, downhole telemetry systems and connections described in relation to FIG.', '2-1 through FIG.', '8.', 'The mud pulse telemetry system 974 may communicate information from the roll stabilized platform 975 to the rotating member 976 by using a control unit 977 to activate the solenoid 978, which actuates the actuator 979.', 'This may cause the mud pulse generator 980 to generate a series of pressure pulses in a drilling fluid.', 'The pressure pulses may propagate through the drilling fluid everywhere the drilling fluid is present.', 'The pressure pulses may include a first set of encoded data 981-1, such as a platform measurement from the platform sensor 983.; FIG.', '10 is a method chart representing a method 1090 for downhole communication.', 'The method may include generating pressure pulses in a pattern using a mud pulse generator in communication with a roll stabilized platform at 1091.', 'The mud pulse generator may be in communication with the roll stabilized platform by a downhole connection.', 'The downhole connection may include a solenoid on the roll stabilized platform.', 'Activating and deactivating the solenoid may actuate and de-actuate an actuation valve for the mud pulse generator.', 'By activating and/or deactivating the solenoid in a pattern, the roll stabilized platform may communicate information to the mud pulse generator.', 'The pattern may include encoded data, such as a measurement or instructions to change a drilling parameter of a downhole tool.', 'The pressure pulses may be generated by actuating the pressure pulse generator using a solenoid on the roll stabilized platform that moves an actuator on a rotating platform.', 'The method 1090 may further include measuring a measurement at the roll stabilized platform with a sensor, the encoded data including the measurement.; FIG.', '11 is a method chart of a method 1190 for downhole communication.', 'The method 1190 may include generating a first set of pressure pulses in a first pattern with a first frequency using a pressure pulse generator in communication with a roll stabilized platform at 1191.', 'The mud pulse generator may be in communication with the roll stabilized platform by a downhole connection.', 'The downhole connection may include a solenoid on the roll stabilized platform.', 'Activating and deactivating the solenoid may actuate and de-actuate an actuation valve for the mud pulse generator.', 'By activating and/or deactivating the solenoid in a pattern, the roll stabilized platform may communicate information to the mud pulse generator.', 'The first pattern may include a first set of encoded data, or in other words, information may be encoded into the first pattern.', 'The method 1190 may further include receiving the first set of pressure pulses at a first receiver at 1194.', 'Receiving the first set of pressure pulses may include receiving the first set of pressure pulses at a surface location or at a downhole tool, or, in other words, the first receiver may be located at a surface location or at a downhole tool.', 'The method may further include decoding the first set of encoded data with a processor in electronic communication with the first receiver.']

US11978944

Downhole communication devices and systems

Jul 21, 2020

Xavier Benoist, Nicolas Mornet, Alexander Hickson, Mohamed Abdeliamin Saad

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion in International Patent Application No. PCT/US2020/042844, dated Oct. 30, 2020, 12 pages.; Twaites, N., et al., “Use of Near Bit Azimuthal Gamma Ray and Inclination Tool Improves Geosteering in CBM Wells, Airth Field, Scotland”, SPE 167700, SPE/EAGE European Unconventional Conference and Exhibition, Vienna, Austria, Feb. 25-27, 2014, 12 pages.; Schlumberger, “Powered Rotary Steerable System Boosts Deepwater Well ROP 257%”, Case Study, accessed from: https://www.slb.com/-/media/files/drilling/case-study/pdvortex-angola-deepwater-cs.ashx, 2011, 2 pages.

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['A downhole communication includes an antenna winding fixed to an inner surface of a collar.', 'A fluid flow flows through a center of the antenna winding.', 'The antenna winding is wound around a chassis in an antenna channel in the chassis.', 'The chassis is attached to the inner surface of the collar with a seal such that fluid does not travel between the fluid flow and an annulus between the antenna winding and the inner surface of the collar.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application claims the benefit of U.S. Provisional Application No. 62/877,644 entitled “Downhole Communication Devices and Systems,” filed Jul. 23, 2019, the disclosure of which is incorporated herein by reference.', 'BACKGROUND OF THE DISCLOSURE\n \nWellbores may be drilled into a surface location or seabed for a variety of exploratory or extraction purposes.', 'For example, a wellbore may be drilled to access fluids, such as liquid and gaseous hydrocarbons, stored in subterranean formations and to extract the fluids from the formations.', 'Wellbores used to produce or extract fluids may be lined with casing around the walls of the wellbore.', 'A variety of drilling methods may be utilized depending partly on the characteristics of the formation through which the wellbore is drilled.', 'A drilling system can provide weight on the bit using one or more drill collars positioned in a bottomhole assembly near the bit.', 'Bottomhole assemblies also include communication devices to transmit information about the bit and other downhole parameters to receiving devices uphole from the bit.', 'Conventional drill collars reduce or block the electromagnetic signals transmitted from the communication devices in the bottomhole assembly.', 'SUMMARY\n \nIn some embodiments, a downhole antenna package includes a collar with an inner surface.', 'An antenna winding is fixed to the inner surface of the collar with an offset.', 'In other embodiments, a collar has an inner surface facing a central bore.', 'An antenna winding is attached to the inner surface and an entirety of a fluid flow through the central bore flows through a center of the antenna winding.', 'In yet other embodiments, a downhole communication system includes a collar with an inner surface.', 'A chassis includes a first stabilizer point and a second stabilizer point.', 'An antenna winding surrounds at least a portion of the chassis.', 'A distance between the first stabilizer point and the second stabilizer point is less than 150% of an antenna length.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Additional features and advantages of embodiments of the disclosure will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by the practice of such embodiments.', 'The features and advantages of such embodiments may be realized and obtained by means of the instruments and combinations particularly pointed out in the appended claims.', 'These and other features will become more fully apparent from the following description and appended claims, or may be learned by the practice of such embodiments as set forth hereinafter.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'In order to describe the manner in which the above-recited and other features of the disclosure can be obtained, a more particular description will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings.', 'For better understanding, the like elements have been designated by like reference numbers throughout the various accompanying figures.', 'While some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale.', 'Understanding that the drawings depict some example embodiments, the embodiments will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:\n \nFIG.', '1\n is a schematic representation of a drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n1\n is a longitudinal cross-sectional view of a downhole communication system, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n2\n is a detailed longitudinal cross-sectional view of the downhole communication system of \nFIG.', '2\n-\n1\n, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n3\n is a transverse cross-sectional view of the downhole communication system of \nFIG.', '2\n-\n1\n, according to at least one embodiment of the present disclosure;\n \nFIG.', '3\n is longitudinal cross-sectional view of another downhole communication system, according to at least one embodiment of the present disclosure;\n \nFIG.', '4\n is a longitudinal cross-sectional view of still another downhole communication system, according to at least one embodiment of the present disclosure;\n \nFIG.', '5\n is a perspective view of a chassis, according to at least one embodiment of the present disclosure;\n \nFIG.', '6\n-\n1\n is a longitudinal cross-sectional view of yet another downhole communication system, according to at least one embodiment of the present disclosure;\n \nFIG.', '6\n-\n2\n is another longitudinal cross-sectional view of the downhole communication system of \nFIG.', '6\n-\n1\n, according to at least one embodiment of the present disclosure; and\n \nFIG.', '7\n is a schematic representation of a downhole communication system, according to at least one embodiment of the present disclosure.', 'DETAILED DESCRIPTION', 'This disclosure generally relates to devices, systems, and methods for downhole antennas used in downhole communication systems.', 'In some embodiments described herein, a downhole antenna may have a sensitivity of less than 1 nanotesla (nT) while attached to a bottomhole assembly (“BHA”).\n \nFIG.', '1\n shows one example of a drilling system \n100\n for drilling an earth formation \n101\n to form a wellbore \n102\n.', 'The drilling system \n100\n includes a drill rig \n103\n used to turn a drilling tool assembly \n104\n which extends downward into the wellbore \n102\n.', 'The drilling tool assembly \n104\n may include a drill string \n105\n, a BHA \n106\n, and a bit \n110\n, attached to the downhole end of drill string \n105\n.', 'The drill string \n105\n may include several joints of drill pipe \n108\n connected end-to-end through tool joints \n109\n.', 'The drill string \n105\n transmits drilling fluid through a central bore and transmits rotational power from the drill rig \n103\n to the BHA \n106\n.', 'In some embodiments, the drill string \n105\n may further include additional components such as subs, pup joints, etc.', 'The drill pipe \n108\n provides a hydraulic passage through which drilling fluid is pumped from the surface.', 'The drilling fluid discharges through selected-size nozzles, jets, or other orifices in the bit \n110\n for the purposes of cooling the bit \n110\n and cutting structures thereon, and for lifting cuttings out of the wellbore \n102\n as it is being drilled.', 'The BHA \n106\n may include the bit \n110\n or other components.', 'An example BHA \n106\n may include additional or other components (e.g., coupled between to the drill string \n105\n and the bit \n110\n).', 'Examples of additional BHA components include drill collars, stabilizers, measurement-while-drilling (“MWD”) tools, logging-while-drilling (“LWD”) tools, downhole motors, steering tools, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'In general, the drilling system \n100\n may include other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves).', 'Additional components included in the drilling system \n100\n may be considered a part of the drilling tool assembly \n104\n, the drill string \n105\n, or a part of the BHA \n106\n depending on their locations in the drilling system \n100\n.', 'The bit \n110\n in the BHA \n106\n may be any type of bit suitable for degrading downhole materials.', 'For instance, the bit \n110\n may be a drill bit suitable for drilling the earth formation \n101\n.', 'Example types of drill bits used for drilling earth formations are fixed-cutter or drag bits.', 'In other embodiments, the bit \n110\n may be a mill used for removing metal, composite, elastomer, other materials downhole, or combinations thereof.', 'For instance, the bit \n110\n may be used with a whipstock to mill into casing \n107\n lining the wellbore \n102\n.', 'The bit \n110\n may also be a junk mill used to mill away tools, plugs, cement, other materials within the wellbore \n102\n, or combinations thereof.', 'Swarf or other cuttings formed by use of a mill may be lifted to surface, or may be allowed to fall downhole.', 'Conventionally, an antenna for a wireless downhole communication system may be mounted on a mandrel located in a central bore of a collar.', 'Fluid flow through the collar may flow around an outer surface of the mandrel (e.g., between the inner surface of the collar and the outer surface of the mandrel).', 'Because of its location inside the collar, a mandrel may protect the antenna from impacts against a borehole wall or a casing.', 'However, the mandrel may vibrate during normal drilling operations.', 'The mandrel, and therefore the antenna, may vibrate with greater frequency and/or amplitude than the collar.', 'The vibration of the mandrel may degrade the signal received and/or transmitted by the antenna, thereby reducing the range and/or reliability of the conventional downhole communication system.', 'Alternatively, conventional downhole communication systems may mount the antenna on an outer surface of the collar.', 'This may reduce the vibrational frequency and/or amplitude experienced by the antenna.', 'However, attaching the antenna to the outer surface of the collar may expose it to damage through contact with the borehole wall or casing, thereby decreasing the service life of the antenna.', 'At least one embodiment described herein overcomes the vibration issues of antennas in a mandrel and the damage issues of external antennas.\n \nFIG.', '2\n-\n1\n is a cross-sectional view of a representation of a downhole communication system \n212\n, according to at least one embodiment of the present disclosure.', 'The downhole communication system \n212\n is a wireless communication system.', 'In other words, the downhole communication system \n212\n is configured to receive and/or transmit wireless signals from other locations downhole and/or on the surface.', 'The downhole communication system \n212\n includes an antenna winding \n216\n fixed to a collar \n214\n.', 'The collar \n214\n may be any portion of a drill string (e.g., drill string \n105\n of \nFIG.', '1\n) or a BHA (e.g., BHA \n106\n of \nFIG.', '1\n).', 'For example, the collar \n214\n may be located on a sub that houses a downhole tool, such as an MWD, an LWD, a mud motor, an expandable tool such as a reamer or a stabilizer, or any other downhole tool.', 'In other examples, the collar \n214\n may be a tubular member of a drill string connected to a downhole tool or another tubular member of the drill string.', 'In still other embodiments, the collar \n214\n may be a member of or connected to any other portion of a downhole drilling system.', 'In some embodiments, the antenna winding \n216\n may be directly fixed to the collar \n214\n.', 'For example, the antenna winding \n216\n may be fixed to the collar \n216\n with a mechanical fastener fastened to the inner surface \n220\n of the collar \n216\n.', 'In other examples, the antenna winding \n216\n may be fastened to the inner surface \n220\n of the collar \n216\n with a weld, a braze, an epoxy, an adhesive, another attachment mechanism, or combinations of the foregoing.', 'The antenna winding \n216\n is fixed to an inner surface \n220\n of the collar \n214\n.', 'For example, in the embodiment shown, the antenna winding \n216\n is attached to a chassis \n222\n, and the chassis \n222\n is fixed to the inner surface \n220\n of the collar.', 'The antenna winding \n216\n is coaxial with a longitudinal axis \n218\n of the collar \n214\n.', 'In other embodiments, the antenna winding \n216\n may have a different longitudinal axis than the longitudinal axis \n218\n of the collar \n214\n.', 'In some embodiments, the chassis \n222\n may protect the antenna winding \n216\n from erosion, corrosion, or other damage caused by drilling fluid or other material flowing through the collar \n214\n.', 'In some embodiments, the chassis \n222\n may fix the antenna winding \n216\n to the inner surface \n220\n of the collar \n214\n.', 'In other words, the chassis \n222\n may secure, fix, or hold the antenna winding \n216\n radially (e.g., perpendicular to the longitudinal axis \n218\n) and/or longitudinally (e.g., parallel to the longitudinal axis \n218\n) to the chassis.', 'For example, the chassis \n222\n may have a threaded outer surface, and a portion of the inner surface \n220\n of the collar \n214\n may be threaded, and the chassis \n220\n may be threaded to the inner surface \n220\n of the collar \n214\n.', 'In other examples, the chassis \n222\n may be secured to the collar \n214\n using a mechanical fastener, such as a bolt, a screw, a jam nut, or other mechanical fastener.', 'In yet other examples, the chassis \n222\n may be secured to the collar with a weld, braze, adhesive, other attachment or any combination of attachment mechanisms described herein.', 'A fluid flow \n224\n, such as drilling mud, flows through a bore (e.g., central bore \n226\n) of the collar \n214\n.', 'In the embodiment shown, the central bore \n226\n is coaxial with and flows through a center \n228\n of the antenna winding \n216\n.', 'In other words, the fluid flow \n224\n flows through the center \n228\n of the antenna winding \n216\n.', 'In other embodiments, the bore may be offset (e.g., not coaxial with) the center \n228\n of the antenna winding \n216\n and/or the longitudinal axis \n218\n.', 'The chassis \n222\n may be hollow, and the center of the chassis may be the same as the center \n228\n of the antenna winding \n216\n.', 'Thus, the fluid flow \n224\n may flow unimpeded or relatively unimpeded from an uphole end \n225\n of the antenna winding \n216\n to a downhole end \n230\n of the antenna winding \n216\n.', 'Thus, the majority of, an entirety of, or all of the fluid flow \n224\n may flow through the center \n228\n of the antenna winding \n216\n.', 'In other words, no portion of the fluid flow \n224\n may flow between the antenna winding \n216\n and the inner surface \n220\n of the collar \n214\n.', 'For example, the fluid flow \n224\n has a mass flow rate between the uphole end \n225\n and the downhole end \n230\n, and an entirety of the mass flow rate flows through the center \n228\n of the antenna winding \n216\n.', 'Similarly, the fluid flow \n224\n has a volumetric flow rate between the uphole end \n225\n and the downhole end \n230\n, and an entirety of the volumetric flow rate flows through the center \n228\n of the antenna winding \n216\n.', 'Flowing the fluid through the center \n228\n of the antenna winding \n216\n may allow for a shorter chassis \n222\n, which may reduce the total length of the downhole communication system \n212\n.', 'The antenna winding \n216\n includes one or more windings or coils of an electromagnetically conductive element (e.g., wire), resulting in an antenna length \n227\n.', 'In other words, the antenna length \n227\n is the length from a first winding to a final winding of the antenna winding \n216\n.', 'In some embodiments, the antenna winding \n216\n may include 1, 2, 4, 6, 8, 10, 12, 14, 16, 18, 20, or more windings or coils of the electromagnetically conductive element.', 'In some embodiments, the antenna length \n227\n may be in a range having an upper value, a lower value, or upper and lower values including any of 40 millimeters (mm), 50 mm, 75 mm, 100 mm, 150 mm, 200 mm, 250 mm, 300 mm, 350 mm, 400 cmm, 450 cm, 500 cm, or any value therebetween.', 'For example, the antenna length \n227\n may be greater than 40 mm.', 'In another example, the antenna length \n227\n may be less than 500 mm.', 'In yet other examples, the antenna length \n227\n may be any value in a range between 40 mm and 500 mm.', 'In some embodiments, it may be critical that the antenna length \n227\n is approximately 125 mm for sufficient sensitivity of the antenna winding \n216\n.', 'The antenna winding \n216\n further has an antenna diameter \n229\n.', 'The antenna diameter \n229\n is the interior distance between opposite interior ends of a coil in the antenna winding \n216\n.', 'In some embodiments, the antenna diameter \n229\n is an inner diameter of the antenna winding \n216\n.', 'The antenna length \n227\n, in combination with the antenna diameter \n229\n results in an antenna enclosed area.', 'The number of coils of the antenna winding \n216\n, in combination with the enclosed area, may affect the sensitivity of the antenna winding \n216\n.', 'By increasing the antenna enclosed area, the sensitivity of the antenna winding \n216\n may be increased.', 'For a set number of windings (and therefore antenna length \n227\n), the sensitivity of the antenna winding \n216\n may be increased by increasing the antenna diameter \n229\n.', 'In some embodiments, the antenna diameter \n229\n may be in a range having an upper value, a lower value, or upper and lower values including any of 50 mm, 75 mm, 100 mm, 150 mm, 200 mm, 250 mm, 300 mm, or any value therebetween.', 'For example, the antenna diameter \n229\n may be greater than 50 mm.', 'In another example, the antenna diameter \n229\n may be less than 300 mm.', 'In yet other examples, the antenna diameter \n229\n may be any value in a range between 50 mm and 300 mm.', 'In some embodiments, it may be critical that the antenna diameter \n229\n of approximately 75 mm for sufficient sensitivity of the antenna winding \n216\n.', 'The antenna winding \n216\n has a length to width ratio, which is the ratio of the antenna length \n227\n to the antenna diameter \n229\n.', 'In some embodiments, the length to width ratio may be in a range having an upper value, a lower value, or upper and lower values including any of 1:5, 1:4, 1:3, 1:2, 1:1, 2:1, 3:1, 4:1, 5:1, or any value therebetween.', 'For example, the length to width ratio may be greater than 1:5.', 'In another example, the length to width ratio may be less than 5:1.', 'In yet other examples, the length to width ratio may be any value in a range between 1:5 and 5:1.', 'The collar \n214\n has a collar diameter \n231\n at the same longitudinal location as the antenna winding \n216\n.', 'The collar diameter \n231\n may be the same as or greater than the antenna diameter \n229\n.', 'In some embodiments, the collar diameter \n231\n may be greater than the antenna diameter \n229\n by double a wire thickness of a wire in the antenna winding \n216\n.', 'In other words, an outer surface of the antenna winding \n216\n may directly abut or contact the inner surface \n220\n of the collar \n214\n.', 'In other embodiments, the collar diameter \n231\n may be greater than the antenna diameter \n229\n by more than double the wire thickness of the wire.', 'For example, the collar diameter may be greater than the antenna diameter \n229\n by less than 2.5, 3, 4, 5, 6, 7, 8, 9, 10, or more multiples of the wire thickness of the wire.', 'In some embodiments, the collar diameter \n231\n may be greater than the antenna diameter \n229\n by a collar difference.', 'In some embodiments, the collar difference may be in a range having an upper value, a lower value, or upper and lower values including any of 2 millimeters (mm), 3 mm, 4 mm, 5 mm, 6 mm, 7 mm, 8 mm, 9 mm, 10 mm, 12 mm, 14 mm, 16 mm, 18 mm, 20 mm, 25 mm, or any value therebetween.', 'For example, the collar difference may be greater than 2 mm.', 'In another example, the collar difference may be less than 25 mm.', 'In yet other examples, the collar difference may be any value in a range between 2 mm and 25 mm.', 'In some embodiments, it may be critical that the collar difference is approximately 7.5 mm to maximize the antenna diameter and/or to reduce the reduction in flow area of the central bore.', 'In some embodiments, the collar \n214\n may include two or more pipe sections coupled together.', 'For example, the collar \n214\n may include a box and pin connection.', 'The antenna winding \n216\n may be secured to the collar \n214\n between the two ends, e.g., a male end (e.g., the pin) and the female end (e.g., the box) of the collar \n214\n.', 'In other words, the antenna winding \n216\n may be located between an uphole end and a downhole end of the collar \n214\n, the antenna length being a percentage of a length of the collar \n214\n.', 'In some embodiments, the antenna location may be in a range having an upper value, a lower value, or upper and lower values including any of 10%, 20%, 30%, 40%, 50%, 60%, 70%, 80%, 90% or any value therebetween.', 'For example, the antenna location may be greater than 10%.', 'In another example, the antenna location may be less than 90%.', 'In yet other examples, the antenna location may be any value in a range between 10% and 90%.', 'In some embodiments, it may be critical that the antenna location is between 25% and 75% to provide room for any onboard electronics inside the collar \n214\n.', 'In still other embodiments, the antenna winding \n216\n may be located on the inner surface \n220\n.\n \nFIG.', '2\n-\n2\n is a detailed cross-sectional view of the downhole communication system \n212\n of \nFIG.', '2\n-\n1\n, according to at least one embodiment of the present disclosure.', 'As may be seen, the antenna winding \n216\n is fixed to the inner surface \n220\n of the collar \n214\n.', 'In the embodiment shown, the antenna winding \n216\n is wound around the chassis \n222\n.', 'The chassis \n222\n is connected to the collar \n214\n, thereby fixing the antenna winding \n216\n to the inner surface of the collar \n214\n.', 'The chassis \n222\n may include an antenna channel \n232\n, which is a reduction in the thickness of the chassis \n222\n where the antenna winding \n216\n is located.', 'The antenna winding \n216\n is placed in the antenna channel \n232\n.', 'Therefore, when the chassis \n222\n is secured to the collar \n214\n, the antenna winding \n216\n is also secured or fixed to the collar \n214\n.', 'When the antenna winding \n216\n is placed in the antenna channel \n232\n, the antenna winding \n216\n (e.g., an outer surface of the antenna winding \n216\n) is radially offset or spaced from the inner surface \n220\n by a gap \n234\n.', 'In other words, an annulus \n236\n may exist between the antenna winding \n216\n and the inner surface \n220\n of the collar \n214\n.', 'In some embodiments, the annulus \n236\n may be filled with a gas, such as air from the surface or an inert gas such as nitrogen.', 'In other embodiments, the annulus \n236\n may be filled with a fluid, such as drilling fluid.', 'In yet other embodiments, the annulus \n236\n may be filled with a solid, such as epoxy or rubber.', 'In some embodiments, the gap \n234\n may less than 5 millimeters (mm).', 'In other embodiments, the gap \n234\n may be less than 3 mm.', 'In yet other embodiments, the gap \n234\n may be less than 2 mm.', 'In further embodiments, the gap \n234\n may be less than 1 mm.', 'In still further embodiments, the gap \n234\n may be 0 mm, or in other words, the antenna winding \n216\n may directly abut or directly contact the inner surface \n220\n of the collar \n214\n.', 'In some embodiments, it may be critical that the gap \n234\n is less than 3 mm for the sensitivity of the antenna winding \n216\n.', 'Furthermore, decreasing the gap \n234\n may increase the antenna diameter (e.g., antenna diameter \n229\n of \nFIG.', '2\n-\n1\n), thereby increasing the enclosed area.', 'Downhole drilling systems experience many different forces, torques, shocks and motions.', 'At least some of these forces, torques, and motions may result in a vibration of the downhole drilling system.', 'The vibration may be transferred through the downhole drilling system to the collar \n214\n and/or other elements of the downhole drilling system, such as the chassis \n222\n and the antenna winding \n216\n.', 'Motion of the antenna winding \n216\n may cause fluctuations in the electromagnetic field around the antenna winding \n216\n.', 'In some embodiments, the fluctuations in the electromagnetic field around the antenna winding \n216\n may cause interference in the receipt and/or transmission of an electromagnetic signal.', 'In some embodiments, an increase in the frequency and/or amplitude of the vibration of the antenna winding \n216\n may increase the interference in the receipt and/or transmission of the electromagnetic signal.', 'Downhole wireless communication systems may be low power systems.', 'In some embodiments, an antenna winding \n216\n may sense variations in the surrounding electromagnetic field of less than 1 nanotesla (nT).', 'In other embodiments, an antenna winding \n216\n may sense variations in the surrounding electromagnetic field of less than 0.1 nT. The sensitivity of the antenna winding \n216\n may affect the vibrational frequency that interferes with the receipt and/or transmission of signals by the antenna winding \n216\n.', 'Therefore, by reducing the vibrations experienced by the antenna winding \n216\n, the antenna winding \n216\n may be able to receive and/or transmit signals with greater accuracy and/or clarity.', 'The chassis \n222\n includes a first stabilization point \n238\n and a second stabilization point \n240\n.', 'The first stabilization point \n238\n is located uphole of the antenna winding \n216\n or uphole of the uphole end \n225\n of the antenna winding \n216\n.', 'The second stabilization point \n240\n is located downhole of the antenna winding \n216\n or downhole of the downhole end \n230\n of the antenna winding \n216\n.', 'The stabilization distance \n242\n is the distance between the first stabilization point \n238\n and the second stabilization point \n240\n.', 'The stabilization distance \n242\n is a stabilization percentage of the antenna length.', 'In some embodiments, the stabilization percentage may be in a range having an upper value, a lower value, or upper and lower values including any of 100%, 110%, 120%, 125%, 130%, 140%, 150%, 175%, 200%, 250%, 300%, or any value therebetween.', 'For example, the stabilization percentage may be 100% (e.g., the chassis \n222\n may be stabilized at the uphole end \n225\n and the downhole end \n230\n of the antenna winding \n216\n).', 'In another example, the stabilization percentage a maximum of 300%.', 'In yet other examples, the stabilization percentage may be any value in a range between 100% and 300%.', 'In some embodiments, it may be critical that the stabilization percentage is less than 150% to stabilize the chassis \n222\n and the antenna winding to the collar \n214\n.', 'A chassis \n222\n with long stabilization distance \n242\n may vibrate with a resonant frequency that is higher than the vibration frequency of the collar \n214\n.', 'Furthermore, a larger gap \n234\n may increase the vibration amplitude of the antenna winding \n216\n compared to the collar \n214\n.', 'An increase in the frequency and/or the amplitude of the vibration of the antenna winding \n216\n may increase the interference in the receipt and/or transmission of the electromagnetic signal.', 'Therefore, by decreasing one or both of the stabilization distance \n242\n or the gap \n234\n, the interference in the receipt and/or transmission of the electromagnetic signals may be reduced.', 'Reducing the interference may increase accuracy of received and/or transmitted signals, and/or increase the range of the downhole communication system \n212\n.', 'In at least one embodiment, a low stabilization percentage and/or a low gap \n234\n may stabilize the chassis \n222\n and/or the antenna winding \n216\n to the collar such that the antenna winding \n216\n vibrates at the or at substantially the same frequency and amplitude as the collar.', 'In other words, fixing the antenna winding \n216\n to the inner surface \n220\n of the collar \n214\n may reduce the vibration of the antenna winding \n216\n until the antenna winding vibrates in synch or simultaneously with the collar \n214\n.', 'In this manner, the interference in signal receipt and/or transmission may be reduced or eliminated.', 'Fixing the antenna winding \n216\n to the inner surface \n220\n of the collar \n214\n may reduce the length of the downhole communication system \n212\n by eliminating the need for a mandrel.', 'Furthermore, the chassis \n222\n may be fabricated from a wear and/or erosion resistant material.', 'In this manner, the chassis \n222\n may protect the antenna winding \n216\n from wear and/or erosion from the fluid flow \n224\n.', 'By placing the antenna winding \n216\n inside the collar \n214\n, the antenna winding \n216\n may be protected from contact with the borehole wall.', 'Thus, the antenna winding \n216\n may be cheaper to manufacture and have a longer operation lifetime.\n \nFIG.', '2\n-\n3\n is a transverse cross-sectional view of the downhole communication system \n212\n of \nFIG.', '2\n-\n1\n, according to at least one embodiment of the present disclosure.', 'As may be seen, the antenna winding \n216\n is internal to the collar \n214\n and concentric with the collar \n214\n about the longitudinal axis \n218\n.', 'The antenna winding \n216\n is supported by the chassis \n222\n.', 'The chassis \n222\n surrounds the central bore \n226\n of the collar \n214\n.', 'In the cross-sectional view shown, the central bore \n226\n runs through the center \n228\n of the antenna winding \n216\n.', 'A fluid flow (e.g., the fluid flow \n224\n of \nFIG.', '2\n-\n1\n) flows through the central bore \n226\n of the collar, and therefore through the center \n228\n of the antenna winding \n216\n.', 'The antenna winding \n216\n may have a smaller antenna diameter (e.g., antenna diameter \n229\n of \nFIG.', '2\n-\n1\n) than the collar diameter (e.g., the collar diameter \n231\n of \nFIG.', '2\n-\n1\n).', 'Thus, there is an annulus \n236\n between the antenna winding \n216\n and the collar \n214\n.', 'The annulus may be filled with any material, such as atmospheric gas, drilling fluid, epoxy, or other material.', 'In some embodiments, no fluid from the fluid flow may enter the annulus \n236\n.', 'In some embodiments, while mud is being pumped downhole from the surface, fluid flows through the center \n228\n and does not flow through the annulus \n236\n, and while some fluid may enter the annulus \n236\n, it does not substantially flow through the annulus \n236\n.\n \nFIG.', '3\n is a representation of a cross-sectional view of a downhole communication system \n312\n, according to at least one embodiment of the present disclosure.', 'An antenna winding \n316\n is attached to an inner surface \n320\n of a collar \n314\n.', 'A chassis \n322\n secures the antenna winding \n316\n to the inner surface \n320\n.', 'In the embodiment shown, the collar \n314\n includes a collar shoulder \n344\n.', 'The collar shoulder \n344\n is a portion of the collar \n314\n with an increased thickness.', 'In some embodiments, the collar shoulder \n344\n may extend perpendicularly from the inner surface \n320\n of the collar.', 'In other embodiments, the collar shoulder \n344\n may extend from the inner surface \n320\n with an acute or an obtuse angle.', 'In some embodiments, the collar \n314\n has a first diameter that extends from a first end of the collar \n314\n to the collar shoulder \n344\n.', 'At the collar shoulder \n344\n, the collar \n314\n increases in diameter to a second diameter that extends from the collar shoulder \n344\n to a second end of the collar \n314\n.', 'The antenna winding \n316\n is installed on the inner surface \n320\n next to the collar shoulder \n344\n at a downhole end \n330\n of the antenna winding \n316\n.', 'For example, the antenna winding \n316\n may be within 5 mm of the collar shoulder \n344\n.', 'In some embodiments, the antenna winding \n316\n may abut (e.g., a longitudinally outermost winding may directly contact) the collar shoulder \n344\n.', 'Installing the antenna winding \n316\n against the collar shoulder \n344\n may stabilize the antenna winding \n316\n from downhole motion parallel with the longitudinal axis \n318\n.', 'The chassis \n322\n includes an antenna channel \n332\n, in which the antenna winding \n316\n is secured to the chassis \n322\n.', 'In the embodiment shown, the antenna channel \n332\n includes an antenna shoulder \n346\n and a chassis shoulder \n348\n.', 'The antenna winding \n316\n may be secured to the antenna channel \n332\n next to or abutting up against the antenna shoulder \n346\n at an uphole end \n325\n of the antenna winding \n316\n.', 'The antenna shoulder \n346\n may stabilize the antenna winding \n316\n from uphole motion parallel with the longitudinal axis \n318\n.', 'In some embodiments, the antenna winding \n316\n may be secured to the chassis \n322\n using a mechanical fastener, such as a screw, a bolt, a nut, or any other mechanical fastener.', 'In other embodiments, the antenna winding \n316\n may be secured to the chassis \n322\n with epoxy, resin, or other hardened polymers, monomers, and so forth.', 'In still other embodiments, the antenna winding \n316\n may be secured to the chassis \n322\n using a weld, solder, braze, and the like.', 'The chassis \n322\n may be secured to or fixed to the inner surface \n320\n of the collar \n314\n.', 'The chassis may be secured to the inner surface \n320\n of the collar \n314\n at the collar shoulder \n344\n.', 'In other words, the chassis shoulder \n348\n may contact, rest against, or be supported by the collar shoulder \n344\n of the collar \n314\n.', 'In some embodiments, the chassis \n322\n may be connected to the collar \n314\n with a threaded connection, a bolted connection, one or more jam nuts, weld, braze, or other connection.', 'By securing the chassis shoulder \n348\n to the collar shoulder \n344\n, the chassis \n322\n may be secured to the collar \n314\n, and stabilized by the collar \n314\n.', 'This may reduce the amount of independent vibration experienced by the chassis \n322\n, and therefore the antenna winding \n316\n.', 'When the chassis \n322\n is secured to the collar \n314\n at the collar shoulder \n344\n, the antenna winding \n316\n may be secured against uphole longitudinal movement by the antenna shoulder \n346\n and downhole longitudinal motion by the collar shoulder \n344\n or by a mechanical fastener or other fastener that connects the antenna winding \n316\n to the chassis \n322\n.', 'A fluid flow \n324\n may flow through a central bore \n326\n of the collar \n314\n and through the center \n328\n of the antenna winding \n316\n.', 'The chassis \n322\n includes a seal (collectively \n350\n) to seal the antenna winding \n316\n from the fluid flow \n324\n.', 'The seal \n350\n includes an uphole seal \n350\n-\n1\n uphole of the antenna winding \n316\n and a downhole seal \n350\n-\n2\n downhole of the antenna winding.', 'Both the uphole seal \n350\n-\n1\n and the downhole seal \n350\n-\n2\n include a sealing element, such a one or more O-rings \n352\n.', 'For example, in the embodiment shown, the uphole seal \n350\n-\n1\n and the downhole seal \n350\n-\n2\n include two O-rings to provide increased seal for a high pressure differential.', 'In this manner, the antenna winding \n316\n may be sealed from the central bore \n326\n and the fluid flow \n324\n.', 'In other words, in some embodiments, no portion of the fluid flow \n324\n may contact the antenna winding \n316\n.', 'In some embodiments, an annulus \n336\n between the antenna winding \n316\n and the collar \n314\n may have an annular pressure that is a different pressure than a bore pressure in the central bore \n326\n.', 'This may be a result of the downhole communication system \n312\n being assembled on the surface, which may seal the annulus \n336\n from the central bore \n326\n at atmospheric pressure.', 'As the downhole communication system \n312\n is tripped into a wellbore, or as the wellbore advances through drilling, the bore pressure in the central bore \n326\n may increase, which may increase the pressure differential between the annular pressure in the annulus \n336\n and bore pressure in the central bore \n326\n.', 'In some embodiments, the chassis \n322\n may be designed to maintain the differential pressure between the central bore \n326\n and the annulus \n336\n.', 'In this manner, the antenna winding \n316\n may not be subjected to high pressures.', 'In this manner, the antenna winding \n316\n may be fabricated from more cost-effective parts, which may reduce the total cost of drilling.', 'In other embodiments, the annulus \n336\n may include a pressure relief system.', 'In this manner, the pressure differential between the annular pressure and the bore pressure may be equalized, which may improve performance of the antenna winding \n316\n.', 'The fluid flow \n324\n may be directional, meaning that the fluid may originate at the surface, flow through the drill string to the collar \n314\n, and flow through the collar \n314\n and the antenna winding \n316\n.', 'In the embodiment shown, the fluid flows from the left to the right.', 'In this manner, fluid enters the center \n328\n of the antenna winding \n316\n from the uphole end \n325\n of the antenna winding \n316\n and exits the center \n328\n from the downhole end \n330\n of the antenna winding.', 'In some embodiments, no portion of the fluid flow \n324\n that travels from the uphole end \n325\n to the downhole end \n330\n may enter the annulus \n336\n.', 'In other embodiments, the pressure equalization system may include a single port into the annulus \n336\n.', 'Thus, as the downhole communication system \n312\n is tripped downhole, and to equalize the pressure between the annulus \n336\n and the central bore \n326\n, a portion of fluid from the fluid flow may enter the annulus \n336\n through the single port.', 'When the downhole communication system \n312\n is tripped back uphole, the portion of the fluid flow may exit the annulus \n336\n through the single port.', 'Therefore, fluid does not flow through the annulus \n336\n.', 'In other words, fluid does not enter the annulus \n336\n from a first port and exit the annulus from a second, different port.', 'Rather, fluid may enter and exit the annulus \n336\n from the same, single port.', 'In still other embodiments, the single port may include a membrane separating the annulus \n336\n from the central bore \n326\n.', 'The annulus \n336\n may be filled with a liquid, such as hydraulic oil or another liquid.', 'As the pressure differential increases, the membrane may be pushed toward the annulus \n336\n.', 'This may increase the pressure of the liquid in the annulus \n336\n, thereby equalizing the pressure between the annulus \n336\n and the central bore \n326\n.', 'A membrane may reduce the contact of the antenna winding \n316\n with the drilling fluid, which may reduce wear on the antenna winding.\n \nFIG.', '4\n is a representation of a cross-sectional view of a downhole communication system \n412\n, according to at least one embodiment of the present disclosure.', 'In the embodiment shown, a board \n454\n extends from a collar shoulder \n444\n extending from an inner surface \n420\n of a collar \n414\n.', 'The board \n454\n is offset from the inner surface \n420\n.', 'In some embodiments, the board \n454\n includes a sensor, such as a nuclear sensor or other type of sensors.', 'In the same or other embodiments, the board \n454\n may include a printed circuit board and one or more processors.', 'The board \n454\n may be attached to the chassis \n422\n with a mechanical fastener, and the antenna winding \n416\n may be fixed or attached to the chassis \n422\n above the board \n454\n.', 'In this manner, the chassis \n422\n radially secures the antenna winding \n416\n and the board \n454\n to the inner surface \n420\n of the collar \n414\n.', 'In the embodiment shown, a single board \n454\n may secure the antenna winding \n416\n to the inner surface \n420\n of the collar \n414\n.', 'In other embodiments, a plurality of boards \n454\n, including 2, 3, 4, 5, 6, 7, 8, or more boards \n454\n may secure the antenna winding to the inner surface \n420\n.', 'In the embodiment shown, a chassis \n422\n longitudinally secures the antenna winding \n416\n to the inner surface \n420\n.', 'In this manner, the chassis \n422\n may provide erosion and/or wear protection and a seal between the antenna winding \n416\n and the central bore \n426\n of the collar \n414\n and the chassis \n422\n may provide the winding \n416\n protection from the pressure.', 'In other embodiments, the antenna winding \n416\n may be longitudinally secured to the collar \n414\n by the collar shoulder \n444\n and a set screw or other mechanical connection uphole of the antenna winding \n416\n.', 'Having the antenna coil \n416\n overlapping the board \n454\n may reduce the length of the chassis \n422\n.', 'In this manner, the length of the downhole communication system \n412\n may be reduced.', 'In this manner, the distance between the transmitter and the receiver may be reduced, which may increase the reliability of the downhole communication system \n412\n.', 'Furthermore, in some embodiments, the antenna winding \n416\n may be electrically connected to the board \n454\n where the board \n454\n is an electronic circuit board.', 'This may further reduce the complexity of the downhole communication system \n412\n, which may improve its reliability.\n \nFIG.', '5\n is a perspective view of a chassis \n522\n, according to a least one embodiment of the present disclosure.', 'In some embodiments, the chassis \n522\n includes a flow diverter \n555\n.', 'The flow diverter \n555\n may direct a fluid flow that flows through an annular space to tubular space.', 'The flow diverter \n555\n includes a central connection \n556\n.', 'In some embodiments, the central connection \n556\n may be configured to connect to an electronics package.', 'In other embodiments, the central connection \n556\n may be configured to connect to any downhole tool, such as a mud motor, an expandable tool, and MWD, an LWD, a mud pulse generator, or any other downhole tool.', 'The central connection \n556\n includes a plug \n558\n.', 'The plug may be configured to electronically connect an antenna (e.g., antenna winding \n216\n of \nFIG.', '2\n-\n1\n) to the downhole tool.', 'The central connection \n556\n connects to a cylindrical body \n560\n of the chassis \n522\n using one or more fins \n562\n.', 'Fluid may flow around an outside of the central connection \n556\n and into an interior of the cylindrical body \n560\n.', 'The fluid may be at least partially directed by the one or more fins \n562\n and/or an angled portion \n564\n of the cylindrical body \n560\n.\n \nFIC.', '6\n-\n1\n is a longitudinal cross-sectional view of a downhole communication system \n612\n, according to at least one embodiment of the present disclosure.', 'In the embodiment shown, the chassis \n622\n is similar to the chassis \n522\n of \nFIG.', '5\n.', 'The chassis \n622\n secures an antenna winding \n616\n to an inner surface \n620\n of the collar \n614\n.', 'The chassis \n622\n includes a flow diverter \n655\n configured to divert a fluid flow (collectively \n624\n) from an annular flow (e.g., around a tool component) to a tubular flow (e.g., central to the antenna winding \n616\n).', 'The flow diverter \n655\n includes a central connection \n656\n.', 'The central connection \n656\n is configured to connect to a downhole tool \n661\n.', 'The downhole tool \n661\n may include any downhole tool \n661\n used in a downhole environment, including an electronics package, a processor, a mud motor, an expandable tool, an MWD, an LWD, a mud pulse generator, or any other downhole tool or component.', 'The central connection \n656\n includes a plug \n658\n.', 'The plug \n658\n may electronically connect the antenna winding \n616\n to the downhole tool \n661\n.', 'The downhole tool \n661\n may be located in a center of a central bore \n626\n.', 'The fluid flow \n624\n may flow around the downhole tool \n661\n in an annular flow \n624\n-\n1\n.', 'Downhole of the downhole tool \n661\n, the fluid flow \n624\n flows through the flow diverter \n655\n in a diverted flow \n624\n-\n2\n.', 'The fluid flow \n624\n may then be directed to a tubular flow \n624\n-\n3\n.', 'An entirety of the fluid flow \n624\n may be diverted from the annular flow \n624\n-\n1\n to the tubular flow \n624\n-\n3\n.', 'In other words, none of the fluid flow \n624\n may flow between the antenna winding \n616\n and the collar \n614\n.', 'The flow diverter \n655\n includes a fin \n662\n and an angled portion \n664\n of a cylindrical body \n660\n of the chassis \n622\n.', 'The fin \n662\n and the angled portion \n664\n are sloped and hydrodynamically optimized to limit any hydrodynamic losses from the flow diverter \n655\n.', 'The chassis \n622\n is longitudinally secured to the collar \n614\n at a shoulder \n644\n.', 'In some embodiments, the downhole tool \n661\n may apply a force to the chassis \n622\n that pushes the chassis \n622\n against the shoulder \n644\n.', 'This may help to longitudinally and rotationally fix the chassis \n622\n, and therefore the antenna winding \n616\n, to the collar \n614\n.', 'This in turn, may reduce electromagnetic interference in the signal received and/or transmitted by the antenna winding \n616\n.', 'The collar \n614\n may include a necked portion \n666\n.', 'A thickness of the collar \n614\n wall may be reduced in the necked portion \n666\n at the antenna winding \n616\n.', 'This may reduce the magnetic interference from the collar \n614\n, thereby improving the signal received and/or transmitted by the antenna winding \n616\n.\n \nFIG.', '6\n-\n2\n is another longitudinal cross-sectional view of the downhole communication system \n612\n of \nFIG.', '6\n-\n1\n.', 'This cross-sectional view is taken parallel to a length of the fins \n662\n.', 'At least one of the fins \n662\n includes a wire channel \n668\n connected to the plug \n658\n.', 'The wire channel \n668\n is connected to the antenna channel \n632\n.', 'In this manner, a wire passed through the wire channel \n668\n may be connected to the antenna winding \n616\n and any electronics plugged into the plug \n658\n.', 'In this manner, each of the portions of the antenna, including the antenna winding \n616\n and the wire, may be protected from wear and/or erosion caused by the drilling fluid.', 'To ensure the structural integrity of the fin \n662\n, the wire channel \n668\n may pass through the thickest portion of the fin \n662\n.', 'The wire channel \n668\n may include one or more bends (e.g., inflection points) to reach the antenna winding \n616\n.', 'For example, in the embodiment shown, the wire channel includes a first bend near the plug \n658\n and a second bend near the wire channel \n668\n.', 'Furthermore, in some embodiments, the wire channel \n668\n may have a circular cross-sectional shape.', 'In other embodiments, the wire channel \n668\n may have a non-circular cross-sectional shape, such as an elliptical shape, square, rectangular, or any other shape.', 'The chassis \n622\n, including the flow diverter \n655\n, the fins \n662\n, and the wire channel \n668\n, may be expensive, time consuming, or even impossible to machine from a block or tube of steel.', 'In some embodiments, to achieve the complex geometry of the flow diverter and the wire channel \n668\n, the chassis \n622\n may be manufactured using additive manufacturing techniques.', 'For example, the chassis \n622\n may be manufactured with an additively manufactured metal.', 'In other embodiments, the chassis may be manufactured using injection molding techniques, including injection molding of hardened plastics and other polymers and polymeric compounds.\n \nFIG.', '7\n is a schematic representation of a downhole communication system \n712\n, according to at least one embodiment of the present disclosure.', 'The downhole communication system \n712\n includes a wireless transmitter \n770\n, a wireless receiver \n772\n, and a downhole tool \n760\n between the wireless transmitter \n770\n and the wireless receiver \n772\n.', 'In some embodiments, the wireless receiver \n772\n includes an antenna winding (e.g., antenna winding \n216\n of \nFIG.', '2\n-\n1\n)', 'according to the present disclosure.', 'In other embodiments, the wireless transmitter \n770\n includes an antenna winding according to the present disclosure.', 'In still other embodiments, both the wireless receiver \n772\n and the wireless transmitter \n770\n include an antenna winding according to the present disclosure.', 'In some embodiments, the wireless receiver \n772\n may be configured to both receive and transmit wireless signals and the wireless transmitter \n770\n may be configured to both transmit and receive wireless signals.', 'In this manner, the downhole communication system \n712\n may be a two-way communication system.', 'The wireless transmitter \n770\n may transmit wireless signals and the wireless receiver \n772\n may receive the wireless signals.', 'The downhole communication system has a signal range \n774\n between the wireless transmitter \n770\n and the wireless receiver \n772\n.', 'In some embodiments, the wireless receiver \n772\n may receive signals from the wireless transmitter \n770\n with a signal strength.', 'In some embodiments, the signal strength may be in a range having an upper value, a lower value, or upper and lower values including any of 1×10\n−13 \nTesla (T), 1×10\n−12 \nT, 1×10\n−11 \nT, 1×10\n−10 \nT, 1×10\n−9 \nT, 1×10\n−8 \nT, 1×10\n−7 \nT, or any value therebetween.', 'For example, the signal strength may be greater than 1×10\n−13 \nT.', 'In another example, the signal strength may be less than 1×10\n−7 \nT.', 'In yet other examples, the signal strength may be between 1×10\n−7 \nT and 1×10\n−13 \nT.', 'In some embodiments, it may be critical that the signal strength is greater than 1×10\n−13 \nT to increase the signal range \n774\n.', 'A greater signal strength may increase the signal range \n774\n.', 'The embodiments of the downhole communication system have been primarily described with reference to wellbore drilling operations; the downhole communication systems described herein may be used in applications other than the drilling of a wellbore.', 'In other embodiments, downhole communication systems according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources.', 'For instance, downhole communication systems of the present disclosure may be used in a borehole used for placement of utility lines.', 'Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.', 'One or more specific embodiments of the present disclosure are described herein.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'The articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements in the preceding descriptions.', 'References to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.']

['1.', 'A downhole antenna, comprising:\na collar including an inner surface that forms a central bore extending through the collar, wherein the central bore provides for fluid flow through the collar;\na chassis disposed inside the central bore of the collar and mechanically secured to the inner surface of the collar, wherein the chassis includes an inner annular surface that forms a secondary bore extending through the chassis and the chassis includes an outer surface facing the inner surface of the collar, wherein the secondary bore is coaxially aligned with the central bore of the collar and the secondary bore provides for the fluid flow through the collar and the chassis; and\nan antenna winding disposed between the outer surface of the chassis and the inner surface of the collar.\n\n\n\n\n\n\n2.', 'The downhole antenna according to claim 1, further comprising:\na gap between the antenna winding and the inner surface of the collar, wherein the gap is less than 3 millimeters.', '3.', 'The downhole antenna according to claim 1, wherein the antenna winding directly abuts the inner surface of the collar.\n\n\n\n\n\n\n4.', 'The downhole antenna according to claim 1, wherein the collar has a collar diameter and the antenna winding has an antenna diameter, the antenna winding includes a wire having a wire thickness, and the collar diameter is larger than the antenna diameter by double the wire thickness.', '5.', 'The downhole antenna according to claim 1, wherein the antenna winding is configured to vibrate at a same frequency as the collar.', '6.', 'The downhole antenna according to claim 1, further comprising:\nan electronics board fixed to the collar, wherein at least a portion of the antenna winding is fixed to the inner surface of the collar between the electronics board and the inner surface of the collar.', '7.', 'The downhole antenna according to claim 1, wherein the collar includes a collar shoulder disposed next to the antenna winding.', '8.', 'The downhole antenna according to claim 1, wherein the central bore of the collar and the secondary bore of the chassis have colinear central axes.', '9.', 'The downhole antenna according to claim 1, wherein the chassis includes a seal between the antenna winding and the central bore of the collar.\n\n\n\n\n\n\n10.', 'The downhole antenna according to claim 9, wherein the seal is configured to prevent the fluid flow in the central bore of the collar from entering an annulus between the inner surface of the collar and the antenna winding.', '11.', 'The downhole antenna according to claim 9, wherein the seal includes an uphole seal uphole of the antenna winding and a downhole seal downhole of the antenna winding.', '12.', 'The downhole antenna according to claim 1, wherein the chassis is configured to longitudinally fix the antenna winding to the inner surface of the collar.\n\n\n\n\n\n\n13.', 'The downhole antenna according to claim 1, wherein the chassis is configured to radially fix the antenna winding to the inner surface of the collar.\n\n\n\n\n\n\n14.', 'The downhole antenna according to claim 1, further comprising:\nan annulus between the inner surface of the collar and the antenna winding, wherein the annulus includes an annular pressure, the annular pressure being equalized with a bore pressure in the central bore.\n\n\n\n\n\n\n15.', 'The downhole antenna according to claim 1, further comprising:\nan annulus between the inner surface of the collar and the antenna winding, wherein the annulus is open to the fluid flow such that a portion of the fluid flow enters the annulus from an annulus opening and the fluid flow exits the annulus from the annulus opening.', '16.', 'The downhole antenna according to claim 1, wherein the chassis includes a first stabilization point and a second stabilization point, wherein the first stabilization point is located uphole of the antenna winding and the second stabilization point is located downhole of the antenna winding, and wherein a distance between the first stabilization point and the second stabilization point is less than 150% of a length of the antenna winding.', '17.', 'The downhole antenna according to claim 1, wherein the chassis includes a flow diverter disposed within the collar and configured to divert the fluid flow through the central bore of the collar from an annular flow to a tubular flow.', '18.', 'The downhole antenna according to claim 17, wherein the flow diverter includes:\na central connection including a wire port;\na cylindrical body; and\na fin connecting the central connection to the cylindrical body, the fin including a wire channel from the wire port to the antenna winding.', '19.', 'The downhole antenna according to claim 18, wherein the wire channel includes a plurality of bends inside the fin.\n\n\n\n\n\n\n20.', 'The downhole antenna according to claim 18, wherein the wire channel has an elliptical cross-sectional shape.', '21.', 'A method of communicating downhole, the method comprising:\ntransmitting data from a transmitter to the downhole antenna of claim 1, and\npumping the fluid flow from a downhole surface such that all the fluid flow past the antenna winding flows through the secondary bore of the chassis.']

['FIG.', '1 is a schematic representation of a drilling system, according to at least one embodiment of the present disclosure;; FIG.', '2-1 is a longitudinal cross-sectional view of a downhole communication system, according to at least one embodiment of the present disclosure;; FIG.', '2-2 is a detailed longitudinal cross-sectional view of the downhole communication system of FIG.', '2-1, according to at least one embodiment of the present disclosure;; FIG.', '2-3 is a transverse cross-sectional view of the downhole communication system of FIG.', '2-1, according to at least one embodiment of the present disclosure;; FIG. 3 is longitudinal cross-sectional view of another downhole communication system, according to at least one embodiment of the present disclosure;; FIG.', '4 is a longitudinal cross-sectional view of still another downhole communication system, according to at least one embodiment of the present disclosure;; FIG.', '5 is a perspective view of a chassis, according to at least one embodiment of the present disclosure;; FIG.', '6-1 is a longitudinal cross-sectional view of yet another downhole communication system, according to at least one embodiment of the present disclosure;; FIG.', '6-2 is another longitudinal cross-sectional view of the downhole communication system of FIG.', '6-1, according to at least one embodiment of the present disclosure; and; FIG. 7 is a schematic representation of a downhole communication system, according to at least one embodiment of the present disclosure.', '; FIG.', '1 shows one example of a drilling system 100 for drilling an earth formation 101 to form a wellbore 102.', 'The drilling system 100 includes a drill rig 103 used to turn a drilling tool assembly 104 which extends downward into the wellbore 102.', 'The drilling tool assembly 104 may include a drill string 105, a BHA 106, and a bit 110, attached to the downhole end of drill string 105.; FIG.', '2-1 is a cross-sectional view of a representation of a downhole communication system 212, according to at least one embodiment of the present disclosure.', 'The downhole communication system 212 is a wireless communication system.', 'In other words, the downhole communication system 212 is configured to receive and/or transmit wireless signals from other locations downhole and/or on the surface.; FIG.', '2-2 is a detailed cross-sectional view of the downhole communication system 212 of FIG.', '2-1, according to at least one embodiment of the present disclosure.', 'As may be seen, the antenna winding 216 is fixed to the inner surface 220 of the collar 214.', 'In the embodiment shown, the antenna winding 216 is wound around the chassis 222.', 'The chassis 222 is connected to the collar 214, thereby fixing the antenna winding 216 to the inner surface of the collar 214.; FIG.', '2-3 is a transverse cross-sectional view of the downhole communication system 212 of FIG.', '2-1, according to at least one embodiment of the present disclosure.', 'As may be seen, the antenna winding 216 is internal to the collar 214 and concentric with the collar 214 about the longitudinal axis 218.', 'The antenna winding 216 is supported by the chassis 222.', 'The chassis 222 surrounds the central bore 226 of the collar 214.', 'In the cross-sectional view shown, the central bore 226 runs through the center 228 of the antenna winding 216.; FIG.', '3 is a representation of a cross-sectional view of a downhole communication system 312, according to at least one embodiment of the present disclosure.', 'An antenna winding 316 is attached to an inner surface 320 of a collar 314.', 'A chassis 322 secures the antenna winding 316 to the inner surface 320.; FIG.', '4 is a representation of a cross-sectional view of a downhole communication system 412, according to at least one embodiment of the present disclosure.', 'In the embodiment shown, a board 454 extends from a collar shoulder 444 extending from an inner surface 420 of a collar 414.', 'The board 454 is offset from the inner surface 420.', 'In some embodiments, the board 454 includes a sensor, such as a nuclear sensor or other type of sensors.', 'In the same or other embodiments, the board 454 may include a printed circuit board and one or more processors.', 'The board 454 may be attached to the chassis 422 with a mechanical fastener, and the antenna winding 416 may be fixed or attached to the chassis 422 above the board 454.', 'In this manner, the chassis 422 radially secures the antenna winding 416 and the board 454 to the inner surface 420 of the collar 414.', 'In the embodiment shown, a single board 454 may secure the antenna winding 416 to the inner surface 420 of the collar 414.', 'In other embodiments, a plurality of boards 454, including 2, 3, 4, 5, 6, 7, 8, or more boards 454 may secure the antenna winding to the inner surface 420.; FIG.', '5 is a perspective view of a chassis 522, according to a least one embodiment of the present disclosure.', 'In some embodiments, the chassis 522 includes a flow diverter 555.', 'The flow diverter 555 may direct a fluid flow that flows through an annular space to tubular space.; FIG.', '6-2 is another longitudinal cross-sectional view of the downhole communication system 612 of FIG.', '6-1.', 'This cross-sectional view is taken parallel to a length of the fins 662.', 'At least one of the fins 662 includes a wire channel 668 connected to the plug 658.', 'The wire channel 668 is connected to the antenna channel 632.', 'In this manner, a wire passed through the wire channel 668 may be connected to the antenna winding 616 and any electronics plugged into the plug 658.', 'In this manner, each of the portions of the antenna, including the antenna winding 616 and the wire, may be protected from wear and/or erosion caused by the drilling fluid.; FIG. 7 is a schematic representation of a downhole communication system 712, according to at least one embodiment of the present disclosure.', 'The downhole communication system 712 includes a wireless transmitter 770, a wireless receiver 772, and a downhole tool 760 between the wireless transmitter 770 and the wireless receiver 772.', 'In some embodiments, the wireless receiver 772 includes an antenna winding (e.g., antenna winding 216 of FIG.', '2-1) according to the present disclosure.', 'In other embodiments, the wireless transmitter 770 includes an antenna winding according to the present disclosure.', 'In still other embodiments, both the wireless receiver 772 and the wireless transmitter 770 include an antenna winding according to the present disclosure.', 'In some embodiments, the wireless receiver 772 may be configured to both receive and transmit wireless signals and the wireless transmitter 770 may be configured to both transmit and receive wireless signals.', 'In this manner, the downhole communication system 712 may be a two-way communication system.']

US11841476

Methods and systems of determining parameters characterizing porous media from data gathered by a plurality of different tools

Mar 27, 2018

Vasileios-Marios Gkortsas, Lalitha Venkataramanan, Jean-Marc Donadille

SCHLUMBERGER TECHNOLOGY CORPORATION

D. Rankin and R.P. Singh, “Effect of Clay and Salinity on the Dielectric Properties of Rock,” Sep. 10, 1985, Journal of Geophysical Resarch, vol. 90, No. B10, pp. 8793-8800. (Year: 1985).; Vasileios-Marios Gkortsas, Lalitha Venkataramanan, T. S. Ramakrishnan, and Denise Freed, “Indication of wettability from dielectric measurements on partially saturated rocks using effective medium models” Sep. 2015, Geophysics, vol. 80, No. 5, pp. E258-E265. (Year: 2015).; G.M. Hamada, M.N.J. Al-Awad and A.A. Alsughayer, “Water Saturation Computation from Laboratory,3D Regression”, Oil & Gas Science and Technology, vol. 57, No. 6, pp. 637-651. (Year: 2002).; Abdel aal, A. F. et al., “Integration of Dielectric Dispersion and 3D NMR Characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir”, SPE 164150, presented at the SPE Middle East Oil and Gas Show and Conference, Manama, Bahrain, 2013, 12 pages.; Feng, S. et al., “Geometrical model of conductive and dielectric properties of partially saturated rocks”, Journal of Applied Physics, 1985, 58, pp. 3236-3243.; Mendelson, K. S. et al, “The effect of grain anisotropy on the electrical properties of sedimentary rocks”, Geophysics, 1982, 47(2), pp. 257-263.; Sen, P. N., “Grain shape effects on dielectric and electrical properties of rocks”, Geophysics, 1984, 49, pp. 586-587.; Stroud, D. et al., “Analytical model for the dielectric response of brine-saturated rocks”, Physical Review B, 1986, 34(8), pp. 5145-5153.

5675147; October 7, 1997; Ekstrom; 8364404; January 29, 2013; Legendre; 9720124; August 1, 2017; Kadayam Viswanathan; 10393641; August 27, 2019; Donadille; 10502863; December 10, 2019; Mosse; 20090015254; January 15, 2009; Castillo et al.; 20090206834; August 20, 2009; Minh; 20120192640; August 2, 2012; Minh et al.; 20130002258; January 3, 2013; Ligneul; 20130204534; August 8, 2013; Anand et al.; 20160097876; April 7, 2016; Freed et al.; 20160230548; August 11, 2016; Gzara et al.

Foreign Citations not found.

['Methods are provided for determining values for a set of parameters for multiple locations in a formation by inversion of formation data obtained from a plurality of different logging tools.', 'The inversion of the formation data is constrained by certain formation data that characterizes each particular location in the formation as obtained from at least one of the plurality of different logging tools.', 'In one embodiment, the set of parameters for each particular location in the formation includes an apparent cementation factor mn and a formation water saturation Sw, which can be derived by inverting dielectric data that characterizes the particular location in the formation as obtained from a dielectric logging tool.', 'The methods can also be adapted to characterize a porous medium such as reservoir rock, particular with regard to laboratory analysis of porous media samples.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS\n \nThe present document is based on and claims priority to U.S. Provisional Application Ser.', 'No. 62/476,902, filed Mar. 27, 2017, which is incorporated herein by reference in its entirety.', 'TECHNICAL FIELD', 'The subject disclosure relates to the investigation of geological formations and other porous media.', 'More particularly, the subject disclosure relates to methods and systems of determining parameters (such as apparent cementation factor) that characterize a geological formation or other porous medium via the use of data gathered by a plurality of different downhole logging tools or laboratory tools.', 'The subject disclosure has particular application to oilfield exploration and exploitation although it is not limited thereto.', 'BACKGROUND', 'In analyzing and developing oilfields, it is common to drill wellbores in the formation containing a hydrocarbon reservoir for the purpose of running logging tools down the wellbore(s) in order to generate data useful in analyzing the makeup of the formation and the contents of the reservoir.', 'Some of the common logging tools include resistivity logging tools, spectroscopy logging tools, dielectric logging tools, nuclear magnetic resonance (NMR) logging tools and acoustic logging tools.', 'The data obtained from the logging tools are regularly used to analyze and model the geological formation and the reservoir.', 'Information regarding the rock matrix and the fluid volume, such as porosity, permeability, hydrocarbon volume, water and oil saturations, conductivities, etc., are desired results.', 'Interpretation models are used to estimate parameters that characterize a formation, such as water saturation S\nw\n, water salinity, and an apparent cementation factor inn.', "The apparent cementation factor n is known to combine multiple effects including the effect of pore space tortuosity, which is captured by a cementation exponent m, and the distribution of water and hydrocarbons in the pore system, which is captured by a saturation exponent n in the well-known Archie's equation.", 'The apparent cementation factor m\nn \nis typically derived from measured dielectric data (permittivity and conductivity) obtained by a dielectric logging tool.', 'The apparent cementation factor m\nn \nhas several applications.', 'When the value of the cementation exponent m of a formation can be estimated through measurements, the values of the apparent cementation factor m\nn \nand the cementation exponent m of the formation can be used to estimate the saturation exponent n of the formation, which can then be used to infer information about wettability of the formation.', "In addition, the value of the apparent cementation factor m\nn \nin a shallow (e.g., invaded) zone of the formation can be used to estimate water saturation in the deep (e.g., virgin) zone of the formation using measurement of resistivity tool of the deep zone and Archie's law.", 'Note that errors in measured dielectric data (permittivity and conductivity) can result in error in the estimation of the apparent cementation factor m\nn\n, which in turn, affects the accuracy of parameters estimated from the apparent cementation factor m\nn \nlike the cementation exponent m and the saturation exponent n, which are used to derive water saturation and infer wettability.', 'SUMMARY\n \nIllustrative embodiments of the present disclosure are directed to methods for determining values for a set of parameters for multiple locations in a formation by inversion of formation data obtained from a plurality of different logging tools.', 'The inversion of the formation data is constrained by certain formation data that characterizes each particular location in the formation as obtained from at least one of the plurality of different logging tools.', 'In one embodiment, the set of parameters for each particular location in the formation includes apparent cementation factor m\nn \nand a formation water saturation S\nw\n, which can be derived by inverting dielectric data that characterizes the particular location in the formation as obtained from a dielectric logging tool.', 'The certain formation data that is used to constrain the inversion can include at least one of resistivity data (e.g., DC resistance) obtained from a resistivity logging tool and porosity data (e.g., total porosity) obtained from a porosity logging tool.', 'In embodiments, the apparent cementation factor m\nn\n, the formation water saturation S\nw\n, and the formation porosity ϕ for the plurality of locations in the formation can be used to determine an estimation of at least one cementation exponent m and/or saturation exponent n at multiple locations in the formation (e.g., which can be depths or depth intervals denoted by an index i).', 'In other embodiments, a method is provided for characterizing a porous medium (such as reservoir rock), which involves determining values for a set of parameters that characterize the porous medium by inversion of data obtained from a plurality of different tools.', 'The inversion of the data that determines the set of parameters is constrained by certain data that characterizes the porous medium as obtained from at least one of the plurality of different tools.', 'In one embodiment, the set of parameters includes an apparent cementation factor m\nn \nand a formation water saturation S\nw \nthat are derived by inverting dielectric data that characterizes the porous medium as obtained from a dielectric tool.', 'The dielectric data can characterize relative permittivity and conductivity of the porous medium.', 'The certain data that is used to constrain the inversion can include at least one of resistivity data obtained from a resistivity tool and porosity data obtained from a porosity tool.', 'In some embodiments, the plurality of different tools can be realized by a plurality of downhole logging tools.', 'In other embodiments, the plurality of different tools can be realized by a plurality of laboratory tools.', 'In various embodiments, the cementation exponent m and saturation exponent n values may be used for, among many applications, inferring wettability, estimating water saturation in virgin zones, and choosing relative permeability curves for dynamic reservoir modeling.', 'Additional aspects, embodiments, objects, and advantages of the disclosed methods may be understood with reference to the following detailed description taken in conjunction with the provided drawings.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n shows a wellbore logging tool that can be used to acquire formation data that characterizes a formation;\n \nFIG.', '2\n illustrates an example computing device that can be used in accordance with various embodiments of the present disclosure;\n \nFIG.', '3\n is a flow chart that shows a method in accordance with one embodiment of the present disclosure;\n \nFIGS.', '4\nA and \n4\nB\n are plots of dielectric constant and conductivity, respectively, as a function of frequency for a number of different combinations of cementation exponent m and water saturation S;\n \nFIGS.', '5\nA and \n5\nB\n are plots of dielectric constant and conductivity, respectively, as a function of frequency as determined by inversion of two computational models that are depicted schematically in \nFIGS.', '6\nA and \n6\nB\n;\n \nFIG.', '7\n is a plot of normalized root mean square error of the apparent cementation factor m\nn \nas a function of the relative error of DC conductivity, which is obtained from inversions using the computational models of \nFIGS.', '6\nA and \n6\nB\n in conjunction with Monte Carlo simulations;\n \nFIGS.', '8\nA and \n8\nB\n are plots that show the distribution of the parameter p (percentage of ellipsodoidal inclusions) as well as true and mean values for the parameter p that are obtained from inversions used in conjunction with Monte Carlo simulations.', 'The plot of \nFIG.', '8\nA\n is derived from an inversion using the computational model of \nFIG.', '6\nA\n, while the plot of \nFIG.', '8\nB\n is derived from an inversion using the computational model of \nFIG.', '6\nB\n;\n \nFIGS.', '8\nC and \n8\nD\n are plots that show the distribution of the water saturation S\nw \nas well as true and mean values of the water saturation S\nw \nthat are obtained from inversions used in conjunction with Monte Carlo simulations.', 'The plot of \nFIG.', '8\nC\n is derived from an inversion using the computational model of \nFIG.', '6\nA\n, while the plot of \nFIG.', '8\nD\n is derived from an inversion using the computational model of \nFIG.', '6\nB\n; and\n \nFIGS.', '8\nE and \n8\nF\n are plots that show the distribution of the apparent cementation factor m\nn \nas well as true and mean values of the apparent cementation factor m\nn \nthat are obtained from inversions used in conjunction with Monte Carlo simulations.', 'The plot of \nFIG.', '8\nE\n is derived from an inversion using the computational model of \nFIG.', '6\nA\n, while the plot of \nFIG.', '8\nF\n is derived from an inversion using the computational model of \nFIG.', '6\nB\n.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'Additionally, some examples discussed herein involve technologies associated with the oilfield services industry.', 'It will be understood however that the techniques of multi-tool measurement processing may also be useful in a wide range of other industries outside of the oilfield services sector, including for example, mining, geological surveying, etc.', 'Example Wellsite\n \nFIG.', '1\n illustrates a wellsite \n100\n for which embodiments of multi-tool measurement processing can be employed.', 'Wellsite \n100\n can be onshore or offshore.', 'In this example system, a bottom hole assembly is positioned within a wellbore \n102\n that traverses a formation \n104\n.', 'The wellbore \n102\n can have a vertical inclination as shown.', 'In other embodiments, the wellbore \n102\n can have a portion with a vertical (or near-vertical) inclination that leads to a curved transition that leads to a portion with a horizontal (or near-horizontal) inclination.', 'Other more complex configurations of the wellbore can be used to traverse the formation \n104\n as well.', 'The bottom hole assembly can include a string of a number of downhole logging tools \n106\n, \n108\n, \n109\n that can be conveyed in the wellbore \n102\n by the wireline cable \n112\n (or other suitable conveyance means, such as drill pipe, coiled tubing, or tractor).', 'Downhole logging tool \n106\n is a dielectric logging tool that can be located at one or more depths of the formation \n104\n and operated to perform dielectric measurements at the one or more depths of the formation \n104\n to obtain dielectric data at different operational frequencies for the one or more depths of the formation \n104\n.', 'Downhole logging tool \n108\n is a resistivity logging tool that can be located at one or more depths of the formation \n104\n and operated to perform resistivity measurements at the one or more depths of the formation \n104\n to obtain resistivity data for the one or more depths of the formation \n104\n.', 'Downhole logging tool \n109\n is a porosity logging tool (such as an NMR logging tool or neutron porosity logging tool or other logging tool) that can be located at one or more depths of the formation \n104\n and operated to perform measurements that obtain porosity data for the one or more depths of the formation \n104\n.', 'The logging tools (e.g., tools \n106\n, \n108\n, \n109\n, etc.) of the bottom hole assembly can be coupled to a processing system \n110\n via a telemetry subsystem, which can be part of the wireline cable \n112\n or which can implement other data telemetry methods.', 'The processing system \n110\n is located at a surface location.', 'Signals and data that are acquired by the logging tools of the bottom hole assembly are communicated uphole by the telemetry subsystem for processing and analysis by the processing system \n110\n.', 'The processing system \n110\n can be proximate and/or remote from the wellsite \n100\n (for example, at a computer located at or near the wellsite, a computer located at a remote command center, combinations thereof, etc.)', 'In an alternate embodiment, the processing system \n110\n or part thereof can be integrated as part of the bottom hole assembly.', 'In one possible embodiment, the processing system \n110\n or parts thereof can be used to perform various aspects of the multi-tool measurement processing as described herein.', 'The dielectric logging tool \n106\n includes transmitters that emit microwaves which propagate into the formation \n104\n and reach several receivers of the dielectric logging tool \n106\n.', 'The amplitude and phase of the propagated waves with respect to the emitted waves depend on the complex permittivity of the formation \n104\n, the wave frequency and the transmitter-receiver spacing.', "As the wave's frequency and the tool's geometry are known, dielectric data that characterizes the relative permittivity and conductivity of the formation \n104\n can be computed by inversion of the amplitude and phase of the propagated waves with respect to the emitted waves as measured by the dielectric logging tool \n106\n.", "In one embodiment, the dielectric logging tool \n106\n can be realized by Schlumberger's Dielectric Scanner, which can be configured to perform continuous measurement of formation complex permittivity at four different frequencies, from about 20 MHz up to about 1 GHz.", "The Dielectric Scanner tool is pad-mounted with two transmitter antenna's and eight symmetrically located receiver antenna's.", 'The two transmitters and eight receivers possess two orthogonal polarization modes, allowing for anisotropy assessment.', 'At a given operating frequency, the symmetry of the Dielectric Scanner tool enables nine attenuation and phase-shift measurements and hence nine relative permittivity and conductivity measurements, each with a different radial response.', 'The Dielectric Scanner tool finally measures thirty-six relative permitivities and thirty-six conductivities, nine couples at every frequency.', 'These measurements can be used to obtain dielectric data that characterizes the dielectric radial profile of the formation \n104\n near the wellbore \n102\n.', 'The depth of investigation of the measurements is about 1 to four inches with a vertical resolution of 1 inch.', 'Note that other dielectric logging tools can be used as well.', 'The resistivity logging tool \n108\n can be configured to derive resistivity data that characterizes resistivity of the formation \n104\n at a depth of investigation that corresponds to the depth of investigation of the dielectric logging tool \n106\n.', 'The resistivity data can include data that characterizes DC resistance of the formation at the particular depth.', 'The DC resistance can represent electrical resistance of the formation at a low frequency or DC limit.', "In one embodiment, the resistivity logging tool \n108\n can be Schlumberger's MicroCylindrically Focused Log (MCFL) logging tool, which includes a pad that is mechanically pressed against the mudcake.", 'The pad supports two current electrodes (A\n0 \nand A\n1\n), a potential electrode M\n0\n, and two monitoring electrodes (M\n1 \nand M\n2\n) that are configured to measure the DC resistance of the formation at a depth of investigation of up to three inches with a vertical resolution of 0.7 inches.', 'Note that other resistivity logging tools can be used.', 'The porosity logging tool \n109\n, which can be a nuclear magnetic resonance (NMR) logging tool or a nuclear porosity tool or other porosity logging tool, can be used to derive porosity data that characterizes porosity of the formation \n104\n at a depth of investigation that corresponds to the depth of investigation of the dielectric logging tool \n106\n and the resistivity logging tool \n108\n.', 'It will also be understood that the multi-tool processing as described herein can be embodied with while-drilling logging tools that are conveyed inside the wellbore for determining properties of the formation while drilling as is well known in the art.', 'The multiple tools can be integrated together into a unitary housing that is conveyed as part of a bottom-hole assembly in the wellbore.', 'Example Computing Device\n \nFIG.', '2\n illustrates an example device \n200\n (including a processor \n202\n and computer memory \n204\n) that can be configured to implement various operations of the multi-tool measurement processing discussed in this disclosure.', 'Computer memory \n204\n can include one or more forms of volatile data storage media such as random access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).', 'Device \n200\n is one example of a computing device or programmable device, and is not intended to suggest any limitation as to scope of use or functionality of device \n200\n and/or its possible architectures.', 'For example, device \n200\n can comprise one or more computing devices, programmable logic controllers (PLCs), etc.', 'Further, device \n200\n should not be interpreted as having any dependency relating to one or a combination of components illustrated in device \n200\n.', 'For example, device \n200\n may include one or more of a computer, such as a laptop computer, a desktop computer, a mainframe computer, etc., or any combination or accumulation thereof.', 'Device \n200\n can also include a bus \n208\n configured to allow various components and devices, such as processors \n202\n, memory \n204\n, and local data storage \n210\n, among other components, to communicate with each other.', 'Bus \n208\n can include one or more of any of several types of bus structures, including a memory bus or memory controller, a peripheral bus, an accelerated graphics port, and a processor or local bus using any of a variety of bus architectures.', 'Bus \n208\n can also include wired and/or wireless buses.', 'Local data storage \n210\n can include fixed media (e.g., RAM, ROM, a fixed hard drive, etc.) as well as removable media (e.g., a flash memory drive, a removable hard drive, optical disks, magnetic disks, and so forth).', 'One or more input/output (I/O) device(s) \n212\n may also communicate via a user interface (UI) controller \n214\n, which may connect with IO device(s) \n212\n either directly or through bus \n208\n.', 'In one possible embodiment, a network interface \n216\n may communicate outside of device \n200\n via a connected network, and in some implementations may communicate with hardware (such as logging tools \n106\n, \n108\n, \n109\n, etc.).', 'In another possible embodiment, equipment (such as the logging tools \n106\n, \n108\n, \n109\n, etc.) may communicate with device \n200\n as input/output device(s) \n212\n via bus \n208\n, such as via a USB port, for example.', 'A media drive/interface \n218\n can accept removable tangible media \n220\n, such as flash drives, optical disks, removable hard drives, software products, etc.', 'In one possible embodiment, logic, computing instructions, and/or software programs comprising elements of a measurement processing module \n206\n may reside on removable media \n220\n readable by media drive/interface \n218\n.', 'In one possible embodiment, input/output device(s) \n212\n can allow a user to enter commands and information to device \n200\n, and also allow information to be presented to the user and/or other components or devices.', 'Examples of input device(s) \n212\n include communication interfaces, sensors, a keyboard, a cursor control device (e.g., a mouse), a microphone, and any other input devices known in the art.', 'Examples of output devices include a display device (e.g., a monitor or projector), speakers, a printer, communication interfaces, and so on.', 'Various processes of the measurement processing module \n206\n may be described herein in the general context of software or program modules, or the techniques and modules may be implemented in pure computing hardware.', 'Software generally includes routines, programs, objects, components, data structures, and so forth that perform particular tasks or implement particular abstract data types.', 'An implementation of these modules and techniques may be stored on or transmitted across some form of tangible computer-readable media.', 'Computer-readable media can be any available data storage medium or media that is tangible and can be accessed by a computing device.', 'Computer readable media may thus comprise computer storage media.', '“Computer storage media” designates tangible media, and includes volatile and non-volatile, removable and non-removable tangible media implemented for storage of information such as computer readable instructions, data structures, program modules, or other data.', 'Computer storage media include, but are not limited to, RAM, ROM, EEPROM, flash memory or other memory technology, CD-ROM, digital versatile disks (DVD) or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other tangible medium which can be used to store the desired information, and which can be accessed by a computer.', 'In one possible embodiment, device \n200\n, or a plurality thereof, can be employed proximate to or remote from the wellsite \n100\n.', 'The device(s) \n200\n can be part of the processing system \n110\n or part of the bottom hole assembly of the logging apparatus or a distributed processing system that includes both the processing system \n110\n and part of the bottom hole assembly of the logging apparatus.', 'Example Multi-Tool Processing Methods and Technique(s)', 'Before turning directly to the embodiments of the multi-tool processing methods and techniques, a technical discussion regarding the parameters of interest is useful for understanding the embodiments.', 'One parameter that is obtained by analyzing data (e.g., using interpretation software) from a downhole logging tool such as a dielectric logging tool or NMR logging tool is m\nn\n.', 'The parameter m\nn \nis often called an “apparent cementation factor.”', 'More particularly, m\nn \nis a textural parameter that is obtained from inversion of the complex permittivity dispersion measured downhole (and in labs).', 'The forward model used in this inversion is often the Bimodal model or the Stroud-Milton-De (SMD) model.', 'Details of the Bimodal model can be found in K. Mendelson and M. Cohen, “The effects of grain anisotropy on the electrical properties of sedimentary rocks,” Geophysics, Vol 47, 1982, pgs 257-263.', 'Details of the Stroud-Milton-De (SMD) model can be found in D. Stroud, G. W. Milton, and B. R. De., “Analytical model for the dielectric response of brine-saturated rocks,” Physical Review B, Vol. 34(8), 1986, pgs. 5145-5153.', 'The predicted conductivity from these models tends to the Archie-like formulation at a low frequency (DC limit) according to: \n σ=(ϕ\nS\nw\n)\nm\nn\nσ\nw\n,\u2003\u2003(1) \n where σ is the measured conductivity of the partially saturated rock at the low frequency (DC limit), σ\nw \nis the conductivity of water at the low (close to zero) frequency (referred to as DC limit), ϕ is the rock porosity, S\nw \nis the water saturation of the rock, and m\nn \nis the apparent cementation factor.', "The apparent cementation factor m\nn \ncombines two effects: (i) the effect of pore space tortuosity which is captured by the cementation exponent m, and (ii) the distribution of water and hydrocarbons in the pore system which is captured by the saturation exponent n. \n \nArchie's law is given from the expression:", 'σ=ϕ\nm\nS\nw\nn\nσ\nw\n,\u2003\u2003(2) \n \nwhere m is the cementation exponent and n is the saturation exponent.', 'Equation (2) can be combined with Equation (1) to obtain: \n (ϕ\nS\nw\n)\nm\nn\n=ϕ\nm\nS\nw\nn\n.', '(3) \n It should be appreciated that unless m=n, there is no constant m\nn \nthat will satisfy equation (3) for all water saturations S\nw\n.', 'Therefore, the apparent cementation factor m\nn \nmay be considered a function of water saturation S\nw\n.', 'Equation (3) may be re-written as:\n \n \n \n \n \n \n \n \n \nm\n \nn\n \n \n=\n \n \n \n \n \nm\n \n\u2062\n \n \nlog\n \n\u2061\n \n(\n \nϕ\n \n)\n \n \n \n+\n \n \nn\n \n\u2062\n \n \nlog\n \n\u2061\n \n(\n \n \nS\n \nw\n \n \n)\n \n \n \n \n \n \nlog\n \n\u2061\n \n(\n \nϕ\n \n)\n \n \n+\n \n \nlog\n \n\u2061\n \n(\n \n \nS\n \nw\n \n \n)\n \n \n \n \n.', '(\n \n4\n \n)\n \n \n \n \n \n \n \n From equation (4), it is clear that in a water zone, m\nn\n=m when S\nw\n=1, and that in a hydrocarbon zone, m\nn \napproaches n when S\nw \nis close to zero.', 'This confirms that the parameter m\nn \nis a function of water saturation S\nw \nand varies between n when S\nw \napproaches 0 and m', 'when S\nw\n=1.', 'In a zone with partial oil and water saturations, the apparent cementation factor m\nn \ntakes an intermediate value between m and n.', 'Thus, the apparent cementation factor m\nn \nis a combination of m and n involving the total porosity and the invaded zone water saturation.', 'There are two primary applications of the apparent cementation factor m\nn\n: i) computation of virgin zone water saturation, and ii) estimating wettability.', 'Sometimes, a value for the apparent cementation factor m\nn \nis simply assumed (e.g., m\nn\n=1.8 or m\nn\n=2.0).', 'In other cases, values for the apparent cementation factor m\nn \nare estimated from dielectric measurements which are generally sensitive to fluid and rock properties in the invaded zone of a formation around a wellbore.', "In order to compute virgin zone water saturation, the apparent cementation factor m\nn \ncan be used in conjunction with knowledge of the porosity and the ratio of the formation conductivity to water conductivity according to an expression similar to Archie's law given by:\n \n \n \n \n \n \n \n \n \nS\n \nw\n \n \n=\n \n \n \n1\n \nϕ\n \n \n\u2062\n \n \n \n \n(\n \n \nσ\n \n \nσ\n \nw\n \n \n \n)\n \n \n \n1\n \n/\n \n \nm\n \nn\n \n \n \n \n.\n \n \n \n \n \n \n \n(\n \n5\n \n)\n \n \n \n \n \n \n \n Again, it should be appreciated that the value of the apparent cementation factor m\nn \nused in equation (5) can be obtained from dielectric dispersion measurements in the invaded zone by a dielectric logging tool.", 'However, using the apparent cementation factor m\nn \nvalue of the invaded zone for deriving the saturation in the virgin zone rests on the generally incorrect assumption that m\nn \nis either saturation independent with m=n, or that the virgin zone water saturation is the same as the invaded zone water saturation.', 'In order to estimate wettability, the value of the apparent cementation factor m\nn \ncan be used in conjunction with knowledge of the porosity and water saturation according to equation (4) rewritten as:\n \n \n \n \n \n \n \n \n \nn\n \n=\n \n \n \n \n \n(\n \n \n \nm\n \nn\n \n \n-\n \nm\n \n \n)\n \n \n\u2062\n \n \nlog\n \n\u2061\n \n(\n \nϕ\n \n)\n \n \n \n+\n \n \n \nm\n \nn\n \n \n\u2062\n \n \nlog\n \n\u2061\n \n(\n \n \nS\n \nw\n \n \n)\n \n \n \n \n \nlog\n \n\u2061\n \n(\n \n \nS\n \nw\n \n \n)\n \n \n \n \n,\n \n \n \n \n \n(\n \n6\n \n)\n \n \n \n \n \n \n \n where the porosity and water saturation are known, and the cementation exponent m is assumed or estimated from sources, such as from an NMR analysis, from a formation micro resistivity imager tool, or from laboratory core study.', 'The saturation exponent n can be estimated in this manner in Abdelaal, A. F., et al., Integration of Dielectric Dispersion and 3D NMR characterizes the Texture and Wettability of a Cretaceous Carbonate Reservoir, SPE 164150 (2013), and can be used to infer wettability of the formation.', 'However, estimating the saturation exponent n in this manner requires an independent measurement for the estimation of cementation exponent m.\n \nAlso note that values for both the cementation exponent m and the saturation exponent n of the formation may be determined through knowledge of the porosity and water saturation of the formation and from dielectric dispersion measurements.', 'Stated in another way, values for both the cementation exponent m and the saturation exponent n of the formation may be determined together without pre-knowledge of the other.', 'In particular, i can be used to denote an index in a set of measurements where the cementation exponent m and the saturation exponent n are expected or assumed to be the same.', 'In downhole data, and as will be discussed hereinafter with respect to particular measurements that may be made for this purpose, this set of measurements may correspond to a depth interval or depth intervals or points with similar petrophysical properties.', 'In surface core measurements, these sets of measurements may correspond to measurements of different saturation stages of a core, measurements on different cores of similar lithology but varying porosity in the same saturation stage, or measurements on different cores with similar Archie parameters but different water saturations and porosities.', 'Thus, according to one embodiment, equation (4) can be rewritten as \n \nm\nn\n(\ni\n)=(\nm−n\n)\na\n(\ni\n)+\nn,\n\u2003\u2003(7) \n where m\nn\n(i) is the estimated m\nn \nat depth i and may be obtained from a dielectric measurement, and \n \n \n \n \n \n \n \n \n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n=\n \n \n \nlog\n \n\u2061\n \n(\n \n \nϕ\n \n\u2061\n \n(\n \ni\n \n)\n \n \n)\n \n \n \n \nlog\n \n\u2061\n \n(\n \n \nϕ\n \n\u2061\n \n(\n \ni\n \n)\n \n \n)\n \n \n+\n \n \nlog\n \n\u2061\n \n(\n \n \n \nS\n \nw\n \n \n(\n \ni\n \n)\n \n \n)\n \n \n \n \n \n,\n \n \n \n \n \n(\n \n8\n \n)\n \n \n \n \n \n \n \n which may be computed from porosity and water saturation measurements.', 'From equation (8), it will be appreciated that when S\nw\n(i)−1, a(i)=1 and m\nn\n=m. Also, when S\nw\n(i)−0, a(i)=0 and m\nn\n=n. Therefore, in an m\nn\n—a crossplot, the data points corresponding to different depths should lie on a straight line with slope (m−n) and intersecting the a=1 and a=0 axes at m and n, respectively.', 'In one embodiment, values for both the cementation exponent m and the saturation exponent n of the formation over a depth interval i (or over wellbore locations having similar petrophysical properties and given index i) can be estimated according to:\n \n \n \n \n \n \n \n \n \n \n[\n \n \n \n \n \n∑\n \n \n \na\n \n2\n \n \n(\n \ni\n \n)\n \n \n \n \n \n \n∑\n \n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n\u2062\n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)\n \n \n \n \n \n \n \n \n \n∑\n \n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n\u2062\n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)\n \n \n \n \n \n \n \n∑\n \n \n(\n \n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)', '2\n \n \n \n \n \n \n \n]\n \n \n[\n \n \n \n \nm\n \n \n \n \n \nn\n \n \n \n \n]\n \n \n=\n \n \n \n[\n \n \n \n \n \n∑\n \n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n\u2062\n \n \n \nm\n \n \nn\n \n \n \n \n \n(\n \ni\n \n)\n \n \n \n \n \n \n \n \n \n∑\n \n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)\n \n \n\u2062\n \n \n \nm\n \nn\n \n \n(\n \ni\n \n)\n \n \n \n \n \n \n \n]\n \n \n.', '(\n \n9\n \n)', 'For increased robustness, equation (9) can be extended to include weights w(i) at each depth interval according to:\n \n \n \n \n \n \n \n \n \n[\n \n \n \n \n \n∑\n \n \n \nw\n \n\u2061\n \n(\n \ni\n \n)', '\u2062\n \n \n \na\n \n2\n \n \n(\n \ni\n \n)\n \n \n \n \n \n \n \n∑\n \n \n \nw\n \n\u2061\n \n(\n \ni\n \n)\n \n \n\u2062\n \n \na\n \n\u2061\n \n(\n \ni\n \n)', '\u2062\n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)\n \n \n \n \n \n \n \n \n \n∑\n \n \n \nw\n \n\u2061\n \n(\n \ni\n \n)\n \n \n\u2062\n \n \na\n \n\u2061\n \n(\n \ni\n \n)', '\u2062\n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)\n \n \n \n \n \n \n \n∑\n \n \n \nw\n \n\u2061\n \n(\n \ni\n \n)', '\u2062\n \n \n(\n \n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)\n \n \n2\n \n \n \n \n \n \n \n \n]\n \n \n\u2062\n \n \n\uf3a8\n \n \n \n[\n \n \n \n \nm\n \n \n \n \n \nn\n \n \n \n \n]\n \n \n=\n \n \n \n[\n \n \n \n \n \n∑\n \n \n \nw\n \n\u2061\n \n(\n \ni\n \n)\n \n \n\u2062\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n\u2062\n \n \n \nm\n \nn\n \n \n(\n \ni\n \n)\n \n \n \n \n \n \n \n \n \n∑\n \n \n \nw\n \n\u2061\n \n(\n \ni\n \n)', '\u2062\n \n \n(\n \n \n1\n \n-\n \n \na\n \n\u2061\n \n(\n \ni\n \n)\n \n \n \n)\n \n \n\u2062\n \n \n \nm\n \nn\n \n \n(\n \ni\n \n)\n \n \n \n \n \n \n \n]\n \n \n.', '(\n \n10\n \n)', 'For example, the weights can be set as the inverse of the uncertainty associated with the m\nn \nvalue, which may have been computed during the inversion of the dielectric measurements.', 'Note that the details of finding the cementation exponent m and the saturation exponent n of the formation according to Eqns.', '(7)-(10) above are similar to those described in U.S. patent application Ser.', 'No. 14/962,201, entitled “Methods of Determining Cementation Exponent and Saturation Exponent in Porous Media from Dielectric Dispersion Data,” filed on Dec. 8, 2015, commonly assigned to assignee of the present application and herein incorporated by reference in its entirety.', 'Note that although the present disclosure discusses integration with an Archie equation, the methodology and systems described in the present disclosure can be adapted to include other Archie-like equations that relate bulk conductivity to rock conductivity through porosity, water saturation, and other petrophysical and fluid parameters.', 'Turning to \nFIGS.', '3\nA and \n3\nB\n, a method according to one embodiment of the present disclosure is shown.', 'More particularly, at \n301\n, formation data at multiple depths in a wellbore are obtained using downhole logging tools and stored in computer memory, which can be volatile or non-volatile memory of the processing system \n110\n of \nFIG.', '1\n.', 'The formation data for each particular depth in a wellbore can include: i) dielectric data for the particular depth (such as data that characterizes relative permittivity and conductivity of the formation at the particular depth); ii) resistivity data for the particular depth (such as data that characterizes DC resistance of the formation at the particular depth); and/or iii) porosity data for the particular depth (such as data that characterizes total porosity of the formation at the particular depth).', 'The dielectric data for the particular depth can be obtained by locating the dielectric logging tool \n106\n at the particular depth in the wellbore \n102\n and operating the dielectric logging tool \n106\n at a number of different frequencies to investigate a local region of the formation \n104\n in order to obtain the dielectric data for the particular depth.', 'In one embodiment, such dielectric data can include data that characterizes relative permittivity and conductivity of the formation at the particular depth.', 'The resistivity data for the particular depth can be obtained by locating the resistivity logging tool \n108\n at the particular depth in the wellbore \n102\n and operating the resistivity logging tool \n108\n to investigate the same local region of the formation \n104\n in order to obtain resistivity data for the particular depth.', 'In one embodiment, such resistivity data can include data that characterizes DC resistance of the formation at the particular depth.', 'The DC resistance can represent electrical resistance of the formation at a low frequency or DC limit.', 'The porosity data for the particular depth can be obtained by locating the porosity logging tool \n109\n at the particular depth in the wellbore \n102\n and operating the porosity logging tool \n109\n to investigate the same local region of the formation \n104\n in order to obtain porosity data for the particular depth.', 'In one embodiment, such porosity data can include data that characterizes total porosity of the formation at the particular depth.', 'At \n303\n, a data processor, which can be part of the processing system \n110\n of \nFIG.', '1\n, can be configured to invert the formation data for multiple depths in the wellbore.', 'Such inversion uses the dielectric data for a given depth as stored in \n301\n to derive a set of parameters (including the apparent cementation factor m\nn \nand the formation water saturation S\nw\n) that describes the local region of the formation corresponding to the given depth.', 'The resistivity data for the given depth as obtained and stored in \n301\n as well as the porosity data as obtained in \n301\n for the given depth can be used as constraints in deriving the set of parameters corresponding to the given depth as part of the inversion.', 'The result of the inversion are values for a set of parameters (e.g., m\nn\n, S\nw\n) for each one of the multiple depths.', 'The set of parameter values corresponding to each given depth can be added to a log of parameters or properties corresponding to different depths in the wellbore.', 'The log can be stored in computer memory, which can be part of the processing system \n110\n of \nFIG.', '1\n.', 'The values for the parameters and properties of the log can include the apparent cementation factor m\nn \nand the formation water saturation S\nw \nas well as other parameters and/or properties.', 'The log can be output for display in order to display the apparent cementation factor m\nn \nand the formation water saturation S\nw \nas well as other parameters and/or properties as desired.', 'If the resistivity data for the given depth has not been measured, resistivity data for the given depth can be estimated from other resistivity measurements and used as a constraint in the inversion of \n303\n.', 'Similarly, if the porosity data for the given depth has not been measured, porosity data for the given depth can be estimated from other porosity measurements and used as a constraint in the inversion of \n303\n.', 'In one embodiment, the predicted conductivity of the reservoir rock at a low frequency (DC limit) according to the Archie-like formulation given by Eqn. 1 can be used as a constraint in the inversion of \n303\n.', 'In this case, values for the DC rock conductivity, DC water conductivity and rock porosity provide a mathematical functional relationship between S\nw \nand m\nn \nat the low frequency (DC limit).', 'The DC rock conductivity can be provided by the resistivity tool measurement.', 'Rock porosity can be provided by the porosity measurement.', 'DC water conductivity can be inferred from literature or measured at the wellsite.', 'For example, when water-based mud is used, the DC resistivity of the mud can be inferred from literature or can be measured at the well-site and used to determine the DC water conductivity.', 'In this example, the mathematic functional relationship between S\nw \nand m\nn \nas derived from Eqn. 1 can be used in selecting (tuning) the values of S\nw \nand/or m\nn \nover iterations of the inversion when solving for the best fit parameters of S\nw \nand m\nn\n.', 'At \n305\n, the data processor, which can be part of the processing system \n110\n of \nFIG.', '1\n, can be configured to assign values of an index i to individual depths (or to depth intervals each consisting of a number of depths or measurement locations having similar petrophysical properties).', 'At \n307\n, the data processor, which can be part of the processing system \n110\n of \nFIG.', '1\n, can be configured to loop through the values for the index i as assigned in \n305\n.', 'For each iteration of the loop, the data processor can be configured to i) use the apparent cementation factor m\nn \nand the formation water saturation S\nw \nof the depth (or depth interval) that correspond to the value of index i for the loop iteration in order to calculate a cementation exponent m and/or a saturation exponent n for the depth (or depth interval), and then ii) add the cementation exponent m and/or the saturation exponent n for the depth (or depth interval) to the log of parameters or properties corresponding to different depths in the wellbore as stored in computer memory, which can be part of the processing system \n110\n of \nFIG.', '1\n.', 'The log (or additions thereto) can be output for display if desired.', 'In one embodiment, the porosity and water saturation measurements of the depth (or depth interval) associated with the value of the index i for the specific loop iteration can be used in \n307\n to calculate the value for a(i) according to Eqn. 8 above.', 'The values for a(i) and the apparent cementation factor m\nn\n(i) for the index i of the specific loop iteration can then be used to determine values for the cementation exponent m(i) and the saturation exponent n(i) for the index i of the specific loop iteration.', 'In some embodiments, Eqn. 9 can be used to calculate the cementation exponent m(i) and the saturation exponent n(i) (i.e., the cementation exponent m and the saturation exponent n for the index i of the specific loop iteration).', 'In some embodiments, where uncertainties associated with the apparent cementation factor m\nn \nvalue is obtained, Eqn. 10 can be used to calculate values for the cementation exponent m(i) and the saturation exponent n(i) for the index i of the specific loop iteration (i.e., values for the cementation exponent m and the saturation exponent n for the index i of the specific loop).', 'Note that the weights w(i) of Eqn. 10 are related to the uncertainties, typically by being the inverses of the uncertainties.', 'In other embodiments, for each depth interval, a(i), a number of m\nn \nvalues are generated, optionally plotted, and fit to a line in order to provide m and n estimates of m and n for the depth interval.', 'FIGS.', '4\nA and \n4\nB\n show values for dielectric constant and conductivity simulated from the Bimodal model as described above for different values of cementation exponent m and S\nw \n(and consequently different values of m\nn\n).', 'Note that the curves of the dielectric constant of \nFIG.', '4\nA\n (which relate to permittivity) have the highest difference at low frequencies less than 1 GHz.', 'Since the only parameter of Bimodal model that varies over the curves of the dielectric constant of \nFIG.', '4\nA\n is m\nn\n, it can be inferred that information about m\nn \nis mainly at low frequencies less than 1 GHz.', 'These results are expected as the apparent cementation factor m\nn \nis known to affect the interfacial polarization phenomenon, which is present at low frequencies only.', 'FIGS.', '5\nA and \n5\nB\n show the predicted dielectric constant and predicted conductivity, respectively, as derived from an inversion using the Bimodal Model as described above for two different cases (labeled “case-1” and “case-2”).', "For case-1, the inversion is based on the electromagnetic response data (e.g., amplitude and phase of the propagated waves with respect to the emitted waves) at four different frequencies as measured by a dielectric logging tool (in this case, Schlumberger's Dielectric Scanner).", 'The inversion of the computational model (forward model) used for case-1 need not employ an Archie-like DC limit (e.g., a constraint derived from Equation (1) as described above) as represented schematically in the schematic of \nFIG.', '6\nA\n.', "For case-2, the inversion is based on the electromagnetic response data (e.g., amplitude and phase of the propagated waves with respect to the emitted waves) at four different frequencies as measured by a dielectric logging tool (in this case, Schlumberger's Dielectric Scanner) as well as an additional measurement of conductivity at low frequency (DC limit) and an additional measurement of rock porosity.", "The measurement of conductivity at the low frequency (DC limit) can be the inverse of the low frequency (DC limit) resistivity as measured by a resistivity logging tool (in this case, Schlumberger's MicroCylindrically Focused Log (MCFL) tool).", 'The inversion of the computational model (forward model) used for case-2 employs an Archie-like DC limit (e.g., a constraint derived from Equation (1) as described above) as represented schematically in the schematic of \nFIG.', '6\nB\n.', 'Note that \nFIG.', '5\nA\n also shows error bars that represent the error between the predicted dielectric constant and measured dielectric constant at the four different frequencies as measured by a dielectric logging tool for the inversion of case-1. \nFIG.', '5\nB\n also shows error bars that represent the error between the predicted conductivity and measured conductivity at the four different frequencies as measured by a dielectric logging tool for the inversion of case-1. \nFIG.', '5\nB\n also shows an error bar that represents the error between the predicted conductivity and measured conductivity at the low frequency (DC limit) for the inversion of case-2.', 'The measured conductivity at the low frequency (DC limit) is the inverse of the low frequency (DC limit) resistivity as measured by a resistivity logging tool for case-2.', 'Note that the curves of \nFIG.', '5\nA\n show that the errorbars of the dielectric constant at lower frequencies is much higher than the errorbars of conductivity, due to the nature of the measurement.', 'This is because complex permittivity is close to the imaginary axis for low frequencies, resulting in a more accurate measurement for conductivity and higher error for the dielectric constant.', 'This fact leads to high errorbars in the apparent cementation factor m\nn\n, which are typically between 7%-10% in field data.', 'Also note that because the apparent cementation factor m\nn \nis more sensitive to low frequencies, the additional measurement of conductivity at low frequency (DC limit) used in the case-2 inversion can decrease the errorbar in the apparent cementation factor m\nn\n.', 'This is shown in the case-2 error bar of \nFIG.', '5\nB\n.', 'Furthermore, the apparent cementation factor m\nn \nneed not be derived from Eq.', '(1).', 'Instead, it can be derived as a direct parameter of the model or as a byproduct.', 'Thus, as part of the computation model, the apparent cementation factor m\nn \ncan be defined using Eq.', '(1), and computed using different expressions dependent on the model parameters.', 'As a consequence, for the same data set, the estimate of the apparent cementation factor m\nn \nis model dependent, making its interpretation challenging.', 'The use of the additional measurement of conductivity at low frequency (DC limit) as a constraint in the inversion can allow the computation model to provide a similar and consistent apparent cementation factor m\nn \nand can decrease the errorbar in the apparent cementation factor m\nn \nas derived from the inversion.', 'The accuracy of the inversion operations as described herein can be verified using simulated data created from the Bimodal model as follows.', 'Three parameters are inputs to the Bimodal model.', 'These three parameters include the apparent cementation factor m\nn\n, the water saturation S\nw\n, and the percentage of ellipsoidal inclusions p.', 'The parameter p is described in more detail in Kenneth S. Mendelson and Morrel H. Cohen, “The effect of grain anisotropy on the electrical properties of sedimentary rocks,” Geophysics, 47, pg.', '257-263, 1982 as well as P. N. Sen, “Grain shape effects on dielectric and electrical properties of rocks,” Geophysics, 49, pg.', '586-587, 1984.', 'The true values for the three Bimodal parameters are input to the Bimodal model to simulate dielectric data at four frequencies of the dielectric tool.', 'Random noise is added to the simulated dielectric data.', 'The noisy simulated dielectric data is compared to measured dielectric data at the same four frequencies of the dielectric tool, and the results of the comparison is used to revise the values for the three Bimodal parameters.', 'This inversion process can be repeated for multiple iterations until the solution converges by satisfying a predetermined stopping criterion.', 'The solution provides estimates for the three Bimodal parameters (m\nn\n, S\nw\n, and p) that characterize the reservoir rock.', 'Note that the dielectric data at the four frequencies of the dielectric tool have 10% error, while the error at the low frequency (DC limit) varies from 1% to 100%.', 'A Monte Carlo simulation can be performed by repeating this process multiple times to obtain the normalized root mean square error (NRMSE) of m\nn \nas follows:\n \n \n \n \n \n \n \n \n \nNRMSE\n \n\u2061\n \n(\n \n \nm\n \nn\n \n \n)\n \n \n=\n \n \n \n \n \n \n(\n \n \n \nm\n \n \nn\n \n,\n \ntrue\n \n \n \n-\n \n \nm\n \n \nn\n \n,\n \nmean\n \n \n \n \n)\n \n \n2\n \n \n+\n \n \nm\n \n \nn\n \n,\n \nstd\n \n \n2\n \n \n \n \n \nm\n \n \nn\n \n,\n \ntrue\n \n \n \n \n \n \n \n \n(\n \n7\n \n)\n \n \n \n \n \n \n \n where m\nn,true \nis the true value of the apparent cementation factor m\nn \nthat was used to simulate the dielectric data, m\nn,mean \nis the mean value of the apparent cementation factor m\nn \nfrom all the iterations of the Monte Carlo simulation and m\nn,std \nis the standard deviation of the apparent cementation factor m\nn \nfrom all the iterations of the Monte Carlo simulation.', 'FIG.', '7\n shows the NRMSE of the apparent cementation factor m\nn \nas a function of conductivity error at the low frequency (DC limit) for an exemplary Monte Carlo simulation as described above.', 'The error in the dielectric data at the four frequencies of the dielectric tool is assumed to be 10%.', 'The last point of the plot, which is a square, shows the NRMSE of the apparent cementation factor m\nn \nwhen the low frequency (DC limit) term of conductivity is not included as part of the inversion.', 'In this case, where the inversion utilizes the dielectric data at the four frequencies and ignores the low frequency (DC limit) term of conductivity, the NRMSE of the apparent cementation factor m\nn \nis 7%.', 'The other points of the plot, which are circles, show the NRMSE of the apparent cementation factor m\nn \nwhen the low frequency (DC limit) term of conductivity is included as part of the inversion.', 'In this case, where the inversion utilizes the dielectric data at the four frequencies in addition to the low frequency (DC limit) term of conductivity, the NRMSE of the apparent cementation factor m\nn \ngets reduced as the error of the conductivity at DC frequency gets smaller.', 'Specifically, the NRMSE of the apparent cementation factor m\nn \nis equal to 4% at the low frequency (DC limit) for the assumed 10% error in conductivity.', 'FIGS.', '8\nA to \n8\nF\n show distributions of three parameters (m\nn\n, S\nw\n, and p) of the Bimodal model that characterize the reservoir rock as obtained from the iterations of the exemplary Monte Carlo simulation used to derive the plot of \nFIG.', '7\n.', 'FIGS.', '8\nA and \n8\nB\n show distributions of the parameter p of the Bimodal model where the low frequency (DC limit) term of conductivity is not included as part of the inversion (\nFIG.', '8\nA\n) and where the low frequency (DC limit) term of conductivity is included as part of the inversion (\nFIG.', '8\nB\n).', 'FIGS.', '8\nC and \n8\nD\n show distributions of the parameter S\nw \nof the Bimodal model where the low frequency (DC limit) term of conductivity is not included as part of the inversion (\nFIG.', '8\nC\n) and where the low frequency (DC limit) term of conductivity is included as part of the inversion (\nFIG.', '8\nD\n).', 'FIGS.', '8\nE and \n8\nF\n show distributions of the parameter m\nn \nof the Bimodal model where the low frequency (DC limit) term of conductivity is not included as part of the inversion (\nFIG.', '8\nE\n) and where the low frequency (DC limit) term of conductivity is included as part of the inversion (\nFIG.', '8\nF\n).', 'FIGS.', '8\nA to \n8\nF\n also include lines that represent the true and mean values for the distributions of three parameters (m\nn\n, S\nw\n, and p) of the Bimodal model that characterize the reservoir rock.', 'Note that although the inversion operations of \nFIGS.', '7\n and \n8\nA to \n8\nF\n use the Bimodal Model as part of the inversion, other computational models capable of predicting the dielectric and resistivity response at multiple frequencies can be used to carry out the inversion.', 'Similarly, the low frequency (DC limit) term of conductivity as measured by the resistivity logging tool can be used to define other useful constraints for the inversion in order to improve the accuracy of the rock parameters that are produced by the inversion.', 'Also note that the values of m\nn\n, ϕ and S\nw \ncan be used to categorize the reservoir rock according to their pore geometry from the cementation exponent m and to infer wettability from the saturation exponent n. More specifically, the cementation exponent m and/or the saturation exponent n of the reservoir rock can be calculated using the values of m\nn\n, S\nw \nand ϕ of the reservoir rock (Block \n315\n of \nFIG.', '3\nB\n and Equations (8) and (9) above).', 'In one embodiment, the cementation exponent m and the saturation exponent n can be assumed to be constant over a set of measurements corresponding to a depth range of similar lithology downhole.', 'In this case, the reduction in the errorbar of the apparent cementation factor m\nn \ncan reduce the errorbars in the calculated values of the cementation exponent m and the saturation exponent n, respectively.', 'Furthermore, the additional measurement of the low frequency (DC limit) term of conductivity of the formation can also be used to increase the vertical resolution of the calculation of the cementation exponent m and the saturation exponent n, respectively.', 'This is summarized in Table 1 below.', 'TABLE 1\n \n \n \n \n \n \nError in\n \nNumber of\n \nError in\n \n \n \n \n \ndata\n \ndata points\n \nm\nn\n \nError in m\n \nError in n\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nCase 1 - 10%\n \n100\n \n7%\n \n3%\n \n13%\n \n \n \nwithout σ\nDC\n \n \n \nCase 2 - 10% +\n \n100\n \n4%\n \n2%\n \n10%\n \n \n \n10% in σ\nDC\n \n \n \nCase 3 - 10% +\n \n40\n \n4%\n \n3%\n \n13%\n \n \n \n10% in σ\nDC\n \n \n \n \n \n \n \n \n \n \nData was simulated with a 10% error using the Bimodal model.', 'In a first case (“case 1”), the simulation was run without inclusion of the low frequency (DC limit) measurement of conductivity of the formation using a depth range discretized by 100 points.', 'In this first case, the error in the apparent cementation factor m\nn \nis approximately 7% with an errorbar of 3% for the cementation exponent m and 13% for the saturation exponent n of the formation.', 'In a second case (“case 2”), the simulation was run with inclusion of the low frequency (DC limit) measurement of conductivity of the formation using a depth range discretized by 100 points.', 'In this second case, the error in the apparent cementation factor m\nn \nis approximately 4% with an errorbar of 2% for the cementation exponent m and 10% for the saturation exponent n of the formation.', 'These results show that reducing the errorbar for the apparent cementation factor m\nn \ncan reduce the errorbar in the cementation exponent m and the saturation exponent n over the same depth interval or increase the vertical resolution of these measurements.', 'In still other embodiments, the data processing operations that characterize the reservoir rock as described herein can be based on dielectric data, resisitivity data and/or porosity data acquired using laboratory measurements.', 'In such an embodiment, a number of core samples of reservoir rock can be extracted using a coring tool and/or wellbore cuttings collected during wellbore drilling operation.', 'The cores and/or cuttings can be analyzed in a laboratory with a different laboratory tool to derive dielectric data, resisitivity data and/or porosity data of the reservoir rock.', 'Such data can be inverted using the methodology as described herein to determine parameters and properties that characterize the reservoir rock.', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples without materially departing from this disclosure.', 'Thus, by way of example only, and not by way of limitation, while various embodiments describe specific tools and techniques, it will be appreciated that other tools and techniques may be utilized.', 'Further, while specific uses of the estimations of the parameters were described, it will be appreciated that any one or subsets of these parameters may be utilized for other purposes as well.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure.']

['1.', 'A method for determining values of at least one parameter of a geological formation, the method comprising:\ndetermining values for a set of parameters for a plurality of locations in the geological formation by inversion of formation data obtained from a plurality of different logging tools, wherein the inversion of the formation data that determines a set of parameters for each particular location in the geological formation is constrained by certain formation data that characterizes the particular location in the geological formation as obtained from at least one of the plurality of different logging tools, wherein the set of parameters for each particular location in the geological formation includes an apparent cementation factor mn and a formation water saturation Sw that are derived by inverting dielectric data that characterizes the particular location in the geological formation as obtained from a dielectric logging tool;\nusing the apparent cementation factor mn, the formation water saturation Sw, nd a formation porosity ϕ for the plurality of locations to determine an estimation of at least one of a cementation exponent m and a saturation exponent n of the geological formation; and\nusing the apparent cementation factor mn based at least in part on measurements in an invaded zone to estimate virgin zone water saturation and drilling into the virgin zone based at least in part on the estimated water saturation of the virgin zone estimated using the apparent cementation factor mn.\n\n\n\n\n\n\n2.', 'The method of claim 1, wherein:\nthe inversion of the formation data obtained from the plurality of different logging tools determines a set of parameters with reduced errorbar for such parameters.', '3.', 'The method of claim 1, wherein:\nthe dielectric data characterizes relative permittivity and conductivity at the particular location in the geological formation.', '4.', 'The method of claim 1, wherein:\nthe certain formation data that is used to constrain the inversion includes at least one of resistivity data obtained from a resistivity logging tool and porosity data obtained from a porosity logging tool.', '5.', 'The method of claim 4, wherein:\nthe certain formation data that is used to constrain the inversion includes resistivity data obtained from the resistivity logging tool, wherein the resistivity data characterizes DC resistance of the particular location in the geological formation.', '6.', 'The method of claim 4, wherein:\nthe certain formation data that is used to constrain the inversion includes porosity data obtained from the porosity logging tool, wherein the porosity data characterizes total porosity of the particular location in the geological formation.', '7.', 'The method of claim 1, wherein: a \u2061 ( i ) = log \u2061 ( ϕ \u2061 ( i ) ) log \u2061 ( ϕ \u2061', '( i ) )', '+ log \u2061 ( S w ( i ) ).', 'at least one of the cementation exponent m and the saturation exponent n are determined according to mn(i)=(m−n)a(i)+n, where mn(i) is an estimated mn at depth i of one of the plurality of locations, and\n\n\n\n\n\n\n8.', 'The method of claim 1, wherein:\nat least one of the cementation exponent m and the saturation exponent n are determined by fitting a line to points on a plot having mn and a(i) as axes, and finding the saturation exponent n as an intersection of the line to where a(i)=0.', '9.', 'The method of claim 1, wherein:\nat least one of the cementation exponent m and the saturation exponent n are determined by fitting a line to points on a plot having mn and a(i) as axes, and finding the cementation exponent m as an intersection of the line to where a(i)=1.', '10.', 'The method of claim 1, wherein: [ ∑ a 2 ( i ) ∑ a \u2061 ( i )', '\u2062', '( 1 - a \u2061 ( i ) ) ∑ a \u2061 ( i ) \u2062', '( 1 - a \u2061 ( i ) ) ∑ ( ( 1 - a \u2061 ( i ) )', '2 ]', '[ m n ] =', '[ ∑ a \u2061 ( i )', '\u2062', 'm', 'n', '( i ) ∑', '( 1 - a \u2061 ( i ) )', '\u2062 m', 'n ( i ) ].', 'at least one of the cementation exponent m and the saturation exponent n are determined by finding m and n according to\n\n\n\n\n\n\n11.', 'The method of claim 1, wherein: [ ∑ w \u2061 ( i ) \u2062 a 2 ( i ) ∑ w \u2061 ( i )', '\u2062', 'a \u2061 ( i )', '\u2062', '( 1 - a \u2061 ( i ) ) ∑ w \u2061 ( i ) \u2062', 'a \u2061 ( i )', '\u2062', '( 1 - a \u2061 ( i ) ) ∑ w \u2061 ( i ) \u2062 ( ( 1 - a \u2061 ( i ) )', '2 ] \u2062 \uf3a8 [ m n ] = [ ∑ w \u2061 ( i )', '\u2062', 'a \u2061 ( i )', '\u2062', 'm', 'n', '( i ) ∑ w \u2061 ( i )', '\u2062', '( 1 - a \u2061 ( i ) )', '\u2062 m', 'n ( i ) ], where w(i) are weights.\nat least one of the cementation exponent m and the saturation exponent n are determined by finding m and n according to\n\n\n\n\n\n\n12.', 'The method of claim 11, wherein:\nthe weights are a function of uncertainties associated with values of the apparent cementation factor mn.\n\n\n\n\n\n\n13.', 'The method of claim 1, wherein using the cementation factor mn to estimate the virgin zone water saturation comprises using the cementation exponent m and the saturation exponent n to estimate virgin zone water saturation according to σ=ϕmSwnσw, where σ is a measured conductivity of partially saturated rock at the plurality of locations and σw is the direct current conductivity of water at the plurality of locations.', '14.', 'The method of claim 1, wherein:\nthe inversion is carried out by a computer processing system.', '15.', 'The method of claim 14, further comprising:\nstoring the set of parameters for the plurality of locations as part of a log stored in computer memory of the computer processing system.', '16.', 'The method of claim 15, further comprising:\ndisplaying the log stored in the computer memory of the computer processing system in order to display the set of parameters for the plurality of locations that are part of the log.', '17.', 'The method of claim 1, wherein:\nthe plurality of different logging tools are realized by a string of logging tools of a bottom hole assembly that is conveyed in a wellbore that traverses the geological formation.', '18.', 'The method of claim 1, wherein:\nthe plurality of different logging tools are integrated into a unitary housing of a bottom hole assembly that is conveyed in a wellbore that traverses the geological formation.', '19.', 'The method of claim 1, wherein determining the value for the apparent cementation factor mn comprises using a measurement of conductivity at a DC limit.\n\n\n\n\n\n\n20.', 'A method for determining values of at least one parameter of a geological formation, the method comprising:\nobtaining formation data for a plurality of locations in the geological formation from a plurality of different logging tools; and\ndetermining values for a set of parameters for the plurality of locations in the geological formation by inversion of the formation data, wherein the inversion of the formation data that determines a set of parameters for each particular location in the geological formation is constrained by certain formation data that characterizes the particular location as obtained from at least one of the plurality of different logging tools, wherein the plurality of different logging tools includes a dielectric logging tool;\nthe formation data includes dielectric data that characterizes each particular location in the geological formation as obtained from the dielectric logging tool;\nthe set of parameters for each particular location in the geological formation includes an apparent cementation factor mn and a formation water saturation Sw that are derived by inverting the dielectric data obtained from the dielectric logging tool;\nusing the apparent cementation factor mnn, the formation water saturation Sw, and a formation porosity ϕ for the plurality of locations to determine an estimation of at least one of a cementation exponent m and a saturation exponent n of the geological formation; and\nusing the apparent cementation factor mn based at least in part on measurements in an invaded zone to estimate virgin zone water saturation and drilling into the virgin zone based at least in part on the estimated water saturation of the virgin zone estimated using the apparent cementation factor mnn.', '21.', 'The method of claim 20, wherein:\nthe dielectric data characterizes relative permittivity and conductivity at the particular location in the geological formation.', '22.', 'The method of claim 20, wherein:\nthe plurality of different logging tools includes at least one of a resistivity logging tool and a porosity logging tool; and\nthe certain formation data that is used to constrain the inversion includes at least one of resistivity data obtained from the resistivity logging tool and porosity data obtained from the porosity logging tool.', '23.', 'The method of claim 22, wherein:\nthe certain formation data that is used to constrain the inversion includes resistivity data obtained from the resistivity logging tool, wherein the resistivity data characterizes DC resistance of the particular location in the geological formation.', '24.', 'The method of claim 22, wherein:\nthe certain formation data that is used to constrain the inversion includes porosity data obtained from the porosity logging tool, wherein the porosity data characterizes total porosity of the particular location in the geological formation.', '25.', 'The method of claim 20, wherein using the cementation factor mn to estimate the virgin zone water saturation comprises using the cementation exponent m and the saturation exponent n to estimate virgin zone water saturation according to σ=ϕmSwnσw, where σ is a measured conductivity of partially saturated rock at the plurality of locations and σw is the direct current conductivity of water at the plurality of locations.', '26.', 'The method of claim 20, wherein determining the value for the apparent cementation factor mn comprises using a measurement of conductivity at a DC limit.', '27.', 'A method for characterizing a porous medium, the method comprising:\ndetermining values for a set of parameters that characterize the porous medium by inversion of data obtained from a plurality of different tools, wherein the inversion of the data that determines the set of parameters is constrained by certain data that characterizes the porous medium as obtained from at least one of the plurality of different tools, wherein the plurality of different tools includes a dielectric logging tool;\nthe data includes dielectric data that characterizes each particular location in a geological formation as obtained from the dielectric logging tool;\nthe set of parameters for each particular location in the geological formation includes an apparent cementation factor mn and a formation water saturation Sw that are derived by inverting the dielectric data obtained from the dielectric logging tool;\nusing the apparent cementation factor mnn, the formation water saturation Sw, and a formation porosity ϕ for each particular location to determine an estimation of at least one of a cementation exponent m and a saturation exponent n of the geological formation; and\nusing the apparent cementation factor mn based at least in part on measurements in an invaded zone to estimate virgin zone water saturation and drilling into the virgin zone based at least in part on the estimated water saturation of the virgin zone estimated using the apparent cementation factor mn.\n\n\n\n\n\n\n28.', 'The method of claim 27, wherein:\nthe dielectric data characterizes relative permittivity and conductivity of the porous medium.\n\n\n\n\n\n\n29.', 'The method of claim 27, wherein:\nthe certain data that is used to constrain the inversion includes at least one of resistivity data obtained from a resistivity tool and porosity data obtained from a porosity tool.', '30.', 'The method of claim 27, wherein:\nthe porous medium is reservoir rock.', '31.', 'The method of claim 27, wherein:\nthe plurality of different tools comprises a plurality of downhole logging tools.\n\n\n\n\n\n\n32.', 'The method of claim 27, wherein:\nthe plurality of different tools comprises a plurality of laboratory tools.\n\n\n\n\n\n\n33.', 'The method of claim 27, wherein using the cementation factor mn to estimate the virgin zone water saturation comprises using the cementation exponent m and the saturation exponent n to estimate virgin zone water saturation according to a σ=ϕmSwnσw, where σ is a measured conductivity of partially saturated rock at a plurality of locations and σw is the direct current conductivity of water at the plurality of locations.']

['FIG.', '1 shows a wellbore logging tool that can be used to acquire formation data that characterizes a formation;; FIG.', '2 illustrates an example computing device that can be used in accordance with various embodiments of the present disclosure;; FIG.', '3 is a flow chart that shows a method in accordance with one embodiment of the present disclosure;; FIGS.', '4A and 4B are plots of dielectric constant and conductivity, respectively, as a function of frequency for a number of different combinations of cementation exponent m and water saturation S;; FIGS.', '5A and 5B are plots of dielectric constant and conductivity, respectively, as a function of frequency as determined by inversion of two computational models that are depicted schematically in FIGS.', '6A and 6B;; FIG. 7 is a plot of normalized root mean square error of the apparent cementation factor mn as a function of the relative error of DC conductivity, which is obtained from inversions using the computational models of FIGS.', '6A and 6B in conjunction with Monte Carlo simulations;; FIGS.', '8A and 8B are plots that show the distribution of the parameter p (percentage of ellipsodoidal inclusions) as well as true and mean values for the parameter p that are obtained from inversions used in conjunction with Monte Carlo simulations.', 'The plot of FIG.', '8A is derived from an inversion using the computational model of FIG.', '6A, while the plot of FIG.', '8B is derived from an inversion using the computational model of FIG.', '6B;; FIGS.', '8C and 8D are plots that show the distribution of the water saturation Sw as well as true and mean values of the water saturation Sw that are obtained from inversions used in conjunction with Monte Carlo simulations.', 'The plot of FIG.', '8C is derived from an inversion using the computational model of FIG.', '6A, while the plot of FIG.', '8D is derived from an inversion using the computational model of FIG.', '6B; and; FIGS.', '8E and 8F are plots that show the distribution of the apparent cementation factor mn as well as true and mean values of the apparent cementation factor mn that are obtained from inversions used in conjunction with Monte Carlo simulations.', 'The plot of FIG.', '8E is derived from an inversion using the computational model of FIG.', '6A, while the plot of FIG.', '8F is derived from an inversion using the computational model of FIG.', '6B.; FIG.', '1 illustrates a wellsite 100 for which embodiments of multi-tool measurement processing can be employed.', 'Wellsite 100 can be onshore or offshore.', 'In this example system, a bottom hole assembly is positioned within a wellbore 102 that traverses a formation 104.', 'The wellbore 102 can have a vertical inclination as shown.', 'In other embodiments, the wellbore 102 can have a portion with a vertical (or near-vertical) inclination that leads to a curved transition that leads to a portion with a horizontal (or near-horizontal) inclination.', 'Other more complex configurations of the wellbore can be used to traverse the formation 104 as well.', 'The bottom hole assembly can include a string of a number of downhole logging tools 106, 108, 109 that can be conveyed in the wellbore 102 by the wireline cable 112 (or other suitable conveyance means, such as drill pipe, coiled tubing, or tractor).', 'Downhole logging tool 106 is a dielectric logging tool that can be located at one or more depths of the formation 104 and operated to perform dielectric measurements at the one or more depths of the formation 104 to obtain dielectric data at different operational frequencies for the one or more depths of the formation 104.', 'Downhole logging tool 108 is a resistivity logging tool that can be located at one or more depths of the formation 104 and operated to perform resistivity measurements at the one or more depths of the formation 104 to obtain resistivity data for the one or more depths of the formation 104.', 'Downhole logging tool 109 is a porosity logging tool (such as an NMR logging tool or neutron porosity logging tool or other logging tool) that can be located at one or more depths of the formation 104 and operated to perform measurements that obtain porosity data for the one or more depths of the formation 104.', 'The logging tools (e.g., tools 106, 108, 109, etc.) of the bottom hole assembly can be coupled to a processing system 110 via a telemetry subsystem, which can be part of the wireline cable 112 or which can implement other data telemetry methods.', 'The processing system 110 is located at a surface location.', 'Signals and data that are acquired by the logging tools of the bottom hole assembly are communicated uphole by the telemetry subsystem for processing and analysis by the processing system 110.', 'The processing system 110 can be proximate and/or remote from the wellsite 100 (for example, at a computer located at or near the wellsite, a computer located at a remote command center, combinations thereof, etc.)', 'In an alternate embodiment, the processing system 110 or part thereof can be integrated as part of the bottom hole assembly.', 'In one possible embodiment, the processing system 110 or parts thereof can be used to perform various aspects of the multi-tool measurement processing as described herein.; FIG. 2 illustrates an example device 200 (including a processor 202 and computer memory 204) that can be configured to implement various operations of the multi-tool measurement processing discussed in this disclosure.', 'Computer memory 204 can include one or more forms of volatile data storage media such as random access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).;', 'FIGS. 4A and 4B show values for dielectric constant and conductivity simulated from the Bimodal model as described above for different values of cementation exponent m and Sw (and consequently different values of mn).', 'Note that the curves of the dielectric constant of FIG.', '4A (which relate to permittivity) have the highest difference at low frequencies less than 1 GHz.', 'Since the only parameter of Bimodal model that varies over the curves of the dielectric constant of FIG.', '4A is mn, it can be inferred that information about mn is mainly at low frequencies less than 1 GHz.', 'These results are expected as the apparent cementation factor mn is known to affect the interfacial polarization phenomenon, which is present at low frequencies only.; FIGS.', '5A and 5B show the predicted dielectric constant and predicted conductivity, respectively, as derived from an inversion using the Bimodal Model as described above for two different cases (labeled “case-1” and “case-2”).', "For case-1, the inversion is based on the electromagnetic response data (e.g., amplitude and phase of the propagated waves with respect to the emitted waves) at four different frequencies as measured by a dielectric logging tool (in this case, Schlumberger's Dielectric Scanner).", 'The inversion of the computational model (forward model) used for case-1 need not employ an Archie-like DC limit (e.g., a constraint derived from Equation (1) as described above) as represented schematically in the schematic of FIG.', "6A. For case-2, the inversion is based on the electromagnetic response data (e.g., amplitude and phase of the propagated waves with respect to the emitted waves) at four different frequencies as measured by a dielectric logging tool (in this case, Schlumberger's Dielectric Scanner) as well as an additional measurement of conductivity at low frequency (DC limit) and an additional measurement of rock porosity.", "The measurement of conductivity at the low frequency (DC limit) can be the inverse of the low frequency (DC limit) resistivity as measured by a resistivity logging tool (in this case, Schlumberger's MicroCylindrically Focused Log (MCFL) tool).", 'The inversion of the computational model (forward model) used for case-2 employs an Archie-like DC limit (e.g., a constraint derived from Equation (1) as described above) as represented schematically in the schematic of FIG.', '6B.; FIG.', '7 shows the NRMSE of the apparent cementation factor mn as a function of conductivity error at the low frequency (DC limit) for an exemplary Monte Carlo simulation as described above.', 'The error in the dielectric data at the four frequencies of the dielectric tool is assumed to be 10%.', 'The last point of the plot, which is a square, shows the NRMSE of the apparent cementation factor mn when the low frequency (DC limit) term of conductivity is not included as part of the inversion.', 'In this case, where the inversion utilizes the dielectric data at the four frequencies and ignores the low frequency (DC limit) term of conductivity, the NRMSE of the apparent cementation factor mn is 7%.', 'The other points of the plot, which are circles, show the NRMSE of the apparent cementation factor mn when the low frequency (DC limit) term of conductivity is included as part of the inversion.', 'In this case, where the inversion utilizes the dielectric data at the four frequencies in addition to the low frequency (DC limit) term of conductivity, the NRMSE of the apparent cementation factor mn gets reduced as the error of the conductivity at DC frequency gets smaller.', 'Specifically, the NRMSE of the apparent cementation factor mn is equal to 4% at the low frequency (DC limit) for the assumed 10% error in conductivity.; FIGS.', '8A to 8F show distributions of three parameters (mn, Sw, and p) of the Bimodal model that characterize the reservoir rock as obtained from the iterations of the exemplary Monte Carlo simulation used to derive the plot of FIG.', '7. FIGS.', '8A and 8B show distributions of the parameter p of the Bimodal model where the low frequency (DC limit) term of conductivity is not included as part of the inversion (FIG.', '8A) and where the low frequency (DC limit) term of conductivity is included as part of the inversion (FIG.', '8B).', 'FIGS.', '8C and 8D show distributions of the parameter Sw of the Bimodal model where the low frequency (DC limit) term of conductivity is not included as part of the inversion (FIG.', '8C) and where the low frequency (DC limit) term of conductivity is included as part of the inversion (FIG.', '8D).', 'FIGS.', '8E and 8F show distributions of the parameter mn of the Bimodal model where the low frequency (DC limit) term of conductivity is not included as part of the inversion (FIG.', '8E) and where the low frequency (DC limit) term of conductivity is included as part of the inversion (FIG.', '8F).', 'FIGS.', '8A to 8F also include lines that represent the true and mean values for the distributions of three parameters (mn, Sw, and p) of the Bimodal model that characterize the reservoir rock.']

US11905773

Securing an internal assembly within a tool

Feb 14, 2020

James Edward Atkins, Seweryn Wrozyna

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion in International Patent Application No. PCT/US2020/018221, dated Nov. 3, 2020, 12 pages.

4655290; April 7, 1987; Smith, Jr.; 4722390; February 2, 1988; Smith, Jr.; 5333685; August 2, 1994; Gilbert; 7063175; June 20, 2006; Kerstetter; 7373974; May 20, 2008; Connell; 7931085; April 26, 2011; Moyes; 8453724; June 4, 2013; Zhou; 9976349; May 22, 2018; Altimas; 20110042107; February 24, 2011; Chambers et al.; 20150129307; May 14, 2015; Pope; 20160281429; September 29, 2016; Wilson; 20210017834; January 21, 2021; Sundarraj

2019240835; December 2019; WO

['A tool includes an internal assembly configured to be positioned at least partially within a body.', 'The tool also includes a collet configured to be positioned at least partially within the body and axially-adjacent to the internal assembly.', 'The collet includes a plurality of fingers that are circumferentially-offset from one another.', 'At least one of the fingers includes a protrusion that extends radially-outward and is configured to be positioned at least partially within a recess formed in an inner surface of the body to secure the collet in place with respect to the body.', 'The tool also includes a collet pin configured to be positioned at least partially within the body, axially-adjacent to the internal assembly, and at least partially within the collet.', 'The collet pin is configured to contact the internal assembly to secure the internal assembly in place within the body.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nDownhole tools oftentimes have one or more internal assemblies positioned therein.', 'More particularly, the downhole tool may include a body defining an internal volume.', 'For example, the body may have a bore formed at least partially therethrough.', 'The internal assembly may be positioned at least partially within the internal volume (e.g., the bore).', 'The internal assembly may be or include any component that may be run downhole in the downhole tool, such as, for example, a measurement tool, a filter tool, a battery, or the like.', 'The internal assembly may be secured to the body (e.g., within the bore) to prevent the internal assembly from moving freely within the body, which may damage the internal assembly.', 'Oftentimes, the internal assembly may be secured to the body by threads or bolts.', 'However, sometimes, the internal assembly cannot be threaded or bolted to the body, and another way to secure the internal assembly may be useful.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'A tool is disclosed.', 'The tool includes an internal assembly configured to be positioned at least partially within a body.', 'The tool also includes a collet configured to be positioned at least partially within the body and axially-adjacent to the internal assembly.', 'The collet includes a plurality of fingers that are circumferentially-offset from one another.', 'At least one of the fingers includes a protrusion that extends radially-outward and is configured to be positioned at least partially within a recess formed in an inner surface of the body to secure the collet in place with respect to the body.', 'The collet also includes inner threads on an inner surface thereof.', 'The tool also includes a collet pin configured to be positioned at least partially within the body, axially-adjacent to the internal assembly, and at least partially within the collet.', 'The collet pin includes outer threads on an outer surface thereof that are configured to engage the inner threads of the collet to secure the collet pin in place with respect to the collet.', 'The collet pin is configured to contact the internal assembly to secure the internal assembly in place within the body.', 'A collecting tool is also disclosed.', 'The collecting tool includes a substantially tubular body defining an axial bore.', 'The bore is configured to have a drilling fluid flow therethrough.', 'An internal assembly is configured to be positioned at least partially within the bore.', 'The internal assembly includes a magnet holder and a plurality of magnets positioned at least partially within the magnet holder.', 'The magnets are configured to attract magnetic debris in the drilling fluid.', 'A collet is configured to be positioned at least partially within the bore and axially-adjacent to the internal assembly.', 'The collet includes a plurality of fingers that are circumferentially-offset from one another.', 'At least one of the fingers includes a protrusion that extends radially-outward and is configured to be positioned at least partially within a recess formed in an inner surface of the body to secure the collet in place with respect to the body.', 'The collet further includes inner threads on an inner surface thereof.', 'A collet pin is configured to be positioned at least partially within the bore, axially-adjacent to the internal assembly, and at least partially within the collet.', 'The collet pin includes outer threads on an outer surface thereof that are configured to engage the inner threads of the collet to secure the collet pin in place with respect to the collet.', 'The collet pin is configured to contact the internal assembly to secure the internal assembly in place within the body.', 'A method for assembling and/or using a tool is also disclosed.', 'The method includes inserting an internal assembly into a body of the tool.', 'The method also includes inserting a collet into the body.', 'The collet is positioned axially-adjacent to the internal assembly.', 'A protrusion on the collet is positioned at least partially within a recess in an inner surface of the body to secure the collet in place within the body.', 'The method also includes inserting a collet pin into the body.', 'The collet pin is positioned axially-adjacent to the internal assembly and at least partially within the collet.', 'The method also includes inserting a collet tool at least partially into the body.', 'The method also includes engaging the collet with the collet tool.', 'The method also includes inserting a collet pin tool at least partially into the body.', 'The method also includes engaging the collet pin with the collet pin tool.', 'The method also includes connecting the collet pin to the collet, using the collet tool and the collet pin tool, to secure the collet pin in place within the body.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is best understood from the following detailed description when read with the accompanying Figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n illustrates a schematic view of an example of a drilling system, according to an embodiment.\n \nFIG.', '2\n illustrates a cross-sectional side view of an example of a tool in the drilling system, according to an embodiment.\n \nFIG.', '3\n illustrates an enlarged cross-sectional side view of a portion of \nFIG.', '2\n, according to an embodiment.', 'FIG.', '4\n illustrates a perspective view of a collet and a collet pin of the tool, according to an embodiment.\n \nFIG.', '5\n illustrates a flowchart of a method for assembling the tool and/or using the tool, according to an embodiment.\n \nFIG.', '6\n illustrates a cross-sectional side view of an internal assembly positioned within a body of the tool, according to an embodiment.\n \nFIG.', '7\n illustrates a cross-sectional side view of the collet positioned within the body and axially-adjacent to the internal assembly, according to an embodiment.\n \nFIG.', '8\n illustrates a cross-sectional side view of the collet pin positioned within the body and at least partially within the collet, according to an embodiment.\n \nFIG.', '9\n illustrates a cross-sectional side view of a collet tool inserted into the body and engaging the collet, according to an embodiment.\n \nFIG.', '10\n illustrates a cross-sectional side view of a collet pin tool inserted into the body and engaging the collet pin, according to an embodiment.', 'DETAILED DESCRIPTION\n \nIllustrative examples of the subject matter claimed below will now be disclosed.', 'In the interest of clarity, not all features of an actual implementation are described in this specification.', "It will be appreciated that in the development of any such actual implementation, numerous implementation-specific decisions may be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort, even if complex and time-consuming, would be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'Further, as used herein, the article “a” is intended to have its ordinary meaning in the patent arts, namely “one or more.”', 'Herein, the term “about” when applied to a value generally means within the tolerance range of the equipment used to produce the value, or in some examples, means plus or minus 10%, or plus or minus 5%, or plus or minus 1%, unless otherwise expressly specified.', 'Further, herein the term “substantially” as used herein means a majority, or almost all, or all, or an amount with a range of about 51% to about 100%, for example.', 'Moreover, examples herein are intended to be illustrative only and are presented for discussion purposes and not by way of limitation.\n \nFIG.', '1\n illustrates a schematic view of an example of a drilling system \n110\n, according to an embodiment.', 'The drilling system \n110\n may be provided at a wellsite which may be an onshore or offshore wellsite, and the drilling system \n110\n may include any combination of the various elements described herein.', 'The drilling system \n110\n may form a borehole \n11\n in a subsurface formation by rotary drilling with a drill string \n12\n suspended within the borehole \n11\n.', 'The drilling system \n110\n may include a platform and derrick assembly \n10\n positioned over the borehole \n11\n.', 'The platform and derrick assembly \n10\n may include a rotary table \n16\n, a kelly \n17\n, a hook \n18\n, and/or a rotary swivel \n19\n.', 'The drill string \n12\n may be rotated by the rotary table \n16\n, which engages the kelly \n17\n at the upper end of the drill string \n12\n.', 'The drill string \n12\n may be suspended from the hook \n18\n, attached to a traveling block, through the kelly \n17\n and the rotary swivel \n19\n, which permits rotation of the drill string \n12\n relative to the hook \n18\n.', 'In another embodiment, a top drive system may be utilized instead of the rotary table \n16\n and/or the kelly \n17\n to rotate the drill string \n12\n from the surface above the borehole \n11\n.', 'The drill string \n12\n may be assembled from a plurality of segments \n125\n that may be or include pipe and/or collars.', 'The drilling system \n110\n may also include a BHA \n120\n connected to a lower end of the drill string \n12\n.', 'The BHA \n120\n may include a logging-while-drilling (hereinafter “LWD”) tool \n130\n, a measuring-while-drilling (hereinafter “MWD”) tool \n140\n, a motor \n150\n, a drill bit \n122\n, or a combination thereof.', 'The drilling system \n110\n may further include a drilling fluid or mud \n26\n (hereinafter “drilling fluid \n26\n”) stored in a pit \n27\n formed at the wellsite.', 'A pump \n29\n may deliver the drilling fluid \n26\n to an interior of the drill string \n12\n via a port in the rotary swivel \n19\n, which may cause the drilling fluid \n26\n to flow downwardly through the drill string \n12\n and the BHA \n120\n, as indicated by the directional arrow \n8\n.', 'The drilling fluid \n26\n may exit via ports in the drill bit \n122\n, and then circulate upwardly through an annulus between an outside of the drill string \n12\n and a wall of the borehole \n11\n, as indicated by directional arrows \n9\n.', 'The drilling fluid \n26\n may lubricate the drill bit \n122\n and/or may carry formation cuttings up to the surface adjacent to the borehole \n11\n.', 'The drilling fluid \n26\n may by returned to the pit \n27\n for cleaning and recirculation.', 'The drilling system \n110\n may also include a tool \n100\n, which may be run into the borehole \n11\n (e.g., on the drill string \n12\n).', 'For example, the tool \n100\n may be connected to the drill string \n12\n, the BHA \n120\n, or both.', 'As described in greater detail below, the tool \n100\n may have an internal assembly positioned at least partially therein.', 'In the embodiment described below, the internal assembly may be or include a filtering tool.', 'More particularly, the internal assembly may be or include a magnetic filtering tool that is configured to separate magnetic, metallic, ferrous, and/or ferromagnetic debris (hereinafter “magnetic debris”) from the drilling fluid \n26\n.', 'However, as will be appreciated, this is merely one example of an internal assembly, and the internal assembly may also or instead include other (e.g., non-magnetic and/or non-filtering) tools such as measurement tools, batteries, etc.', 'In the embodiment shown, the tool \n100\n may be positioned above and/or upstream from the BHA \n120\n.', 'If the magnetic debris enters the BHA \n120\n, the magnetic debris may damage the BHA \n120\n and/or reduce the efficiency of the BHA \n120\n.', 'Thus, in one embodiment, the tool \n100\n may be configured to separate at least a portion of the magnetic debris from the drilling fluid \n26\n, prior to the drilling fluid \n26\n flowing into the BHA \n120\n.', 'The tool \n100\n may collect and/or store the magnetic debris therein.', 'The magnetic debris that remains within the tool \n100\n may be removed or collected therefrom at the surface of the wellsite after the tool \n100\n has been pulled out of the borehole \n11\n.', 'In another embodiment, the magnetic debris that remains within the tool \n100\n may be removed or collected therefrom while the tool \n100\n is being pulled out of the borehole \n11\n.', 'In yet another embodiment, the magnetic debris that remains within the tool \n100\n may be removed or collected therefrom in the borehole \n11\n by one or more downhole tools and/or components.', 'As will be appreciated, collecting the magnetic debris in the tool \n100\n may prevent the magnetic debris or at least a portion of the magnetic debris from reaching and potentially damaging the BHA \n120\n.', 'In an embodiment, the tool \n100\n may minimize pressure loss across the drilling system \n110\n by collecting the magnetic debris.', 'In another embodiment, the tool \n100\n may reduce or prevent the magnetic debris from interfering with any directional survey tools conducted in/by the BHA \n120\n.\n \nFIG.', '2\n illustrates a cross-sectional side view of an example of the tool \n100\n, according to an embodiment.', 'The tool \n100\n may include a body \n210\n having a first (e.g., upstream) end \n212\n and a second (e.g., downstream) end \n214\n.', 'The first end \n212\n may be connected to a segment \n125\n of the drill string \n12\n.', 'The second end \n214\n may be connected to the BHA \n120\n or to a segment \n125\n of the drill string \n12\n that is positioned between the tool \n100\n and the BHA \n120\n.', 'The body \n210\n may define an axial bore \n216\n that extends from the first end \n212\n to the second end \n214\n.', 'An internal assembly \n230\n may be positioned at least partially within the body \n210\n (e.g., within the bore \n216\n).', 'As mentioned above, while the following embodiment of the internal assembly \n230\n is configured to filter the magnetic debris from the drilling fluid \n26\n, in other embodiments, the internal assembly \n230\n may also or instead include other (e.g., non-magnetic and/or non-filtering) tools such as measurement tools, batteries, etc.', 'In one embodiment, the internal assembly \n230\n may include a magnet holder \n234\n.', 'A lower end \n235\n of the internal assembly (e.g., the magnet holder \n234\n) may be configured to contact an internal shoulder \n218\n formed on an inner surface of the body \n210\n.', 'This may prevent the internal assembly \n230\n from moving farther in the downstream direction (e.g., to the right in \nFIG. \n2\n).', 'A plurality of magnets \n236\n may be connected to, positioned within, or otherwise held by the magnet holder \n234\n.', 'The magnets \n236\n may be axially-offset and/or circumferentially-offset from one another.', 'As described in greater detail below, the magnets \n236\n may be configured to attract magnetic debris in the drilling fluid \n26\n.', 'The internal assembly \n230\n may also include a sleeve \n238\n positioned at least partially around the magnet holder \n234\n.', 'The internal assembly \n230\n may also include an adapter \n240\n that is coupled to or positioned proximate to a first (e.g., upstream) end of the magnet holder \n234\n and/or the sleeve \n238\n.', 'The drilling fluid \n26\n may flow down the drill string \n12\n and into the bore \n216\n of the body \n210\n via the first end \n212\n of the body \n210\n.', 'At least a portion of the magnetic debris in the drilling fluid \n26\n may be attracted by the magnets \n236\n and thus collected by/within the tool \n100\n.', 'The drilling fluid \n26\n, with at least a portion of the magnetic debris separated/removed therefrom, may then be discharged from the bore \n216\n of the body \n210\n via the second end \n214\n of the body \n210\n and flow into the BHA \n120\n.', 'FIG.', '3\n illustrates an enlarged portion of \nFIG.', '2\n, according to an embodiment.', 'Referring to \nFIGS.', '2\n and \n3\n, a collet \n250\n may also be positioned at least partially within the body \n210\n (e.g., within the bore \n216\n).', 'The collet \n250\n may be or include an annular member that includes a first (e.g., upstream) end \n252\n and a second (e.g., downstream) end \n254\n.', 'The second end \n254\n may be positioned axially-adjacent to the internal assembly \n230\n (e.g., the adapter \n240\n).', 'As shown, an axial gap \n256\n may be present between the second end \n254\n of the collet \n250\n and the adapter \n240\n.', 'In another embodiment, the second end \n254\n may contact the adapter \n240\n.', 'In yet another embodiment, the adapter \n240\n may be omitted, and the second end \n254\n may contact the magnet holder \n234\n or the sleeve \n238\n directly.\n \nFIG.', '', '4\n illustrates a perspective view of a portion of \nFIG.', '3\n, according to an embodiment.', 'Referring to \nFIGS.', '3\n and \n4\n, the first end \n252\n of the collet \n250\n may include one or more tool-engaging features \n258\n.', 'The tool-engaging features \n258\n may be or include a plurality of circumferentially-offset teeth that include alternating peaks and valleys.', 'The second end \n254\n of the collet \n250\n may include a plurality of circumferentially-offset fingers \n260\n.', 'One or more of the fingers \n260\n may include a protrusion \n262\n that extends radially-outward therefrom.', 'As described in greater detail below, as the collet \n250\n is being inserted into the body \n210\n, the contact between the protrusions \n262\n and the inner surface of the body \n210\n may cause the fingers \n260\n to flex radially-inward.', 'The inner surface of the body \n210\n may define a recess \n220\n that is configured to receive the protrusions \n262\n.', 'When the protrusions \n262\n reach the recess \n220\n, the fingers \n260\n may flex radially-outward, allowing the protrusions \n262\n to be positioned at least partially within the recess \n220\n.', 'This may secure the collet \n250\n axially in place within the body \n210\n.', 'Referring now to \nFIGS.', '2\n-\n4\n, a collet pin \n270\n may also be positioned at least partially within the body \n210\n (e.g., within the bore \n216\n).', 'The collet pin \n270\n may be or include an annular member that is configured to be positioned at least partially within the collet \n250\n.', 'The collet pin \n270\n may also or instead be positioned axially-adjacent to the internal assembly \n230\n.', 'More particularly, as illustrated in \nFIGS.', '2\n and \n3\n, the collet pin \n270\n may be positioned axially-adjacent to the adapter \n240\n.', 'The collet pin \n270\n may include one or more tool engaging features \n272\n.', 'As shown, the tool-engaging feature \n272\n may be or include the inner surface of the collet pin \n270\n, which may have a polygonal (e.g., square, rectangle, pentagon, hexagon, etc.)', 'cross-sectional shape that is configured to receive a collet pin tool.', 'In another embodiment, the tool engaging feature \n272\n may be or include the upstream end of the collet pin \n270\n, which may include a plurality of circumferentially-offset teeth that include alternating peaks and valleys, similar to the tool engaging features \n258\n of the collet \n250\n, but positioned radially-inward therefrom.', 'The collet pin \n270\n may be rotated with respect to the collet \n250\n to cause outer threads \n274\n on the outer surface of the collet pin \n270\n to engage inner threads \n264\n on the inner surface of the collet \n250\n.', 'This may connect the collet \n250\n and the collet pin \n270\n together, which may secure the collet pin \n270\n axially in place within the body \n210\n.', 'As the collet pin \n270\n rotates with respect to the collet \n250\n, the collet pin \n270\n may move axially toward and eventually contact the adapter \n240\n and/or exert an axial force on the adapter \n240\n in the downstream direction.', 'As described in greater detail below, the internal assembly \n230\n may be secured axially in place within the body \n210\n by/between the internal shoulder \n218\n of the body \n210\n and the collet pin \n270\n.', 'More particularly, the end \n235\n of the magnet holder \n234\n may be in contact with the internal shoulder \n218\n in the body \n210\n, thereby preventing further downstream movement of the internal assembly \n230\n.', 'The adapter \n240\n may be in contact with the collet pin \n270\n, which is secured axially in place within the body \n210\n, thereby preventing further upstream movement of the internal assembly \n230\n.', 'Together, the collet \n250\n and the collet pin \n270\n may help to secure the internal assembly \n230\n in place within the body \n210\n of the tool \n100\n, while providing the axial bore \n216\n through the tool \n100\n.', 'The bore \n216\n may be used to pump the drilling fluid \n26\n through the tool \n100\n.', 'In another embodiment, the bore \n216\n may also or instead provide a path for another tool (e.g., a fishing tool) to pass through the collet \n250\n and the collet pin \n270\n to access the internal assembly \n230\n or a component below the tool \n100\n (e.g., the BHA \n120\n).\n \nFIG.', '5\n illustrates a flowchart of a method \n500\n for assembling and/or using the tool \n100\n, according to an embodiment.', 'For example, the method \n500\n may be used to secure the internal assembly \n230\n in the body \n210\n.', 'An illustrative order of the method \n500\n is provided below; however, as will be appreciated, one or more portions of the method \n500\n may be performed in a different order or omitted.', 'The method \n500\n may include inserting the internal assembly \n230\n into the body \n210\n (e.g., into the bore \n216\n), as at \n502\n.', 'This is shown in \nFIG.', '6\n.', 'The internal assembly \n230\n may be inserted until the end \n235\n of the magnet holder \n234\n contacts the internal shoulder \n218\n of the body \n210\n, which may prevent further downstream movement of the magnet holder \n234\n within the body \n210\n.', 'The magnet holder \n234\n may be holding the magnets \n236\n.', 'The method \n500\n may also include inserting the collet \n250\n into the body \n210\n (e.g., into the bore \n216\n), as at \n504\n.', 'This is shown in \nFIG.', '7\n.', 'The collet \n250\n may be inserted until the protrusions \n262\n are positioned at least partially within the recess \n220\n in the body \n210\n.', 'This may secure the collet \n250\n axially in place within the body \n210\n.', 'The collet \n250\n may be positioned axially-adjacent to the internal assembly \n230\n (e.g., the adapter \n240\n).', 'The collet \n250\n may be in contact with the adapter \n240\n, or the axial gap \n256\n may be present between the collet \n250\n and the adapter \n240\n.', 'When the axial gap \n256\n is present, the internal assembly \n230\n may be configured to move in the upstream direction until the adapter \n240\n contacts the collet \n250\n.', 'The method \n500\n may also include inserting the collet pin \n270\n into the body \n210\n (e.g., into the bore \n216\n), as at \n506\n.', 'This is shown in \nFIG.', '8\n.', 'The collet pin \n270\n may be positioned at least partially within the collet \n250\n.', 'The collet pin \n270\n may be positioned axially-adjacent to the internal assembly \n230\n (e.g., the adapter \n240\n).', 'In at least one embodiment, the collet pin \n270\n may not yet be in contact with the adapter \n240\n (i.e., the axial gap \n256\n may be present between the adapter \n240\n and the collet pin \n270\n).', 'The method \n500\n may also include inserting a collet tool \n280\n at least partially into the body \n210\n (e.g., into the bore \n216\n), as at \n508\n.', 'This is shown in \nFIG.', '9\n.', 'The collet tool \n280\n may include one or more collet-engaging features \n282\n that are configured to engage the tool-engaging features \n258\n on the collet \n250\n.', 'The collet-engaging features \n282\n may be or include a plurality of circumferentially-offset teeth that include alternating peaks and valleys.', 'The method \n500\n may also include engaging the collet \n250\n with the collet tool \n280\n, as at \n510\n.', 'This is also shown in \nFIG.', '9\n.', 'This may include engaging the tool-engaging features \n258\n on the collet \n250\n with the collet-engaging features \n282\n on the collet tool \n280\n.', 'More particularly, the peaks of the collet-engaging features \n282\n of the collet tool \n280\n may be inserted at least partially into the valleys of the tool-engaging features \n258\n of the collet \n250\n.', 'Thus, each peak of the collet tool \n280\n may be positioned circumferentially-between two adjacent peaks of the collet \n250\n.', 'In one embodiment, the collet tool \n280\n may be held substantially stationary to prevent the collet \n250\n from rotating within the body \n210\n.', 'In another embodiment, the collet tool \n280\n may be rotated to rotate the collet \n250\n within the body \n210\n.', 'The method \n500\n may also include inserting a collet pin tool \n290\n at least partially into the body \n210\n (e.g., into the bore \n216\n), as at \n512\n.', 'This is shown in \nFIG.', '10\n.', 'The collet pin tool \n290\n may be inserted into and/or through the collet tool \n280\n.', 'The collet pin tool \n290\n may include one or more collet pin-engaging features \n292\n that is/are configured to engage the tool-engaging feature \n272\n of the collet pin \n270\n.', 'The collet pin-engaging feature \n292\n may be or include an outer surface of the collet pin tool \n290\n that has a substantially-polygonal (e.g., hexagonal) cross-sectional shape.', 'The method \n500\n may also include engaging the collet pin \n270\n with the collet pin tool \n290\n, as at \n514\n.', 'This is also shown in \nFIG.', '10\n.', 'This may include engaging the tool-engaging feature \n272\n of the collet pin \n270\n with the collet pin-engaging feature \n292\n of the collet pin tool \n290\n.', 'More particularly, the polygonal outer surface of the collet pin tool \n290\n may contact the polygonal inner surface of the collet pin \n270\n.', 'The method \n500\n may also include connecting the collet pin \n270\n to the collet \n250\n, as at \n516\n.', 'In one embodiment, this may include rotating the collet pin \n270\n using the collet pin tool \n290\n while the collet \n250\n is substantially prevented from rotating using the collet tool \n280\n.', 'In another embodiment, this may instead include rotating the collet \n250\n using the collet tool \n280\n while the collet pin \n270\n is substantially prevented from rotating using the collet pin tool \n290\n.', 'In yet another embodiment, this may instead include rotating the collet \n250\n and the collet pin \n270\n in opposing directions using the collet tool \n280\n and the collet pin tool \n290\n, respectively.', 'The relative rotation between the collet \n250\n and the collet pin \n270\n may cause the outer threads \n274\n of the collet pin \n270\n to engage the inner threads \n264\n of the collet \n250\n.', 'As mentioned above, the collet \n250\n is secured axially in place within the body \n210\n by the protrusions \n262\n in the recess \n220\n.', 'Thus, as the collet pin \n270\n is threaded to the collet \n250\n, the collet pin \n270\n may move axially within the body \n210\n and/or the collet \n250\n in the downstream direction toward the internal assembly \n230\n (e.g., the adapter \n240\n).', 'The rotation may continue until the collet pin \n270\n contacts the adapter \n240\n, which may prevent further rotation and axial movement of the collet pin \n270\n in the downstream direction.', 'At this point, the collet \n250\n is secured axially in place within the body \n210\n by the protrusions \n262\n in the recess \n220\n, and the collet pin \n270\n is secured axially in place within the body by the threaded engagement with the collet \n250\n.', 'The collet pin \n270\n may exert an axial force on the internal assembly \n230\n (e.g., the adapter \n240\n) in the downstream direction, which may secure the internal assembly \n230\n axially in place between the shoulder \n218\n of the body \n210\n and the collet pin \n270\n.', 'The method \n500\n may also include disengaging the collet pin tool \n290\n from the collet pin \n270\n, as at \n518\n.', 'This may include moving the collet pin tool \n290\n in the upstream direction while the collet pin \n270\n remains axially-stationary, as the collet pin \n270\n and the collet pin tool \n290\n are not axially-connected together.', 'The method \n500\n may also include withdrawing the collet pin tool \n290\n from the body \n210\n, as at \n520\n.', 'The method \n500\n may also include disengaging the collet tool \n280\n from the collet \n250\n, as at \n522\n.', 'This may include moving the collet tool \n280\n in the upstream direction while the collet \n250\n remains axially-stationary, as the collet \n250\n and the collet tool \n280\n are not axially-connected together.', 'The method \n500\n may also include withdrawing the collet tool \n280\n from the body \n210\n, as at \n524\n.', 'At this point, the tool \n100\n is assembled.', 'This is shown in \nFIG.', '2\n, where it may be seen that the internal assembly \n230\n, the collet \n250\n, and the collet pin \n270\n are positioned within the body \n210\n, and the collet tool \n280\n and the collet pin tool \n290\n have been removed.', 'Once assembled, the method \n500\n may also include running the tool \n100\n into the borehole \n11\n, as at \n526\n.', 'The method \n500\n may also include pumping the drilling fluid \n26\n through the tool \n100\n, as at \n528\n.', 'For example, the pump \n29\n may cause the drilling fluid \n26\n to flow down through the drill string \n12\n and into the bore \n216\n of the body \n210\n through the first (e.g., upstream) end \n212\n of the body \n210\n.', 'The drilling fluid \n26\n may flow from the first end \n212\n toward the second end \n214\n.', 'More particularly, the drilling fluid \n26\n may flow through the collet \n250\n and the collet pin \n270\n (which may be at least partially concentric with one another), and through or past the internal assembly \n230\n.', 'As the drilling fluid \n26\n flows through/past the magnets \n236\n in the internal assembly \n230\n, the magnets \n236\n may attract the magnetic debris.', 'This may separate at least a portion of the magnetic debris from the drilling fluid \n26\n, and the magnetic debris may remain collected within the tool \n100\n.', 'As a result, the drilling fluid \n26\n, with the magnetic debris separated therefrom, may be discharged from the tool \n100\n through the second end \n214\n of the body \n210\n, and the drilling fluid \n26\n may then flow into the BHA \n120\n.', 'As mentioned above, the collet \n250\n and the collet pin \n270\n may secure the internal assembly \n230\n in place while still providing the bore \n216\n for another tool (e.g., a fishing tool) to pass therethrough.', 'For example, a fishing tool may be run into the bore hole \n11\n from the surface.', 'The fishing tool may enter the bore \n216\n of the tool \n100\n through the first end \n212\n.', 'The fishing tool may then pass through the collet \n250\n and the collet pin \n270\n.', 'The fishing tool may also pass through the internal assembly \n230\n and the second end \n214\n of the body \n210\n, allowing the fishing tool to reach a component below the tool \n100\n such as the BHA \n120\n or debris in the borehole \n11\n below the drill bit \n122\n.', 'The foregoing description, for purposes of explanation, used specific nomenclature to provide a thorough understanding of the disclosure.', 'However, it will be apparent to one skilled in the art that the specific details are not required in order to practice the systems and methods described herein.', 'The foregoing descriptions of specific examples are presented for purposes of illustration and description.', 'They are not intended to be exhaustive of or to limit this disclosure to the precise forms described.', 'Many modifications and variations are possible in view of the above teachings.', 'The examples are shown and described in order to best explain the principles of this disclosure and practical applications, to thereby enable others skilled in the art to best utilize this disclosure and various examples with various modifications as are suited to the particular use contemplated.', 'It is intended that the scope of this disclosure be defined by the claims and their equivalents below.']

['1.', 'A tool, comprising:\nan internal assembly configured to be positioned at least partially within a body;\na collet configured to be positioned at least partially within the body and axially-adjacent to the internal assembly, wherein the collet comprises a plurality of fingers that are circumferentially-offset from one another, wherein at least one of the fingers comprises a protrusion that extends radially-outward and is configured to be positioned at least partially within a recess formed in an inner surface of the body to secure the collet in place with respect to the body, wherein the fingers are positioned proximate to a first axial end of the collet, wherein the collet further comprises a tool-engaging feature proximate to a second axial end of the collet, wherein the tool-engaging feature is configured to be engaged by a collet tool, and wherein the collet further comprises inner threads on an inner surface thereof; and\na collet pin configured to be positioned at least partially within the body, axially-adjacent to the internal assembly, and at least partially within the collet, wherein the collet pin comprises outer threads on an outer surface thereof that are configured to engage the inner threads of the collet to secure the collet pin in place with respect to the collet, and wherein the collet pin is configured to contact the internal assembly to secure the internal assembly in place within the body.', '2.', 'The tool of claim 1, wherein the tool-engaging feature comprises a plurality of circumferentially-offset teeth that are configured to be engaged by the collet tool to substantially prevent the collet from rotating when the outer threads of the collet pin are engaged with the inner threads of the collet.', '3.', 'The tool of claim 1, wherein an inner surface of the collet pin comprises a tool-engaging feature that is configured to receive a collet pin tool.', '4.', 'The apparatus of claim 3, wherein the tool-engaging feature is substantially hexagonal.', '5.', 'A collecting tool, comprising:\na substantially tubular body defining an axial bore, wherein the bore is configured to have a drilling fluid flow therethrough;\nan internal assembly configured to be positioned at least partially within the bore, wherein the internal assembly comprises a magnet holder and a plurality of magnets positioned at least partially within the magnet holder, wherein the magnets are configured to attract magnetic debris in the drilling fluid;\na collet configured to be positioned at least partially within the bore and axially-adjacent to the internal assembly, wherein the collet comprises a plurality of fingers that are circumferentially-offset from one another, wherein at least one of the fingers comprises a protrusion that extends radially-outward and is configured to be positioned at least partially within a recess formed in an inner surface of the body to secure the collet in place with respect to the body, and wherein the collet further comprises inner threads on an inner surface thereof; and\na collet pin configured to be positioned at least partially within the bore, axially-adjacent to the internal assembly, and at least partially within the collet, wherein the collet pin comprises outer threads on an outer surface thereof that are configured to engage the inner threads of the collet to secure the collet pin in place with respect to the collet, and wherein the collet pin is configured to contact the internal assembly to secure the internal assembly in place within the body,\nwherein the collecting tool is configured to receive the drilling fluid from a drill string and to discharge the drilling fluid to a bottom hole assembly,\nwherein the collet and the collet pin are at least partially concentric with one another and positioned upstream from the internal assembly in the bore, and\nwherein the fingers are positioned proximate to a first axial end of the collet, wherein the collet further comprises a plurality of circumferentially-offset teeth proximate to a second axial end of the collet, and wherein the teeth are configured to be engaged by a collet tool to substantially prevent the collet from rotating when the outer threads of the collet pin are engaged with the inner threads of the collet.', '6.', 'The collecting tool of claim 5, wherein an inner surface of the collet pin is configured to receive a collet pin tool, wherein the collet pin tool is configured to rotate the collet pin while the collet tool substantially prevents the collet from rotating to screw the outer threads and the inner threads together, wherein the collet moves toward and contacts the internal assembly as the outer threads and the inner threads are screwed together, and wherein the contact between the collet pin and the internal assembly secures the internal assembly in place within the bore.', '7.', 'The tool of claim 5, wherein an inner surface of the collet pin comprises a tool-engaging feature that is configured to receive a collet pin tool.', '8.', 'The apparatus of claim 7, wherein the tool-engaging feature is substantially hexagonal.', '9.', 'A method, comprising:\ninserting an internal assembly into a body of a tool;\ninserting a collet into the body, wherein the collet is positioned axially-adjacent to the internal assembly, and wherein a protrusion on the collet is positioned at least partially within a recess in an inner surface of the body to secure the collet in place within the body;\ninserting a collet pin into the body, wherein the collet pin is positioned axially-adjacent to the internal assembly and at least partially within the collet;\ninserting a collet tool at least partially into the body;\nengaging the collet with the collet tool;\ninserting a collet pin tool at least partially into the body, wherein inserting the collet pin tool at least partially into the body comprises inserting the collet pin tool through the collet tool;\nengaging the collet pin with the collet pin tool; and\nconnecting the collet pin to the collet, using the collet tool and the collet pin tool, to secure the collet pin in place within the body.', '10.', 'The method of claim 9, wherein connecting the collet pin to the collet comprises engaging inner threads on an inner surface of the collet with outer threads on an outer surface of the collet pin.', '11.', 'The method of claim 10, wherein connecting the collet pin to the collet comprises rotating the collet pin using the collet pin tool while substantially preventing the collet from rotating using the collet tool.\n\n\n\n\n\n\n12.', 'The method of claim 11, wherein rotating the collet pin causes the collet pin to move axially-toward and contact the internal assembly.', '13.', 'The method of claim 12, wherein the collet pin contacting the internal assembly secures the internal assembly in place between the collet pin and an internal shoulder of the body.', '14.', 'The method of claim 9, wherein engaging the collet with the collet tool comprises engaging a plurality of circumferentially-offset teeth on an axial end of the collet with the collet tool, and wherein the method further comprises:\ndisengaging the collet tool from the collet after the collet pin is connected to the collet; and\nwithdrawing the collet tool from the body.\n\n\n\n\n\n\n15.', 'The method of claim 14, wherein engaging the collet pin with the collet pin tool comprises engaging a polygonal inner surface of the collet pin with a polygonal outer surface of the collet pin tool, and wherein the method further comprises:\ndisengaging the collet pin tool from the collet pin; and\nwithdrawing the collet pin tool from the body.\n\n\n\n\n\n\n16.', 'The method of claim 9, wherein the internal assembly comprises a magnet holder and a plurality of magnets, and wherein the method further comprises:\nrunning the tool into a borehole, while the body has the internal assembly, the collet, and the collet pin positioned therein; and\npumping a drilling fluid through the body while the body is positioned within the borehole, wherein the magnets are configured to attract magnetic debris in the drilling fluid to prevent the magnetic debris from flowing into a bottom hole assembly that is connected to and positioned downstream from the body.', '17.', 'The method of claim 16, further comprising running a fishing tool into the borehole, through the body, the internal assembly, the collet, and the collet pin to reach a component positioned below the tool.']

['FIG. 1 illustrates a schematic view of an example of a drilling system, according to an embodiment.; FIG.', '2 illustrates a cross-sectional side view of an example of a tool in the drilling system, according to an embodiment.; FIG.', '3 illustrates an enlarged cross-sectional side view of a portion of FIG.', '2, according to an embodiment.', '; FIG.', '4 illustrates a perspective view of a collet and a collet pin of the tool, according to an embodiment.; FIG.', '5 illustrates a flowchart of a method for assembling the tool and/or using the tool, according to an embodiment.; FIG.', '6 illustrates a cross-sectional side view of an internal assembly positioned within a body of the tool, according to an embodiment.; FIG.', '7 illustrates a cross-sectional side view of the collet positioned within the body and axially-adjacent to the internal assembly, according to an embodiment.; FIG.', '8 illustrates a cross-sectional side view of the collet pin positioned within the body and at least partially within the collet, according to an embodiment.; FIG.', '9 illustrates a cross-sectional side view of a collet tool inserted into the body and engaging the collet, according to an embodiment.; FIG.', '10 illustrates a cross-sectional side view of a collet pin tool inserted into the body and engaging the collet pin, according to an embodiment.; FIG.', '1 illustrates a schematic view of an example of a drilling system 110, according to an embodiment.', 'The drilling system 110 may be provided at a wellsite which may be an onshore or offshore wellsite, and the drilling system 110 may include any combination of the various elements described herein.; FIG. 2 illustrates a cross-sectional side view of an example of the tool 100, according to an embodiment.', 'The tool 100 may include a body 210 having a first (e.g., upstream) end 212 and a second (e.g., downstream) end 214.', 'The first end 212 may be connected to a segment 125 of the drill string 12.', 'The second end 214 may be connected to the BHA 120 or to a segment 125 of the drill string 12 that is positioned between the tool 100 and the BHA 120.', 'The body 210 may define an axial bore 216 that extends from the first end 212 to the second end 214.; FIG.', '3 illustrates an enlarged portion of FIG.', '2, according to an embodiment.', 'Referring to FIGS.', '2 and 3, a collet 250 may also be positioned at least partially within the body 210 (e.g., within the bore 216).', 'The collet 250 may be or include an annular member that includes a first (e.g., upstream) end 252 and a second (e.g., downstream) end 254.', 'The second end 254 may be positioned axially-adjacent to the internal assembly 230 (e.g., the adapter 240).', 'As shown, an axial gap 256 may be present between the second end 254 of the collet 250 and the adapter 240.', 'In another embodiment, the second end 254 may contact the adapter 240.', 'In yet another embodiment, the adapter 240 may be omitted, and the second end 254 may contact the magnet holder 234 or the sleeve 238 directly.; FIG.', '4 illustrates a perspective view of a portion of FIG.', '3, according to an embodiment.', 'Referring to FIGS.', '3 and 4, the first end 252 of the collet 250 may include one or more tool-engaging features 258.', 'The tool-engaging features 258 may be or include a plurality of circumferentially-offset teeth that include alternating peaks and valleys.', 'The second end 254 of the collet 250 may include a plurality of circumferentially-offset fingers 260.', 'One or more of the fingers 260 may include a protrusion 262 that extends radially-outward therefrom.', 'As described in greater detail below, as the collet 250 is being inserted into the body 210, the contact between the protrusions 262 and the inner surface of the body 210 may cause the fingers 260 to flex radially-inward.', 'The inner surface of the body 210 may define a recess 220 that is configured to receive the protrusions 262.', 'When the protrusions 262 reach the recess 220, the fingers 260 may flex radially-outward, allowing the protrusions 262 to be positioned at least partially within the recess 220.', 'This may secure the collet 250 axially in place within the body 210.; FIG.', '5 illustrates a flowchart of a method 500 for assembling and/or using the tool 100, according to an embodiment.', 'For example, the method 500 may be used to secure the internal assembly 230 in the body 210.', 'An illustrative order of the method 500 is provided below; however, as will be appreciated, one or more portions of the method 500 may be performed in a different order or omitted.']

US11835371

Multiphase flowmeter aperture antenna transmission and pressure retention

May 27, 2021

Yu Ke Lim, Shasha Wang, Linyuan Zhan, Muhammad Fuad Bin Mohamed Zain, Kenny Shin Han Wei, Guillaume Jolivet, Cheng-Gang Xie

Schlumberger Technology Corporation

Sensia, Caldon Ultrasonics LEFM 2xxCi Family of Ultrasonic Flowmeters with G3 Transmitters, User Manual Safety Manual, Aug. 2021.; Balanis, C. A., Antenna theory: analysis and design, Fourth ed., Hoboken, New Jersey, John Wiley, 2016, Chapter 12, p. 683, 9 pages.; Pozar, D. M., Microwave engineering, 3rd ed. (no. Book, Whole). Hoboken, NJ: John Wiley, 2004, Chapter 3, p. 129, 81 pages.; Collin, R. E., Field Theory of Guided Waves, 2nd; ed. John Wiley Sons, 1990, Chapter 7, pp. 471-483, 86 pages.

3886549; May 1975; Cheal; 5006785; April 9, 1991; Revus; 5793216; August 11, 1998; Constant; 7908930; March 22, 2011; Xie; 8536883; September 17, 2013; Xie; 20080319685; December 25, 2008; Xie; 20170016750; January 19, 2017; Edward; 20190145910; May 16, 2019; Alvarez; 20190301280; October 3, 2019; Xiao et al.

Foreign Citations not found.

['Multiphase flowmeter aperture antenna transmission and pressure retention are disclosed herein.', 'An example apparatus includes at least one radiating element to transmit or receive an electromagnetic signal along a measurement plane orthogonal to a direction of flow of the fluid in the vessel; a pressure retaining member to prevent fluid from entering the aperture antenna assembly through a measurement window of the aperture antenna assembly, at least a portion of the pressure retaining member to separate the radiating element and the fluid; and a metal housing with or without slits, the pressure retaining member to be at least partially within the metal housing, the radiating element to be coupled to the metal housing.']

['Description\n\n\n\n\n\n\nThis application claims priority to and the benefit of a U.S. Provisional Application having Application No. 62/704,805, filed 29 May 2020, which is incorporated by reference herein.', 'BACKGROUND\n \nThis disclosure relates generally to flowmeters and, more particularly, to multiphase flowmeter aperture antenna transmission and pressure retention.', 'DESCRIPTION OF THE RELATED ART\n \nHydrocarbons are widely used as a primary source of energy and have a great impact on the world economy.', 'Consequently, the discovery and efficient production of hydrocarbon resources is increasingly noteworthy.', 'As relatively accessible hydrocarbon deposits are depleted, hydrocarbon prospecting and production has expanded to new regions that may be more difficult to reach and/or may pose new technological challenges.', 'During typical operations, a borehole is drilled into the earth, whether on land or below the sea, to reach a reservoir containing hydrocarbons.', 'Such hydrocarbons are typically in the form of oil, gas, water, or mixtures thereof that may be brought to the surface through the borehole.', 'Well testing or production monitoring is often performed to evaluate a potential or current production value of a reservoir.', 'During well testing, a test well is drilled to produce a test flow of fluid from the reservoir.', 'During the test flow, flow rates of oil, gas and water, and the parameters of the mixture, such as a water-liquid ratio and a liquid-gas ratio, are typically measured along a portion of the borehole over time to indicate the well production and the contents of the mixture.', 'The flow rates and the mixture parameters may be determined during various types of well tests, such as pressure drawdown, interference, reservoir limit tests, and other tests generally known by those skilled in the art.', 'The data collected during well testing may be used to characterize physical properties of the reservoir and assess the economic viability of the reservoir.', 'The costs associated with performing the testing operations may be substantial.', 'Therefore, testing operations should be performed as efficiently and economically as possible.', 'The same is true for permanent production monitoring operations to evaluate the production flow rates of oil and/or gas wells of a reservoir.', 'SUMMARY\n \nCertain aspects of some embodiments disclosed herein are set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of certain forms the invention might take and that these aspects are not intended to limit the scope of the invention.', 'Indeed, the invention may encompass a variety of aspects that may not be set forth below.', 'An example aperture antenna assembly of a multiphase flowmeter disclosed herein includes at least one radiating element to transmit or receive an electromagnetic signal along at least one measurement plane orthogonal to a direction of flow of the fluid in the vessel, a pressure retaining member to prevent the fluid from entering the aperture antenna assembly through a measurement window of the aperture antenna assembly, at least a portion of the pressure retaining member to separate the radiating element and the fluid, and a metal housing (with or without slits), the pressure retaining member to be at least partially within the metal housing, the radiating element to be coupled to the metal housing.', 'A multiphase flowmeter with a plurality of example aperture antenna assemblies to measure properties of a fluid in a vessel disclosed herein, including a first aperture antenna assembly according to the disclosure, wherein the at least one radiating element of the first aperture antenna is at least one first radiating element, a second aperture antenna assembly according to the disclosure, wherein the at least one radiating element of the second aperture antenna is at least one second radiating element, wherein the first aperture antenna assembly is coupled to a first side of the vessel and the second aperture antenna assembly is coupled to a second side of the vessel, wherein the at least one second radiating element includes one or more radiating elements respectively having one or more angular displacements with respect to the first radiating element, wherein the at least one first radiating element is configured to transmit an electromagnetic signal through the fluid, the at least one second radiating element is configured to receive the electromagnetic signal, and the at least one first radiating element is configured to receive at least a portion of the electromagnetic signal reflected by the fluid in the vessel.', 'An example pressure vessel apparatus of a multiphase flowmeter disclosed herein includes a pressure retaining measurement window having an outer face and a shoulder, the outer face flushed with an interior wall of a vessel, the outer face to be in fluid communication with a fluid included in the vessel, a seal to radially surround the shoulder of the pressure retaining measurement window, wherein the shoulder is substantially orthogonal to the outer face, an elastic member to provide a resistance force to the pressure retaining measurement window to counteract a fluid pressure within the vessel, a metal housing coupled between the pressure retaining measurement window and the elastic member, and a retaining member coupled to a side of the elastic member opposite the metal housing, the retaining member to maintain a relative position of the elastic member.', 'An example method disclosed herein includes transmitting an electromagnetic signal from a first radiating element on a first side of the pressure vessel into the pressure vessel based on a plurality of frequencies, receiving the electromagnetic signal at a second antenna radiating element at a second side of the pressure vessel, receiving a reflection of the electromagnetic signal at the first radiating element, determining first electromagnetic data based on receiving the reflection of the electromagnetic signal at the first radiating element, determining second electromagnetic data based on the second radiating element receiving the electromagnetic signal, and determining the properties of the multi-phase fluid based on at least one of the first electromagnetic data or the second electromagnetic data.', 'Various refinements of the features noted above may exist in relation to various aspects of the present embodiments.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'Again, the brief summary presented above is intended just to familiarize the reader with certain aspects and contexts of some embodiments without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n illustrates an example multiphase flowmeter with a first example aperture antenna assembly with a first example pressure vessel apparatus coupled to an example vessel, and an example flowmeter controller.\n \nFIG.', '2\n illustrates another view of the first example aperture antenna assembly of \nFIG.', '1\n and the first example pressure vessel apparatus of the example multiphase flowmeter of \nFIG.', '1\n.', 'FIG.', '3\n illustrates an example cross-section of a simplified representation of the first example aperture antenna assembly of \nFIGS.', '1\n and/or \n2\n.\n \nFIG.', '4\nA\n illustrates a first example metal housing with cross-cut slits of the aperture antenna assembly of \nFIGS.', '1\n, \n2\n, and/or \n3\n.', 'FIG.', '4\nB\n illustrates a second example metal housing without slits of the aperture antenna assembly of \nFIGS.', '1\n, \n2\n, and/or \n3\n.', 'FIG.', '5\n illustrates an example midsection of the second example metal housing with cross-cut slits of \nFIG.', '4\nA\n.\n \nFIG.', '6\n illustrates a simplified cross-section of an example pressure vessel apparatus of the aperture antenna assembly of \nFIGS.', '1\n and/or \n2\n.\n \nFIG.', '7\n illustrates a second example pressure vessel apparatus of the aperture antenna assembly implemented on the edge of a vessel of \nFIGS.', '1\n and/or \n2\n.', 'FIGS.', '8\nA-\n8\nD\n illustrate an example process to preload an example pressure vessel apparatus.\n \nFIG.', '9\n illustrates an example pressure retaining measurement window that may be included in the example aperture antenna assembly of \nFIGS.', '1\n, \n2\n, and/or \n3\n and the example pressure vessel apparatus of \nFIGS.', '1\n, \n2\n, \n6\n, \n7\n, and/or \n8\n.', 'FIG.', '10\n is a block diagram of an example implementation of an aperture antenna assembly on the example vessel of \nFIGS.', '1\n and/or \n2\n.\n \nFIG.', '11\n is a block diagram of an example flowmeter controller associated with the example aperture antenna assembly of \nFIGS.', '1\n and/or \n2\n.\n \nFIG.', '12\n is a flowchart representative of example machine-readable instructions that may be executed to implement the flowmeter controller of \nFIGS.', '1\n, \n2\n, and/or \n11\n to determine physical properties of a multiphase fluid in the example vessel of \nFIGS.', '1\n and/or \n2\n.\n \nFIG.', '13\n is a block diagram of an example processing platform structured to execute the example machine-readable instructions of \nFIG.', '12\n to implement the flowmeter controller of \nFIGS.', '1\n, \n2\n, and/or \n11\n.', 'DETAILED DESCRIPTION', 'It is to be understood that the present disclosure provides many different embodiments, or examples, for implementing different features of various embodiments.', 'Specific examples of components and arrangements are described below for purposes of explanation and to simplify the present disclosure.', 'These are, of course, merely examples and are not intended to be limiting.', 'When introducing elements of various embodiments, the articles “a,” “an,” “the,” and “said” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Moreover, any use of “top,” “bottom,” “above,” “below,” other directional terms, and variations of these terms is made for convenience, but does not mandate any particular orientation of the components.', 'The figures are not to scale.', 'In general, the same reference numbers will be used throughout the drawing(s) and accompanying written description to refer to the same or like parts.', 'Connection references (e.g., attached, coupled, connected, and joined) are to be construed broadly and may include intermediate members between a collection of elements and relative movement between elements unless otherwise indicated.', 'As such, connection references do not necessarily infer that two elements are directly connected and in fixed relation to each other.', 'Stating that any part is in “contact” with another part means that there is no intermediate part between the two parts.', 'Although the figures show layers and regions with clean lines and boundaries, some or all of these lines and/or boundaries may be idealized.', 'In reality, the boundaries and/or lines may be unobservable, blended, and/or irregular.', 'Unless specifically stated otherwise, descriptors such as “first,” “second,” “third,” etc. are used herein without imputing or otherwise indicating any meaning of priority, physical order, arrangement in a list, and/or ordering in any way, but are merely used as labels and/or arbitrary names to distinguish elements for ease of understanding the disclosed examples.', 'In some examples, the descriptor “first” may be used to refer to an element in the detailed description, while the same element may be referred to in a claim with a different descriptor such as “second” or “third.”', 'In such instances, it should be understood that such descriptors are used merely for identifying those elements distinctly that might, for example, otherwise share a same name.', 'As used herein, “approximately” and “about” refer to dimensions that may not be exact due to manufacturing tolerances and/or other real world imperfections.', 'Well testing or production monitoring is often performed to acquire data related to hydrocarbon properties of a well and identify or measure capabilities of the well to produce such hydrocarbons.', 'During well testing, a test well is drilled to produce a test flow of fluid from an underground reservoir.', 'During the test flow, parameters such as fluid pressure and fluid flow rate may be monitored over a period of time.', 'The data collected during well testing, or during production monitoring for an existing well, may be used to assess the extraction of hydrocarbons from the reservoir and, thus, the economic viability and/or the current production value of the reservoir.', 'Due to the substantial costs associated with performing well testing or production monitoring, testing or production monitoring operations should be performed as efficiently and economically as possible.', 'To efficiently and economically perform such well testing or production monitoring operations, some characteristics of the fluid(s) being produced may be determined such as, for example, the flow rate of the fluid.', 'In some instances, the fluid(s) produced from a test well or a production well are multiphase fluids including water, oil, and/or gas.', 'Determining the flow rate of a multiphase fluid may be more complex than determining the flow rate of a single-phase fluid.', 'In some instances, a vessel is implemented to transport the fluid(s) from the underground reservoir to a storage container at the surface.', 'In some instances, a multiphase flowmeter implements a Venturi device along a portion of the vessel to allow flow of the fluid(s) to be analyzed.', 'Some multiphase flowmeters have different Venturi throat sizes to facilitate different liquid and gas production flow rates.', 'Venturi throat inner diameter sizes may vary, where larger Venturi throat sizes may be used for higher-rate oil/gas wells and smaller Venturi throat sizes may be used for lower-rate oil/gas wells.', 'In some instances, a multiphase flowmeter is a gamma densitometer that utilizes gamma rays to determine parameters associated with the fluid in the vessel.', 'In some instances, the gamma densitometer uses fluid and/or flow sensor(s) including a radioactive source of gamma rays, a gamma ray transmitter, a gamma ray detector, and a flow computer.', 'The radioactive source of the gamma rays requires radioactivity safety measures to be implemented to meet regulatory requirements for safe handling, transportation, and operation.', 'Additionally, known pressure retaining systems of such gamma-ray based multiphase flowmeter may utilize a bolt-flange assembly for the gamma-ray measurement windows to create a preload proportional to a fluid pressure in the vessel and prevent a displacement of the pressure retaining components.', 'However, the preload is typically increased by increasing the size of the bolts, increasing the strength of the bolts, and/or increasing the number of bolts, which further increases the size of the multiphase flowmeter and associated costs.', 'Examples disclosed herein include a multiphase flowmeter including an aperture antenna assembly to transmit and receive electromagnetic signals (e.g., radio frequency (RF) waves) that are used to determine parameters of the fluid within the vessel.', 'In some disclosed examples, the aperture antenna assembly includes at least one radiating element to transmit and/or receive electromagnetic signals, a pressure vessel apparatus to prevent the fluid of the vessel from entering the aperture antenna without altering the flow, and a metal housing (e.g., a metal cavity housing) with or without slits.', 'In some disclosed examples, the slits of the metal housing are parallel and/or perpendicular slits relative to the displacement of the radiating element that improve the signal level transmitted by the radiating element.', 'As used herein, the term “pressure vessel apparatus” refers to a seal between the vessel and the aperture antenna that can also be operative as a measurement window through which electromagnetic signals propagate.', 'In some disclosed examples, the aperture antenna assembly is positioned along a portion of the vessel at a throat section of a Venturi device to allow flow of the fluid(s) to be analyzed.', 'Examples disclosed herein include aperture antenna assemblies that produce low-power (e.g., 30 dBm or 1 Watt), RF electromagnetic signals to accurately measure parameters of a fluid within a vessel that, in some disclosed examples, has a relatively larger throat diameter.', 'Examples disclosed herein remove the need for a gamma ray source and/or radioactivity safety measures to be implemented to meet regulatory requirements for safe handling, transportation, and operation.', 'Examples disclosed herein include aperture antenna assemblies with improved pressure retention, via a pressure vessel apparatus, that prevents fluid from entering an aperture antenna of the aperture antenna assemblies without affecting flow within the vessel.', 'Advantageously, examples disclosed herein can include aperture antenna assemblies having removable components to facilitate convenient testing, field repairs, and/or replacement of parts.', 'In some disclosed examples, the pressure vessel apparatus can be tested prior to coupling electronic components to the vessel to reduce and/or otherwise eliminate the risk of damaging the electronic components.', 'In some disclosed examples, the aperture antenna assembly includes a first radiating element and a second radiating element positioned around the periphery of the vessel.', 'For example, the first radiating element can transmit an electromagnetic signal into the vessel and the second radiating element can receive a transmission signal.', 'The first radiating element can receive a reflection signal subsequent to the transmitted signal being reflected by the fluid in the vessel.', 'As used herein, the term “radiating element” refers to an electrical component that can transmit and/or receive electromagnetic signals.', 'For example, a radiating element can be a magnetic dipole with a conductor wire aligned in the flow direction, or with a conductor wire aligned perpendicular to the flow direction, arranged across the middle of a circular or non-circular (e.g. rectangular, square, triangular) antenna aperture.', 'Additionally, a radiating element can be an electric dipole (e.g. a coaxial conductor, a patch antenna, etc.).', 'In some disclosed examples, the radiating element is made of a beryllium copper, bronze, and/or brass conductor, with or without gold plating.', 'In some disclosed examples, the radiating element includes one or more radiating elements disposed across the throat of section of the pressure vessel on a first measurement plane and/or a second measurement plane with one or more angular displacements.', 'As used herein, the term “transmission signal” refers to an electromagnetic radio-frequency signal that is to be transmitted from one radiating element to a different radiating element (e.g., a different radiating element across the vessel).', 'As used herein, the term “reflection signal” refers to an electromagnetic signal that is to be transmitted from a radiating element that can be received by the same radiating element after the signal has been reflected by a fluid in the vessel.', 'In some disclosed examples, a plurality of the radiating elements transmit (e.g., at least a transmitting antenna, a transmitter, etc.) and receive (e.g., at least a receiving antenna, a receiver, etc.)', 'electromagnetic signals along a first measurement plane that is orthogonal to the direction of flow in the vessel.', 'In some disclosed examples, the vessel includes a plurality of measurement planes.', 'In some disclosed examples, a plurality of radiating elements is positioned around the periphery of the vessel.', 'In some such disclosed examples, the radiating elements that receive the transmission signal (e.g., receiving antennae, receivers, etc.) are positioned with more than one angular displacement (e.g., 60°, 90°, 120°, 180°, etc.) with respect to the radiating element that transmits the electromagnetic signal.', 'In some disclosed examples, a first radiating element (e.g., the transmitting antennae) disposed on the first measurement plane transmits the electromagnetic signals and a second radiating element(s) (e.g., the receiving antennae) disposed on the first measurement plane and/or a second measurement plane receives the electromagnetic signals.', 'In general, the transmitting antennae can be disposed on the first measurement plane and/or the second measurement plane to transmit the electromagnetic signals to the receiving antennae positioned on a same measurement plane as the transmitting antennae or a different measurement plane.', 'In some disclosed examples, magnitude and phase data is generated based on the transmission signals and/or reflection signals received by the radiating element(s) and communicated to a flowmeter controller.', 'In some disclosed examples, the aperture antenna assembly measures a phase fraction (e.g., liquid or gas fraction), a water-liquid ratio (WLR), a salinity, a conductivity, and/or a permittivity based on magnitude and phase data of the electromagnetic signals.', 'Typically, measurements of the multiphase fluid are utilized to determine if the production system will produce, or continue to produce, hydrocarbons at an economically viable rate.', 'Advantageously, in some disclosed examples, online continuous measurements of the multiphase fluid by the aperture antenna assembly and the differential pressure venturi device characterize physical properties of the reservoir and assess the economic viability of the reservoir.', 'In some disclosed examples, the aperture antenna assembly measurements can provide flow assurance and detect potential issues in the reservoir and/or production system.', 'In some disclosed examples, a choke valve is adjusted based on the measurements of the aperture antenna assembly and the venturi device to precisely control the flow rate.', 'In some disclosed examples, a pressure vessel apparatus (e.g., a pressure retaining member) meshes with an interior surface of the vessel and protects the radiating element from ingress of fluid within the vessel.', 'The pressure vessel apparatus can include fewer and/or smaller components than a conventional bolt-flange assembly and, thus, reduces costs and a size of the aperture antenna assembly.', 'In some disclosed examples, the pressure vessel apparatus includes a plug (e.g., a pressure retaining measurement window (PRMW)) that is flush (e.g., mesh) with an interior surface of the vessel that contains hydrocarbons.', 'As used herein in the context of describing the surface and/or shape of a first object relative to a second object, the terms “flush” and “mesh” encompass a surface of the first object including geometry and/or curvature that substantially matches (e.g., substantially matches within a tolerance range of 0-1%) a surface of the second object.', 'In some disclosed examples, a seal radially surrounds the pressure retaining measurement window.', 'In some disclosed examples, the pressure retaining measurement window and additional components of the pressure vessel apparatus are preloaded to withstand a pressure exerted on the pressure retaining measurement window by the fluid within the vessel.', 'In some such disclosed examples, additional components of the pressure vessel include an elastic member (e.g., a spring, a washer, etc.), a retaining member (e.g., a retaining ring, a screw, etc.), and/or a spacer (e.g., a metal housing) to support the pressure retaining measurement window against the pressure exerted by the fluid.', 'In some disclosed examples, the pressure vessel is preloaded by a bolt that is screwed and/or otherwise operatively coupled to the metal housing to compress the elastic member.', 'In some such disclosed examples, the bolt is removed subsequent to applying the preload and, thus, can be used to preload more than one pressure vessel apparatus.', 'In some such disclosed examples, removing the bolt subsequent to applying the preload further reduces the size of the pressure vessel apparatus, in addition to reducing passive electromagnetic interference or cross-talk, compared to the bolt-flange assembly.', 'In some disclosed examples, a metal housing is coupled to an exterior surface of the vessel to secure and protect the radiating element of the aperture antenna assembly and the pressure vessel apparatus, while also maintaining the stability and quality of the electromagnetic signal by electrically shielding the electromagnetic signal from background electromagnetic interference.', 'In some disclosed examples, the metal housing, with advantageous electrical shielding, can include sets of appropriately cut (e.g., cut substantially parallel to the radiating element and/or cut substantially perpendicular to the radiating element) slits (e.g., gaps, openings, etc.) that enhance a field propagation of the electromagnetic signal through the fluids via constructive electromagnetic field interference inside a cavity of the metal housing.', 'In some disclosed examples, sections of the metal housing are separated by slits.', 'In some disclosed examples, a section (e.g., a middle section) of the metal housing is positioned between a set of slits (e.g., 2 or more slits) and is coupled to one end of the radiating element.', 'In some disclosed examples, the middle section can be uncoupled from other sections of the metal housing and, thus, is removable to assist with repairs and replacements of components, such as the radiating element with a flange-mount RF coaxial connector with coaxial feedthrough.', 'FIG.', '1\n illustrates an example multiphase flowmeter \n100\n with a first example aperture antenna assembly \n102\n coupled to an example throat section \n107\n of an example vessel \n105\n.', 'The example aperture antenna assembly \n102\n includes a first example pressure vessel apparatus \n103\n located at the venturi throat section \n107\n of the vessel \n105\n described in further detail in connection with \nFIG.', '2\n.', 'The aperture antenna assembly \n102\n includes an example flowmeter controller \n104\n including example microwave sensor electronics \n106\n, an example flowmeter transmitter \n108\n, example electrical RF coaxial cables (e.g., RF coaxial cables and associated RF coaxial connectors) \n110\n with RF coaxial connectors, an example network \n112\n, an example computing device(s) \n114\n, and an example process control system \n116\n.', 'In \nFIG. \n1\n, radiating elements of the aperture antenna assembly \n102\n transmit and receive electromagnetic signals (e.g., radio frequency waves) across the throat section \n107\n of the vessel \n105\n as a multiphase fluid from a reservoir flows through the vessel \n105\n.', 'In some examples, a first radiating element transmits the electromagnetic signal through the throat section \n107\n of the vessel \n105\n and receives a reflection signal after the fluid in the vessel reflects the signal.', 'Additionally, a second radiating element receives a transmission signal after the electromagnetic signal travels through the multiphase fluid across the throat section \n107\n of the vessel \n105\n, described in further detail in connection with \nFIG. \n2\n.', 'In \nFIG.', '1\n, example microwave sensor electronics \n106\n can generate and/or receive electromagnetic signals.', 'In some examples, the microwave sensor electronics \n106\n are mounted on the vessel \n105\n and coupled to the radiating elements via the electrical RF coaxial cables \n110\n.', 'The electrical RF coaxial cables \n110\n transport the electromagnetic signals from one component (e.g., a signal generator, a signal receiver, etc.) of the aperture antenna assembly \n102\n to another component (e.g., a signal transmitter, a signal analyzer, etc.).', 'The electrical RF coaxial cables \n110\n are coupled to the flowmeter controller \n104\n and the radiating elements of the aperture antenna assembly \n102\n.', 'The electrical RF coaxial cables \n110\n can forward the electromagnetic signals to be transmitted from the flowmeter controller \n104\n to the radiating elements and/or can provide the electromagnetic signal received by the radiating elements to the flowmeter controller \n104\n.', 'In some examples, the electrical RF coaxial cables \n110\n carry the electromagnetic signals from the microwave sensor electronics \n106\n of the flowmeter controller \n104\n to the radiating elements and/or vice versa.', 'In some examples, the microwave sensor electronics \n106\n measure magnitude (e.g., amplitude-attenuation) and phase-shift data of the electromagnetic signals at least one radio frequency from one or more radiating elements.', 'In some such examples, the microwave sensor electronics \n106\n can determine flow parameters such as a water-liquid ratio (WLR) and/or a gas holdup (GHU) value based on the amplitude-attenuation and the phase-shift of the electromagnetic signals.', 'In \nFIG.', '1\n, the flowmeter controller \n104\n delivers and/or otherwise transmits the electromagnetic signals to the flowmeter transmitter \n108\n.', 'In some disclosed examples, the flowmeter transmitter \n108\n utilizes flow parameters, data, etc., of the electromagnetic signals and pressure, temperature and Venturi differential-pressure signals upstream or downstream of the throat section \n107\n, to determine measurements of the flow within the vessel \n105\n.', 'For example, the flowmeter transmitter \n108\n can receive flow parameters such as the WLR and/or GHU from the microwave sensor electronics \n106\n, and flow pressure, temperature, and/or Venturi differential pressure of the multiphase fluid from a pressure sensor, a temperature sensor, and/or a differential pressure sensor (not shown).', 'In the illustrated example of \nFIG. \n1\n, the network \n112\n enables the flowmeter controller \n104\n to transmit the measurements of the microwave sensor electronics \n106\n and/or the flowmeter transmitter \n108\n to the computing device(s) \n114\n and/or the process control system \n116\n.', 'The network \n112\n of the illustrated example of \nFIG.', '1\n is the Internet.', 'However, the network \n112\n can be implemented using any suitable wired and/or wireless network(s) including, for example, one or more data buses, one or more Local Area Networks (LANs), one or more wireless LANs, one or more cellular networks, one or more private networks, one or more public networks, etc.', 'In some examples, the network \n112\n is a communication network channel, or a channel of a network.', 'In some examples, the computing device(s) \n114\n are representative of one or more computing devices that include programs (e.g., machine readable instructions representative of algorithms, functions, equations, etc.) to analyze the measurements from the flowmeter controller \n104\n and further determine flow properties of the multiphase fluid in the vessel \n105\n.', 'For example, the computing device(s) \n114\n can determine an oil flow rate, a gas flow rate, a water flow rate, a salinity, a permittivity, and/or a conductivity of the multiphase fluid.', 'In \nFIG.', '1\n, the computing device(s) \n114\n and/or the flowmeter controller \n104\n can communicate the flow properties to the process control system \n116\n via the network \n112\n.', 'In some examples, the process control system \n116\n determines an adjustment to flow parameters of the multiphase fluid.', 'For example, the process control system \n116\n can adjust a choke valve at the surface to control the flow rate and/or gas volume fraction within the vessel \n105\n based on the measured flow properties.', 'In some examples, the process control system \n116\n can adjust a reservoir water-injection strategy to enhance oil recovery based on the measured flow parameters (e.g., changes in water salinity, changes in WLR) of the multiphase fluid of one or more production wells monitored by flowmeter(s).', 'In some examples, the process control system \n116\n can optimize the production of a well implemented with an artificial lift system and monitored by a flowmeter, by reducing the gas volume fraction experienced by a downhole electric submersible pump, by adjusting the pump operating speed, and/or adjusting the opening of a gas-lift valve.', 'In some examples, the process control system \n116\n may help shut or abandon the well if the well WLR is excessively high and, thus the well has no economic value to continue the production.\n \nFIG.', '2\n illustrates another view of the first aperture antenna assembly \n102\n of \nFIG.', '1\n and the first pressure vessel apparatus \n103\n of the multiphase flowmeter \n100\n positioned at the throat section \n107\n of the vessel \n105\n of \nFIG.', '1\n.', 'The aperture antenna assembly \n102\n includes an example ingress protection cover \n217\n and example RF cable glands \n216\n to radially surround and secure the electrical RF coaxial cables (e.g., RF coaxial cables with SubMiniature Version A (SMA) ‘male’ connectors)', '110\n as they couple to example SMA connectors (e.g., RF SMA ‘female’ connectors)', '228\n.', 'Each SMA connector \n228\n is removably coupled to an example metal housing (e.g., a metal cavity housing) \n205\n, which is surrounded by an example electrical conductor shield \n208\n.', 'In some examples, the metal housing \n205\n acts as the electrical conductor shield \n208\n and provides electrical shielding to protect the electromagnetic signals from interference.', 'In other words, the metal housing \n205\n and conductor shield \n208\n are the same structure.', 'Additionally, the aperture antenna assembly \n102\n includes example radiating elements \n204\n to transmit and/or receive electromagnetic signals across an example measurement plane \n226\n orthogonal to a direction of flow of fluid within the throat section \n107\n of the vessel \n105\n of \nFIG.', '1\n.', 'The pressure vessel apparatus \n103\n of \nFIG.', '2\n is a pressure retaining member that includes an example pressure retaining measurement window (PRMW) \n212\n, example electrical conductor shims \n213\n, an example seal \n214\n, example cavity fillers \n206\nA, \n206\nB, the metal housing \n205\n, an example elastic member \n220\n, and an example retaining member \n222\n.', 'In the illustrated example of \nFIG.', '2\n, the radiating elements \n204\n can be transmitting antennae and/or receiving antennae that are positioned around the perimeter of the throat section \n107\n of the vessel \n105\n.', 'The pressure vessel apparatus \n103\n and the metal housing \n205\n protect and secure the radiating elements \n204\n.', 'In some examples, the radiating elements \n204\n can be one or more radiating conductors.', 'In some examples, if the radiating element \n204\n is a transmitting antenna (e.g., a transmitter), the radiating element \n204\n transmits the electromagnetic signal into the throat section \n107\n of the vessel \n105\n across the measurement plane \n226\n.', 'In some such examples, the fluid within the throat section \n107\n of the vessel \n105\n reflects the transmission and the radiating element \n204\n receives a reflection of the electromagnetic signal (e.g., a reflection signal).', 'In some examples, magnitude and phase data of the reflection signal can be utilized to determine a water-liquid ratio, in addition to other parameters, of the multiphase fluid within the vessel \n105\n.', 'Additionally, in some examples, the radiating elements \n204\n that act as receiving antennae (e.g., receivers) are positioned across the throat section \n107\n of the vessel \n105\n with one or more angular displacement (e.g., 60°, 90°, 120°, 180°, etc.) in relation to the radiating element \n204\n that acts as the transmitting antenna.', 'In some such examples, the receiving antennae receive the transmission of the electromagnetic signal (e.g., a transmission signal) from the transmitting antenna.', 'The angular displacements of the radiating elements \n204\n that receive the transmission signals results in different magnitude and phase data due to the different spatial displacements and/or different gas fractions among the different transmitter-receiver pairs.', 'For example, during a vertical upward flow of fluid gas tends to flow through the center of the vessel \n105\n causing different gas fractions to be measured by receivers with different angular displacements.', 'In some examples, the magnitude and phase data of the transmission signals received by the receiving antennae is utilized to determine a gas phase fraction or gas holdup (GHU), in addition to other parameters such as WLR, of the multiphase fluid within the throat section \n107\n of the vessel \n105\n.', 'In the cases described above including several radiating elements \n204\n arranged on the vessel \n105\n, an aperture antenna assembly \n102\n including the pressure vessel apparatus \n103\n may be configured to include all radiating elements as described above.', 'In an alternative, multiple antenna assemblies, each including one or more radiating elements \n204\n as for instance disclosed in relationship with \nFIG. \n10\n, may be arranged on the vessel \n105\n.', 'In a particular embodiment, when a plurality of radiating elements are positioned with an angular and/or axial displacement relative to each other, each radiating element of the plurality is associated to a distinct aperture antenna assembly and pressure vessel apparatus \n103\n.', 'In the illustrated example of \nFIG.', '2\n, a first end of the radiating element \n204\n couples to the SMA connector \n228\n via a soldering connection or an interference fit.', 'In some such examples, the SMA connector \n228\n includes a coaxial feedthrough that is coupled the first end of the radiating element \n204\n and the electrical RF coaxial cable \n110\n.', 'As discussed in \nFIG.', '1\n, the electrical RF coaxial cable \n110\n transports the electromagnetic signals to and from the radiating element \n204\n to the flowmeter controller \n104\n.', 'In some examples, the electrical RF coaxial cable \n110\n extends through the metal housing \n205\n, via the SMA connector \n228\n with a coaxial feedthrough, to couple to the first end of the radiating element \n204\n.', 'In some such examples, an insulation ring radially surrounds the first end of the radiating element \n204\n to insulate the connection between the radiating element \n204\n and a center-conductor of the of SMA connector \n228\n and, thus insulate the center-conductor of electrical RF cable \n110\n from the metal housing \n205\n, as discussed further in association with \nFIG.', '5\n.', 'In some examples, the electrical RF coaxial cable \n110\n includes a first portion outside the metal housing \n205\n that couples to the SMA connector \n228\n attached to the metal housing \n205\n.', 'In some such examples, the SMA connector \n228\n can include a flange-mount that is secured to the metal housing \n205\n via screws.', 'In the illustrated example, the electrical conductor shield \n208\n surrounds the SMA connector \n228\n and the associated flange-mount.', 'In \nFIG.', '2\n, a second end of the radiating element \n204\n is coupled to the associated metal housing \n205\n via an interference fit.', 'In some examples, the metal housing \n205\n is electrically coupled by a mechanical metal surface contact to an exterior surface of the vessel \n105\n, which is composed of metal.', 'In some such examples, the electrical coupling between the metal housing \n205\n and the vessel \n105\n and/or electrical shielding is enhanced by the electrical conductor shims \n213\n.', 'In some disclosed examples, the metal housing \n205\n can be intact without any cuts or slits.', 'In some disclosed examples, to improve electromagnetic transmission signal between radiating elements \n204\n peripherally displaced over a large pipe and/or throat diameter, the metal housing \n205\n can include a first section, a second section, and a third section defined by example slits (e.g., gaps, openings, etc.) \n224\n.', 'In some such examples, the metal housing \n205\n can include a first set of slits \n224\n parallel to the radiating element \n204\n.', 'In some examples, the first set of slits \n224\n can completely separate and/or otherwise isolate the second section (e.g., the middle section) from the first and third sections of the metal housing \n205\n as discussed further in association with \nFIGS.', '4\nA-\n4\nB\n.', 'In some examples, the middle section of the metal housing \n205\n includes the coaxial feedthrough of the SMA connector \n228\n to provide electromagnetic signals transported by the electrical RF cable \n110\n to the radiating element \n204\n within the metal housing \n205\n.', 'Additionally, the flange and screws associated with the flange-mount of the SMA connector \n228\n couple to the first and third sections of the metal housing \n205\n.', 'In some examples, the second section of the metal housing \n205\n couples to the second end of the radiating element \n204\n.', 'In some such examples, the second section of the metal housing \n205\n and the radiating element \n204\n can be removed from the exterior surface of the vessel when the screws associated with the flange-mount SMA connector \n228\n are uncoupled from the first and third sections of the metal housing \n205\n.', 'In some examples, the metal housing \n205\n can include a second set of slits (not shown) that extend partially through the first and third section of the metal housing \n205\n to form cross-cut slits.', 'In some such examples, the second set of slits are parallel to one another and perpendicular to the first set of slits \n224\n and the radiating element \n204\n.', 'In some examples, the first set of slits \n224\n and the second set of slits improve a transmission gain of the electromagnetic signals that the radiating element \n204\n transmits and/or receives.', 'For example, the first set of slits \n224\n and the second set of slits can cause a constructive interference of electromagnetic fields inside the cavity formed by the metal housing \n205\n that enhances field propagation of the electromagnetic transmission signal into the throat section \n107\n of the vessel \n105\n.', 'In some disclosed examples, the electromagnetic signal enhanced by the constructive interference caused by the first set of slits \n224\n and the second set of slits allows for more accurate magnitude and phase measurements across larger vessel diameters.', 'In the illustrated example of \nFIG.', '2\n, the pressure vessel apparatus \n103\n prevents fluid from entering the aperture antenna assembly \n102\n through the PRMW \n212\n, which isolates the radiating element \n204\n from the fluid within the vessel \n105\n.', 'In some examples, the metal housing \n205\n and other components of the pressure vessel apparatus \n103\n provide support to the PRMW \n212\n.', 'The PRMW \n212\n provides a low-loss dielectric window for electromagnetic signals to propagate through as the electromagnetic signals transmit through the throat section \n107\n of the vessel \n105\n to and/or from the radiating element \n204\n.', 'In some examples, the PRMW \n212\n includes a high mechanical-strength ceramic material to improve a pressure-rating (e.g., 5000 psi or greater) and a temperature-rating (e.g., 150° C. or greater) of the PRMW \n212\n.', 'The example PRMW \n212\n includes a first face facing the interior of the throat section \n107\n of the vessel \n105\n, a second face orthogonal to the first face extending away from the interior of the throat section \n107\n of the vessel \n105\n, and a third face opposite the first face.', 'In some disclosed examples, the first face of the PRMW \n212\n is flush (e.g., mesh) with an interior surface of the throat section \n107\n of the vessel \n105\n.', 'In some examples, the PRMW \n212\n includes flanges (e.g., tabs) extending from an edge of the second face farthest from the first face on opposite sides of the PRMW \n212\n.', 'In some such examples, an exterior surface of the vessel includes grooves that the flanges are to be aligned with to maintain an alignment of the first face of the PRMW \n212\n.', 'In some examples, the seal (e.g., an O-ring) \n214\n radially surrounds the second face of the PRMW \n212\n, substantially orthogonal to the first face extending away from the vessel, to provide seal integrity during high-pressure flow.', 'In some examples, the PRMW \n212\n is in contact with the electrical conductor shims \n213\n to ensure proper electrical shielding among the radiating element \n204\n by reducing (e.g., minimizing) cross-talk among the radiating elements \n204\n.', 'In some such examples, the electrical conductor shims \n213\n include copper, beryllium copper, bronze, and/or brass.', 'Additionally, the electrical conductor shims \n213\n can include a gold-plating or a silver-plating on an exterior surface thereof.', 'In \nFIG.', '2\n, the cavity filler', '206\nA extends from the third face of the PRMW \n212\n opposite the first face.', 'In some examples, the cavity filler \n206\nA and the PRMW \n212\n are machined from a single piece of an appropriate dielectric material, such as an engineering thermoplastic (e.g., a polyether ether ketone (PEEK) material), for example.', 'In some such examples, the cavity filler \n206\nB can be machined from another piece of the same appropriate dielectric material.', 'In some examples, the design of the PRMW \n212\n and the associated cavity filler \n206\nA, \n206\nB is based on the radiating element \n204\n design.', 'For example, the cavity filler \n206\nA can include slots based on the geometry of the radiating element \n204\n.', 'Further, in some examples, the cavity filler \n206\nA, \n206\nB is implemented to fill the cavity of the metal housing \n205\n on the opposite side of the radiating element \n204\n from the PRMW \n212\n.', 'In some such examples, the cavity filler \n206\nA, \n206\nB similarly includes PEEK material.', 'The PEEK material provides high pressure retaining performance (e.g., design pressure of 100 to 200 bar) and wide temperature range (e.g., −29° C. to 121° C.).', 'Additionally, the dielectric permittivity of the PEEK material within the PRMW \n212\n and the cavity filler \n206\nA, \n206\nB improves a transmission magnitude gain of the electromagnetic signal.', 'Further, in some examples, the PRMW \n212\n and the cavity filler \n206\nA, \n206\nB include other ceramic materials with higher dielectric permittivity than PEEK, such as aluminum oxide, which substantially improves a transmission gain of the electromagnetic signal, in addition to improving the design pressure performance and temperature rating of the PRMW \n212\n.', 'In some examples, the cavity filler \n206\nA, \n206\nB includes a material with a higher dielectric permittivity than aluminum oxide, such as titanium dioxide, which substantially improves the transmission gain of the electromagnetic signal.', 'In the illustrated example of \nFIG.', '2\n, the pressure vessel apparatus \n103\n further includes the metal housing \n205\n, the elastic member \n220\n, and the retaining member \n222\n to provide support to the PRMW \n212\n against fluid pressure within the vessel \n105\n.', 'In \nFIG.', '2\n, the elastic member \n220\n is a washer.', 'For example, the elastic member \n220\n can be a Bellville washer or any other type of washer.', 'In \nFIG.', '2\n the retaining member \n222\n is a ring.', 'For example, the retaining member \n222\n can be a Spirolox® retaining ring.', 'In some examples, the elastic member \n220\n is preloaded to provide a resistance force by a bolt which is subsequently removed from the pressure vessel apparatus \n103\n, as discussed in association with \nFIG.', '8\n.', 'In some such examples, the metal housing \n205\n includes internal threads for the bolt to couple to and preload the elastic member \n220\n.', 'Alternatively, in some examples, a body of the vessel \n105\n includes the internal threads for the bolt to couple to and preload the elastic member \n220\n.', 'In some such examples, the body of the vessel \n105\n includes a portion (e.g., an interior portion, a portion extending from an exterior surface to an interior point, etc.) of the vessel \n105\n that does not directly contact the fluid within the vessel.', 'In the illustrated example, the electrical conductor shims \n213\n are positioned at a secondary contact area between the pressure retaining measurement window (PRMW) \n212\n and the metal housing \n205\n to provide electrical shielding of the radiating element \n204\n.', 'In the illustrated example, a primary contact area between the PRMW \n212\n and the metal housing \n205\n is at a surface of the cavity filler \n206\nA, \n206\nB opposite the vessel \n105\n.', 'In some such examples, the electrical conductor shims \n213\n can include one or more layers at the secondary contact area based on the geometry of the PRMW \n212\n and the metal housing \n205\n.', 'Additionally, the electrical conductor shims \n213\n of the secondary contact area can provide a shielding connection between the metal housing \n205\n and the vessel \n105\n.', 'In other examples, separate ones of the electrical conductor shims \n213\n provide the separation between the flange of the PRMW \n212\n and the metal cavity housing \n205\n and the separation between the metal housing \n205\n and the vessel \n105\n.', 'In the illustrated example, at the primary contact area between the PRMW \n212\n and the metal housing \n205\n an inside face (e.g., a front face) of the metal housing \n205\n is in contact with the cavity filler \n206\nA, \n206\nB and/or the PRMW \n212\n and an outside face (e.g., a back face) of the metal housing \n205\n is in contact with the elastic member \n220\n.', 'In the illustrated example, the retaining member \n222\n couples to a face of the elastic member \n220\n opposite the metal housing \n205\n.', 'In some examples, an exterior surface of the vessel \n105\n includes grooves for the retaining member \n222\n to be at least partially inserted within to align and maintain a relative position thereof.', 'After the elastic member \n220\n of the pressure vessel apparatus \n103\n is preloaded, the retaining member \n222\n maintains a relative position of the elastic member \n220\n so that the elastic member \n220\n provides a force to the PRMW \n212\n to resist pressure within the vessel \n105\n.\n \nFIG.', '3\n illustrates an example cross-section A-A of a simplified representation of the first aperture antenna assembly \n102\n of \nFIGS.', '1\n and/or \n2\n.', 'The simplified representation of the aperture antenna assembly \n102\n includes an example cavity filler \n304\n and a second example radiating element \n306\n in addition to the radiating element \n204\n, the metal housing (e.g., the metal housing without any slits) \n205\n, the pressure retaining measurement window (PRMW) \n212\n, and the measurement plane \n226\n of \nFIG.', '2\n.', 'The simplified representation illustrates an example implementation of the aperture antenna of the aperture antenna assembly \n102\n.', 'In \nFIG. \n3\n, the radiating element \n204\n is coupled to the metal housing \n205\n and the second radiating element \n306\n is positioned within the metal housing behind and orthogonally aligned with the radiating element \n204\n.', 'In the illustrated example, the radiating element \n204\n and the second radiating element \n306\n form a cross-dipole antenna.', 'In some examples, the PRMW \n212\n functions as a dielectric window and a cavity-plug within an example interior surface \n302\n of the throat section \n107\n of the vessel \n105\n to provide a pressure barrier between the radiating element \n204\n and the flow within the vessel \n105\n.', 'In some examples, the thickness of the illustrated PRMW \n212\n is at least 2 mm, but in other examples, the thickness may be less than 2 mm.', 'In the illustrated example, the cavity filler \n304\n at least partially extends from the PRMW \n212\n away from the throat section \n107\n of the vessel \n105\n and surrounds the radiating element \n204\n to provide insulation.', 'For example, the cavity filler \n304\n of \nFIG.', '3\n can be an example implementation of at least one of the cavity filler \n206\nA or the cavity filler \n206\nB of \nFIG.', '2\n.', 'In the illustrated example, the radiating element \n204\n and the associated measurement plane \n226\n are substantially orthogonal to a direction of flow within the vessel \n105\n.', 'In some examples, the aperture antenna assembly \n102\n can include multiple radiating elements (e.g., 3 radiating elements, 4 radiating elements, etc.), such as radiating element \n204\n, positioned around the periphery of a measurement plane, with e.g. two receivers at appropriate angular displacements with respect to two transmitters at the measurement plane, to perform drift-free magnitude and phase-shift measurements, as disclosed in the U.S. Pat.', 'No. 8,536,883.', 'Drift-free magnitude and phase-shift measurements may be performed at multiple (e.g. two) measurement planes, and/or across two measurement planes.', 'FIG.', '4\nA\n illustrates a first example implementation of cross-cut slits in the metal housing \n205\n of the aperture antenna assembly \n102\n of \nFIGS.', '1\n, \n2\n, and/or \n3\n.', 'The first example metal housing \n205\n includes an example first section \n404\n, an example second section (e.g., a middle section) \n402\n, and an example third section \n406\n.', 'In the illustrated example, the second section \n402\n is separated from the first section \n404\n and the third section \n406\n by the parallel slits \n224\n.', 'In some examples, the second section \n402\n is coupled to the first section \n404\n and the third section \n406\n via a flange-mount and screws in association with the SMA connector \n228\n, as further discussed in association with \nFIG.', '5\n.', 'In some such examples, the second section \n402\n and/or the metal housing \n205\n is supported by the cavity filler \n304\n inside the metal housing \n205\n and supported by a metal (e.g. copper tape with adhesive) shield \n420\n surrounding a circumference of the metal housing \n205\n.', 'In some examples, the metal shield \n420\n can be an example implementation of the conductor shield \n208\n, discussed in association with \nFIG.', '2\n.', 'The second section \n402\n of the metal housing \n205\n includes an example opening \n416\n that the flange-mount of the SMA connector \n228\n aligns with so that the electrical RF cable \n110\n can extend through the metal housing \n205\n to couple to an end of the radiating element \n204\n.', 'In some examples, screws secure the flange-mount of the SMA connector \n228\n to the metal housing \n205\n by coupling to example threaded openings \n418\n of the first section \n404\n and the third section \n406\n.', 'In the illustrated example, the second section \n402\n of the metal housing \n205\n and, thus, the radiating element \n204\n can be removed by uncoupling the screws from the metal housing \n205\n.', 'The removability of the second section \n402\n of the metal housing \n205\n allows for easy repairs or replacement of the radiating element \n204\n and associated SMA connector \n228\n connected to the electrical RF cable \n110\n.', 'Additionally, the removability of the second section \n402\n allows for the pressure retaining performance of the pressure vessel apparatus \n103\n to be tested without the radiating element \n204\n installed and, thus, reduces the risk of damaging the radiating element \n204\n due to poor pressure retaining performance.', 'In \nFIG.', '4\nA\n, the parallel slits \n224\n are parallel (e.g., substantially parallel) to the radiating element \n204\n, as discussed in association with \nFIG.', '2\n.', 'As used herein in the context of describing the position and/or orientation of a first object relative to a second object, the term “substantially parallel” encompasses the term parallel and more broadly encompasses a meaning whereby the first object is positioned and/or oriented relative to the second object at an absolute angle of no more than two degrees (2°) from parallel.', 'For example, a first axis that is substantially parallel to a second axis is positioned and/or oriented relative to the second axis at an absolute angle of no more than two degrees (2°) from parallel.', 'In some examples, the parallel slits \n224\n include a width in an example range of 0.5 and 2.0 mm with the 2.0 mm maximum width determined by the diameter of the radiating element \n204\n.', 'In some such examples, a larger slit width results in a better transmission gain of the electromagnetic signal.', 'In the illustrated example, the first section \n404\n includes an example first slit \n408\n and an example second slit \n410\n that extend partially through the first section \n404\n.', 'Additionally, the third section \n406\n includes an example third slit \n412\n and an example fourth slit \n414\n that extend partially through the third section \n406\n.', 'The first slit \n408\n, the second slit \n410\n, the third slit \n412\n, and the fourth slit \n414\n form a set of perpendicular slits \n408\n, \n410\n, \n412\n, \n414\n that are substantially perpendicular, substantially orthogonal, etc., to the parallel slits \n224\n and, thus, to the radiating element \n204\n.', 'In some examples, the perpendicular slits \n408\n, \n410\n, \n412\n, \n414\n include a width between 0.5 and 2.0 mm with the 2.0 mm maximum width determined by the diameter of the radiating element \n204\n.', 'In some such examples, a larger slit width results in a better transmission gain of the electromagnetic signal.', 'The parallel slits \n224\n and/or the perpendicular slits \n408\n, \n410\n, \n412\n, \n414\n are configured to enhance a field propagation of the electromagnetic signal into the throat section \n107\n of the vessel \n105\n via constructive interference inside the cavity formed by the metal housing \n205\n.', 'Specifically, the perpendicular slits \n408\n, \n410\n, \n412\n, \n414\n produce complimentary electromagnetic fields that are in the same direction as the transmitted electromagnetic field.', 'As used herein in the context of describing the position and/or orientation of a first object relative to a second object, the term “substantially perpendicular” encompasses the term perpendicular and more broadly encompasses a meaning whereby the first object is positioned and/or oriented relative to the second object at an absolute angle of no more than two degrees (2°) from perpendicular.', 'For example, a first axis that is substantially perpendicular to a second axis is positioned and/or oriented relative to the second axis at an absolute angle of no more than two degrees (2°) from perpendicular.\n \nFIG.', '4\nB\n illustrates a second example metal housing \n205\n without slits on the aperture antenna assembly \n102\n of \nFIGS.', '1\n, \n2\n, and/or \n3\n.', 'In the illustrated example, the metal housing \n205\n includes the opening \n416\n that the flange-mount of the SMA connector \n228\n aligns with so that the electrical RF cable \n110\n can extend through the metal housing \n205\n to the radiating element \n204\n.', 'Additionally, the metal housing \n205\n includes the threaded openings \n418\n to allow screws to couple the flange-mount of the SMA connector \n228\n to the metal housing \n205\n.\n \nFIG.', '5\n illustrates an example midsection (e.g., a middle section) \n500\n of the second example metal housing \n205\n of \nFIG.', '4\nB\n.', 'For example, the midsection \n500\n of \nFIG.', '5\n can correspond to the second section \n402\n of \nFIG.', '4\nB\n.', 'The midsection \n500\n of the metal housing \n205\n includes the electrical RF cable \n110\n coupled to an example (Male′)', 'SMA connector \n502\n, an example flange-mount (‘female’)', 'SMA connector (e.g., an SMA connector and associated coaxial feedthrough) \n503\n including example threaded holes \n508\n for screws to couple the flange-mount SMA connector \n503\n to the first section \n404\n and the third section \n406\n of the metal housing \n205\n.', 'For example, the flange-mount SMA connector \n503\n can correspond to the SMA connector \n228\n of \nFIGS.', '1\n and/or \n2\n.', 'The second section \n402\n of the metal housing \n205\n further includes the opening \n416\n to allow the coaxial feedthrough of the SMA connector \n503\n to couple to the radiating element \n204\n.', 'In the illustrated example, a solder or interference-fit connection \n504\n couples an end of the coaxial-feedthrough of the SMA connector \n503\n to a first end of the radiating element \n204\n.', 'In the illustrated example, the second section \n402\n includes an insulation ring \n510\n to insulate the connection between a center-conductor of the SMA connector \n503\n and the radiating element \n204\n from the metal housing \n205\n.', 'In some such examples, the metal housing \n205\n, or second section \n402\n thereof, is electrically connected to an outer-conductor of the SMA connectors \n502\n, \n503\n.', 'In some examples, a second end \n506\n of the radiating element \n204\n couples to the second section \n402\n of the metal housing \n205\n, via the interference fit.', 'In the illustrated example, the electrical RF cable \n110\n, coupled with SMA connectors \n502\n, \n503\n transports electromagnetic signals between the flowmeter controller \n104\n and the radiating element \n204\n.', 'In some examples, the radiating element \n204\n includes a gold plating on the exterior surface thereof to prevent oxidation.\n \nFIG.', '6\n illustrates a simplified cross-section A-A of the pressure vessel apparatus \n103\n of the aperture antenna assembly of \nFIGS.', '1\n and/or \n2\n.', 'The pressure vessel apparatus \n103\n of \nFIG.', '6\n includes the metal housing \n205\n, the PRMW \n212\n, the seal \n214\n, the elastic member \n220\n, the retaining member \n222\n, and the measurement plane \n226\n of \nFIG.', '2\n.', 'Advantageously, the pressure vessel apparatus \n103\n provides a relatively compact, low-cost solution to replace the generic bolt-flange assembly that supports the PRMW \n212\n from displacement.', 'The pressure vessel apparatus \n103\n can reduce passive interference or cross-talk of the electromagnetic signals that can be caused by the bolt-flange assembly as components deteriorate (e.g., rust).', 'In the illustrated example, a first face \n610\n of the PRMW \n212\n meshes with the interior surface \n302\n of the throat section \n107\n of the vessel \n105\n.', 'In some examples, a second face \n612\n of the PRMW \n212\n extends away from the interior surface \n302\n of the throat section \n107\n of the vessel \n105\n and is substantially orthogonal to the first face \n610\n of the PRMW \n212\n.', 'In \nFIG. \n6\n, the seal \n214\n is an O-ring that radially surrounds the second face \n612\n of the PRMW \n212\n.', 'The seal \n214\n provides seal integrity to the PRMW \n212\n when there is high pressure flow within the vessel \n105\n.', 'In the illustrated example, the metal housing \n205\n is in contact with a third face \n614\n of the PRMW \n212\n and the conductor shield \n208\n is in contact with an opposite side of the metal housing \n205\n.', 'In some examples, the metal housing \n205\n and conductor shield \n208\n are the same structure.', 'The elastic member \n220\n is in contact with an example face \n615\n of the conductor shield \n208\n and/or the metal housing \n205\n opposite the PRMW \n212\n.', 'The elastic member \n220\n is preloaded to support the PRMW \n212\n against the pressure exerted by the fluid within the vessel \n105\n.', 'The retaining member \n222\n is in contact with an example face \n616\n of the elastic member \n220\n opposite the PRMW \n212\n to retain the relative position of the elastic member \n220\n and the pressure vessel apparatus \n103\n.', 'The design of the pressure vessel apparatus \n103\n considers a compressed configuration of the elastic member \n220\n that supports the PRMW \n212\n against pressure and prevents axial displacement.', 'In the example of Equation (1) below, the preload, F\nP\n, of the elastic member \n220\n is calculated to be higher than the pressure, P, that the fluid within the vessel \n105\n exerts based on the dimensions of the seal \n214\n, πd\nS\n2\n/4.', 'Further, Equation (1) below considers the loss of preload due to contacts embedment, F\nZ\n, and thermal effects, F\nT\n.', 'The contacts embedment, F\nZ\n, and thermal effects, F\nT\n, considers the stiffness of the retaining member \n222\n, K\nRD\n, the metal housing \n205\n and/or conductor shield \n208\n, K\nSP\n, and the elastic member \n220\n, K\nEC\n.', 'The contacts embedment, F\nZ\n, also considers the contact surface embedment between the retaining member \n222\n and the elastic member \n220\n, f\nz1\n, between the elastic member \n220\n and the metal housing \n205\n and/or conductor shield \n208\n, f\nz2\n, and between the metal housing \n205\n and/or conductor shield \n208\n and the third face \n614\n of the PRMW \n212\n, f\nz3\n.', 'The thermal effects, F\nT\n, includes a maximum temperature difference between pressure vessel apparatus \n103\n temperature and an operation temperature, ΔT.', 'Additionally, the thermal effects, F\nT\n, considers an average coefficient of thermal expansion of the retaining member \n222\n, α\nRD\n, the metal housing \n205\n and/or conductor shield \n208\n, α\nSP\n, and the elastic member \n220\n, α\nEC\n, in addition to a distance between the retaining member \n222\n and the first face \n610\n of the PRMW \n212\n, l\nk\n.', 'F\n \nP\n \n \n=\n \n \n \nP\n \n\u2062\n \n \n \nπ\n \n\u2062\n \n \n \n \n\u2062\n \n \nd\n \nS\n \n2\n \n \n \n4\n \n \n \n+\n \n \n \nF\n \nZ\n \n \n\u2061\n \n \n(\n \n \n \nK\n \nRD\n \n \n,\n \n \nK\n \nSP\n \n \n,\n \n \nK\n \n \nE\n \n\u2062\n \nC\n \n \n \n,\n \n \nf\n \n \nz\n \n\u2062\n \n \n \n \n\u2062\n \n1\n \n \n \n,\n \n \nf\n \n \nz\n \n\u2062\n \n \n \n \n\u2062\n \n2\n \n \n \n,\n \n \nf\n \n \nz\n \n\u2062\n \n3\n \n \n \n \n)\n \n \n \n+\n \n \n \nF\n \nT\n \n \n\u2061\n \n \n(\n \n \n \nK\n \nRD\n \n \n,\n \n \nK\n \nSP\n \n \n,\n \n \nK\n \n \nE\n \n\u2062\n \nC\n \n \n \n,\n \n \nΔ\n \n\u2062\n \n \n \n \n\u2062\n \nT\n \n \n,\n \n \nα\n \nRD\n \n \n,\n \n \nα\n \nSP\n \n \n,\n \n \nα\n \nEC\n \n \n,\n \n \nl\n \nk\n \n \n \n)\n \n \n \n \n \n \n \n \nEquation\n \n\u2062\n \n \n \n \n\u2062\n \n \n(\n \n1\n \n)', 'In some examples, the flowmeter controller \n104\n uses Equation (1) to determine a material and/or geometry of the retaining member \n222\n, the elastic member \n220\n, the metal housing \n205\n, and/or the conductor shield \n208\n that provides the elastic member \n220\n with the preload, F\nP\n.', 'In some examples, an operator (e.g., a machine, a machine operator, etc.) can perform numerical analysis to validate the sufficiency of the preload, F\nP\n, that the elastic member \n220\n exerts.', 'The preload, F\nP\n, of the elastic member \n220\n can be increased by incorporating a second elastic member in series with the elastic member \n220\n and the retaining member \n222\n.', 'Additionally, the retaining member \n222\n is designed to withstand the preload, F\nP\n, to prevent displacement of the PRMW \n212\n against pressure in the vessel \n105\n.', 'In some examples, the elastic member \n220\n is a Belleville washer that provides a large preload F\nP\n, from a small compression to allow for a compact design of the pressure vessel apparatus \n103\n.', 'Additionally, in some examples, the retaining member \n222\n is a Spirolox® retaining ring that includes a high strength to size ratio to further allow for a compact design of the pressure vessel apparatus \n103\n.\n \nFIG.', '7\n illustrates a second example implementation of the pressure vessel apparatus \n103\n of the aperture antenna assembly \n102\n implemented on the edge of the vessel \n105\n of \nFIGS.', '1\n and/or \n2\n.', 'The example pressure vessel apparatus \n103\n includes the PRMW \n212\n, the seal \n214\n, the metal housing \n205\n, the elastic member \n220\n, and the retaining member \n222\n of \nFIG.', '2\n.', 'The pressure vessel apparatus \n103\n of \nFIG.', '7\n includes the radiating element \n204\n of \nFIG.', '2\n to transmit and/or receive electromagnetic signals across the measurement plane \n226\n of \nFIG.', '2\n.', 'In \nFIG.', '7\n, the PRMW \n212\n has a curvature that matches with the interior surface \n302\n of the throat section \n107\n of the vessel \n105\n.', 'The seal \n214\n radially surrounds the PRMW to create a sufficient seal against the fluid pressure within the throat section \n107\n of the vessel \n105\n.', 'In the illustrated example, the metal housing \n205\n contacts a face of the cavity filler extending from a face of the PRMW \n212\n opposite the throat section \n107\n of the vessel \n105\n.', 'In \nFIG.', '7\n, the elastic member \n220\n is compressed to provide a preload to the metal housing \n205\n and, thus, the PRMW \n212\n to resist the fluid pressure within the throat section \n107\n of the vessel \n105\n.', 'In some examples, the flowmeter \n100\n includes a groove (e.g., a slot, a rim, etc.) to install the retaining member \n222\n and maintain a relative position thereof.', 'In the illustrated example, the retaining member \n222\n supports the preload of the elastic member \n220\n so that the retaining force is directed towards the metal housing \n205\n and the PRMW \n212\n to counteract the pressure within the throat section \n107\n of the vessel \n105\n and prevent displacement of the PRMW \n212\n.\n \nFIGS.', '8\nA-\n8\nD\n illustrate an example process or workflow to preload the pressure vessel apparatus \n103\n of \nFIG.', '1\n.', 'The illustrated example includes an example bolt \n802\n, the elastic member (e.g., a washer, a Belleville washer, etc.) \n220\n, the retaining member (e.g., a retaining ring, a Spirolox® retaining ring, etc.) \n222\n, the metal housing \n205\n, the seal (e.g., an O-ring) \n214\n, and the PRMW \n212\n.', 'In \nFIG. \n8\nA\n, an operator (e.g., a machine, a machine operator, etc.) screws the bolt \n802\n into an opening of the metal housing \n205\n with the elastic member \n220\n radially surrounding a body of the bolt \n802\n above the metal housing \n205\n.', 'In \nFIG.', '8\nB\n, an operator (e.g., a machine, a machine operator, etc.) torques the bolt \n802\n to compress (e.g., flatten) the elastic member \n220\n between the bolt \n802\n and the metal housing \n205\n, thereby preloading the elastic member \n220\n.', 'In \nFIG.', '8\nC\n, an operator (e.g., a machine, a machine operator, etc.) installs the retaining member \n222\n into a groove of the flowmeter \n100\n of \nFIG. \n1\n.', 'In the illustrated example, an inner diameter of the retaining member \n222\n is larger than the diameter of a head of the bolt \n802\n so that the user can install the retaining member \n222\n over the head of the bolt \n802\n.', 'In the illustrated example, the inner diameter of the retaining member \n222\n is smaller than an outer diameter of the elastic member \n220\n so that the retaining member \n222\n remains in contact with, and retains a position of, the elastic member \n220\n after the bolt \n802\n applies the preload.', 'In \nFIG.', '8\nD\n, an operator (e.g., a machine, a machine operator, etc.) removes (e.g., unscrews) the bolt \n802\n from the opening in the metal housing \n205\n.', 'The retaining member \n222\n retains the preload of the elastic member \n220\n applied by the bolt \n802\n and, as a result, the pressure vessel apparatus \n103\n is preloaded to support the PRMW \n212\n against fluid pressure within the vessel \n105\n and prevent axial displacement thereof.', 'In some examples, the bolt \n802\n is utilized to preload more than one pressure vessel apparatus \n103\n.', 'FIG.', '9\n illustrates an example implementation of the pressure retaining measurement window \n212\n of \nFIG.', '2\n that can be included in the pressure vessel apparatus \n103\n of \nFIGS.', '1\n, \n2\n, \n6\n, \n7\n, and/or \n8\n.', 'In the illustrated example, the PRMW \n212\n includes an example outer face \n902\n, an example shoulder \n904\n, an example inner face \n906\n, two example flanges (e.g., tabs) \n908\n on opposite sides of the PRMW \n212\n, an example cavity filler \n910\n, an example primary contact surface \n912\n, and an example secondary contact surface \n914\n.', 'The PRMW \n212\n includes a low-loss dielectric material and/or a substantially high dielectric constant (ε) material (e.g., ε=3, ε=9, etc.), such as an engineering thermoplastic PEEK, or an aluminum oxide ceramic, for example, to facilitate the transmission and reception of electromagnetic signals by a radiating element \n204\n.', 'In the illustrated example, the outer face \n902\n has a curvature that substantially matches (e.g., matches within a tolerance in a range of 0-1%) a curvature of an interior surface \n302\n of the throat section \n107\n of the vessel \n105\n of \nFIG.', '1\n.', 'The thickness between the outer face \n902\n and the inner face \n906\n is at least 2 mm.', 'Alternatively, the thickness may be any other value depending on the design pressure and temperature.', 'In some examples, the shoulder \n904\n is substantially orthogonal to the outer face \n902\n and the interior surface \n302\n of the throat section \n107\n of the vessel \n105\n.', 'In some such examples, the seal (e.g., an O-ring) \n214\n surrounds the shoulder \n904\n to provide seal integrity to the PRMW \n212\n during high pressure applications.', 'In some disclosed examples, a geometry of the inner face \n906\n typically depends on a geometry of the metal housing \n205\n including the radiating element \n204\n that will be implemented within a cavity between the metal housing \n205\n and the inner face \n906\n.', 'In the illustrated example, the cavity filler \n910\n can be an example implementation of the cavity filler \n206\nA of \nFIG.', '2\n, and/or the cavity filler \n304\n of \nFIG.', '3\n.', 'In \nFIG.', '9\n, the cavity filler \n910\n extends from the inner face \n906\n of the PRMW \n212\n.', 'In some examples, the cavity filler \n910\n is a cylinder that includes slots within which the radiating element \n204\n is to be positioned.', 'In the illustrated example, the cavity filler (e.g., cavity filler \n206\nA, cavity filler \n304\n) \n910\n includes a single slot within which the radiating element \n204\n is to be implemented.', 'In other words, the cavity filler \n910\n includes two half-circle pillars that extend from the inner face \n906\n of the PRMW \n212\n.', 'In \nFIG.', '9\n, the face of the cavity filler \n910\n opposite the outer face \n902\n of the PRMW \n212\n is the primary contact surface \n912\n that contacts a cavity bottom surface of the metal housing \n205\n directly.', 'In some examples, the secondary contact surface \n914\n is in contact with the metal housing \n205\n, and/or the electrical conductor shim \n213\n to provide electrical shielding among the radiating elements \n204\n.', 'In \nFIG.', '9', ', the primary contact surface \n912\n for the pressure vessel apparatus \n103\n is the face of the cavity filler \n910\n opposite the outer face \n902\n.', 'In some examples, a face of the cavity filler \n206\nA, \n206\nB forms the primary contact surface \n912\n that contacts the metal housing \n205\n of \nFIG.', '2\n.', 'In the illustrated example, a face of the flanges \n908\n opposite the outer face \n902\n forms the secondary contact surface \n914\n.', 'In some examples, the secondary contact surface \n914\n is in contact with a flange shoulder of the metal housing \n205\n and/or the electrical conductor shim \n213\n to provide electrical shielding for the electromagnetic signals transmitted and/or received by the radiating element \n204\n.', 'In some examples, the flowmeter \n100\n includes grooves in an exterior surface of the vessel \n105\n for the flanges \n908\n to be positioned within.', 'The flanges \n908\n maintain the alignment of the curvature of the outer face \n902\n with the interior face \n302\n of the throat section \n107\n of the vessel \n105\n.\n \nFIG.', '10\n is a block diagram \n1000\n of an example implementation of a multiphase flow meter including a plurality of antenna aperture assemblies \n102\nA, \n102\nB coupled to the vessel \n105\n of \nFIGS.', '1\n and/or \n2\n.', 'The illustrated example includes the measurement plane \n226\n, a transmission radiating element \n204\nA (of a first aperture antenna assembly \n102\nA), a receiving radiating element \n204\nB (of a second aperture antenna assembly \n102\nB), and the pressure vessel apparatus \n103\nA, \n103\nB of the respective aperture antenna assemblies \n102\nA, \n102\nB including the measurement windows (e.g., PRMWs) \n212\nA, \n212\nB, the cavity fillers \n304\nA, \n304\nB, the seals \n214\nA, \n214\nB, the metal housings (e.g., metal cavity housings) \n205\nA, \n205\nB, the conductor shields \n208\nA, \n208\nB, the elastic members \n220\nA, \n220\nB, and the retaining members \n222\nA, \n222\nB of \nFIG.', '2\n.', 'The aperture antenna assemblies \n102\nA, respectively \n102\nB, further includes the electrical RF cables with associated RF connectors \n110\nA,', 'respectively \n110\nB. Each aperture antenna assembly \n102\nA, \n102\nB may further comprise a flowmeter transmitter \n108\n, a process control system \n116\n, a computing device(s) \n114\n, and a flowmeter controller \n104\n including the microwave electronics \n106\n of \nFIGS. \n1\n and/or \n2\n.', 'Alternatively, all or part of the elements \n104\n-\n116\n may not be included in the aperture antenna assemblies.', 'Furthermore, all or part of the elements \n104\n-\n116\n may be connected to both aperture antenna assemblies \n102\nA, \n102\nB and configured to operate, communicate and/or interact with both of the aperture antenna assemblies as explained below.', 'In \nFIG. \n10\n, the microwave electronics \n106\n generate an electromagnetic signal and transmit the electromagnetic signal to the transmission radiating element \n204\nA via the electrical RF cable \n110\nA.', 'The transmission radiating element \n204\nA transmits the electromagnetic signal through the PRMW \n212\nA across the measurement plane \n226\n.', 'In some examples, the transmission radiating element \n204\nA receives a reflection of the electromagnetic signal after the electromagnetic signal reflects off a fluid in the throat section \n107\n of the vessel \n105\n near the PRMW \n212\nA.', 'The receiving radiating element \n204\nB receives the transmission of the electromagnetic signal across the throat section \n107\n of the vessel \n105\n after the electromagnetic signal travels through the associated PRMW \n212\nB.\n \nIn \nFIG.', '10\n, the radiating elements \n204\nA, \n204\nB communicate the received electromagnetic signals to the flowmeter controller \n104\n.', 'The flowmeter controller \n104\n utilizes the microwave electronics \n106\n to determine magnitude and phase data of the transmitted and reflected electromagnetic signals.', 'In some examples, the flowmeter controller \n104\n and/or the microwave electronics \n106\n determine fluid parameters such as a water-liquid ratio (WLR) and/or a gas holdup (GHU) based on the magnitude and phase data.', 'In some examples, the flowmeter controller \n104\n may transmit the determined fluid parameters, such as WLR and/or GHU data, for example, to the flowmeter transmitter \n108\n.', 'Additionally, the flowmeter transmitter \n108\n can receive a pressure, a differential pressure, a temperature of the fluid within the vessel \n105\n, measured respectively by a pressure sensor, a differential-pressure sensor, a temperature sensor (not shown).', 'In some examples, the flowmeter transmitter \n108\n may transmit the measured pressure, differential pressure, and the temperature of the fluid within the vessel \n105\n to the flowmeter controller \n104\n.', 'In some examples, the flowmeter controller \n104\n communicates, via the communication network channel (e.g., the Internet) \n112\n as shown in \nFIG.', '1\n, the magnitude and phase data, the determined fluid parameters (WLR and/or GHU), and/or the measured pressure, differential pressure, and the temperature of the fluid within the vessel \n105\n to the computing device(s) \n114\n.', 'In some examples, the computing device(s) \n114\n determine additional fluid parameters such as an oil flow rate, a gas flow rate, a water flow rate, a salinity, permittivity, and/or conductivity of the fluid within the vessel \n105\n and communicate the additional fluid parameters to the flowmeter controller \n104\n.', 'Further, the flowmeter controller \n104\n, the computing device(s) \n114\n, and/or the flowmeter transmitter \n108\n communicate determined fluid parameters to the process control system \n116\n.', 'In some examples, the flowmeter controller \n104\n generates a report including the determined fluid parameters and transmits the report to a database and/or the process control system \n116\n.', 'In some disclosed examples, the flowmeter controller \n104\n determines if the aperture antenna assembly \n102\n should adjust fluid property parameters based on the measured pressure, temperature, and/or salinity, and/or adjust a radio frequency of the electromagnetic signal based on the determined fluid parameters, such as the WLR and/or the GHU.', 'In some examples, the process control system \n116\n adjusts fluid parameters based on the determined fluid parameters.', 'For examples, the process control system \n116\n can adjust a choke valve at the surface to increase or decrease line pressure and/or a flow rate within the vessel \n105\n.', 'In the illustrated example of \nFIG. \n10\n, the pressure vessel apparatus \n103\nA, \n1036\n prevents fluid from entering the aperture antenna assembly \n102\n and, thus, protects the associated radiating element \n204\nA,', '204', 'B.', 'In some disclosed examples, to prevent fluid from entering the aperture antenna assembly, without obstructing flow within the vessel \n105\n, the PRMW \n212\nA, \n212\nB is positioned between the fluid and the radiating element \n204\nA, \n204\nB and meshes with an interior surface \n302\n of the throat section \n107\n of the vessel \n105\n.', 'In some examples, the seal \n214\nA, \n214\nB radially surrounds the associated PRMW \n212\nA, \n212\nB to ensure seal integrity when high pressures within the vessel \n105\n are encountered.', 'In some examples, the cavity filler \n304\nA, \n304\nB extends from the PRMW \n212\nA, \n212\nB away from the throat section \n107\n of the vessel \n105\n.', 'In some examples, the cavity filler \n304\nA, \n304\nB includes slots to fit the radiating element \n204\nA, \n204\nB within the cavity filler \n304\nA, \n304\nB.\n \nIn the illustrated example, the elastic member \n220\nA, \n220\nB preloads the associated PRMW \n212\nA, \n212\nB to withstand the pressure exerted by the flow of the fluid within the vessel \n105\n.', 'Specifically, the elastic member \n220\nA, \n220\nB is compressed to provide the preload and a retaining member \n222\nA, \n222\nB withstands the preload exerted by the elastic member \n220\nA, \n220\nB to retain a relative position thereof.', 'In some such examples, the elastic member \n220\nA, \n220\nB transfers the preload to the PRMW \n212\nA, \n212\nB through the conductor shield \n208\nA, \n208\nB and/or the metal housing \n205\nA, \n205\nB which contacts the cavity filler \n304\nA, \n304\nB of the PRMW \n212\nA, \n212\nB.\n \nIn the illustrated example of \nFIG.', '10\n, the metal housing \n205\nA, \n205\nB couples to an end of the associated radiating element \n204\nA, \n204\nB. Advantageously', ', the metal housing \n205\nA, \n205\nB includes slits to cause a constructive interference of the electromagnetic fields in the cavity of the metal housing including the high-permittivity cavity filler \n304\nA, \n304\nB, which allows the electromagnetic signals to attain higher transmission gain to have relative good-quality magnitude and phase measurements over a higher salinity range, and/or across a larger diameter throat section \n107\n of the vessel \n105\n.', 'In some such examples, the relative good-quality magnitude and phase measurements result from less amplitude attenuation of the electromagnetic signals and provide operators with more precise and accurate measurements than a flowmeter \n100\n using a low-permittivity cavity filler.', 'In \nFIG. \n10\n, the conductor shield \n208\nA, \n208\nB surrounds the metal housing \n205\nA, \n205\nB to provide electromagnetic shielding for the electromagnetic signals within the metal housing \n205\nA, \n205\nB.\n \nFIG.', '11\n is a block diagram of an example multiphase flowmeter system \n1100\n including the flowmeter controller \n104\n of \nFIG.', '1\n associated with the multiphase flowmeter \n100\n of \nFIG.', '1\n.', 'The multiphase flowmeter system \n1100\n includes the flowmeter transmitter \n108\n, the flowmeter controller \n104\n, the network \n112\n, the computing device(s) \n114\n, the process control system \n116\n, example signal transmitter(s) (e.g., radiating element \n204\nA) \n1102\n, example reflected signal receivers (e.g., radiating element \n204\nA) \n1104\n, and example transmitted signal receiver(s) (e.g., radiating element \n204\nB) \n1106\n.', 'The example implementation of the flowmeter controller \n104\n depicted in \nFIG.', '11\n includes an example sensor interface \n1108\n, an example signal generator \n1110\n, an example parameter determiner \n1112\n, an example report generator \n1114\n, an example command generator \n1116\n, and an example database \n1118\n including example fluid parameter(s) \n1120\n.', 'In the illustrated example of \nFIG. \n11\n, the signal generator \n1110\n can be an example implementation of the microwave sensor electronics \n106\n of \nFIG.', '1\n.', 'The signal generator \n1110\n can generate an electromagnetic signal and transmit the electromagnetic signal to the signal transmitter(s) \n1102\n via the electrical RF cables with associated RF connectors \n110\n of \nFIG.', '1\n.', 'In some examples, the signal transmitter(s) \n1102\n transmit(s) the electromagnetic signal into the throat section \n107\n of the vessel \n105\n.', 'In some such examples, the electromagnetic signal is received by the reflected signal receiver(s) \n1104\n and the transmitted signal receiver(s) \n1106\n.', 'The reflected signal receiver(s) \n1104\n and the transmitted signal receiver(s) \n1106\n communicate the received electromagnetic signals to the sensor interface \n1108\n of the flowmeter controller \n104\n.', 'In \nFIG. \n11\n, the sensor interface \n1108\n transmits the electromagnetic signals to the parameter determiner \n1112\n.', 'In the illustrated example, the parameter determiner \n1112\n can be an example implementation of the microwave sensor electronics \n106\n.', 'In some examples, the parameter determiner \n1112\n determines magnitude and phase data of the electromagnetic signals.', 'In some examples, the parameter determiner \n1112\n utilizes the determined magnitude and phase data of the electromagnetic signals to determine a water-liquid ratio (WLR) and/or a phase-fraction (e.g. gas holdup GHU) of a fluid within the vessel \n105\n.', 'Further, in some examples, the flowmeter transmitter \n108\n determines additional fluid parameters such as a flow pressure, a temperature, and/or a differential pressure of the fluid within the vessel \n105\n and communicates the fluid parameters to the flowmeter controller \n104\n.', 'In \nFIG. \n11\n, the flowmeter controller \n104\n transmits the fluid parameters determined by the parameter determiner \n1112\n and the flowmeter transmitter \n108\n to the network \n112\n.', 'In some examples, the network \n112\n communicates the determined fluid parameters to the computing device(s) \n114\n.', 'In some such examples, the computing device(s) \n114\n includes functions (e.g., algorithms, equations, etc.) that utilize the parameters determined by the flowmeter transmitter \n108\n and the flowmeter controller \n104\n to determine an oil flow rate, a gas flow rate, a water flow rate, a salinity, a permittivity, and/or a conductivity of the fluid within the vessel \n105\n.', 'In the illustrated example, the computing device(s) \n114\n communicates the determined oil flow rate, gas flow rate, water flow rate, salinity, permittivity, and/or conductivity of the fluid to the network \n112\n.', 'Additionally, the network \n112\n transmits the fluid parameters determined by the flowmeter controller \n104\n, the flowmeter transmitter \n108\n, and/or the computing device(s) \n114\n to the process control system \n116\n.', 'In some examples, the process control system \n116\n includes a data collection and distribution system that can be utilized to predict characteristics of the reservoir associated with the multiphase flowmeter system \n1100\n.', 'In some examples, the process control system \n116\n determines if the measurements by the multiphase flowmeter system \n1100\n are within a predetermined normal operating range.', 'In some examples, the process control system \n116\n adjusts a choke valve at the surface, and/or a pump speed downhole used to lift the fluid to a surface in connection with the vessel \n105\n, based on the determined fluid parameters.', 'In the illustrated example of \nFIG. \n11\n, the network \n112\n communicates the parameters determined by the computing device(s) \n114\n to the flowmeter controller \n104\n.', 'In some examples, the report generator \n1114\n generates a report including fluid properties within the vessel \n105\n determined by the parameter determiner \n1112\n, the flowmeter transmitter \n108\n, and the computing device(s) \n114\n.', 'The report generator \n1114\n communicates the report to the database \n1118\n, which stores the report with the fluid parameter(s) \n1120\n.', 'In some examples, the fluid parameter(s) \n1120\n can include parameters of the fluid within the vessel \n105\n at specific time intervals so that the productivity over time of the associated reservoir can be analyzed to evaluate system parameters, such as the economic viability, the production history matching, or the production forecast, for example, of the reservoir.', 'Additionally, the report generator \n1114\n can generate one or more user interfaces on a computer screen to provide the report to an operator.', 'In some examples, an operator can store the report from a first user interface and/or communicate a command to the command generator \n1116\n via a second user interface.', 'In the illustrated example of \nFIG. \n11\n, the report generator \n1114\n can communicate the report to the command generator \n1116\n.', 'In the illustrated example, the command generator \n1116\n determines an adjustment to the operating radio frequency of the electromagnetic signal so that accurate parameters of the fluid within the vessel \n105\n can be determined.', 'For example, the command generator \n1116\n can generate a command to the signal generator \n1110\n to generate higher frequency signals (e.g., 960 MHz) when the water-liquid ratio (WLR) is lower than a predetermined threshold (e.g., WLR<0.35).', 'Further, the signal generator \n1110\n generates an electromagnetic signal at the operating radio frequency determined by the command generator \n1116\n and transmits the electromagnetic signal to the signal transmitter(s) \n1102\n.', 'While an example manner of implementing the flowmeter controller \n104\n of \nFIGS.', '1\n, \n2\n, and/or \n11\n is illustrated in \nFIG.', '11\n, one or more of the elements, processes and/or devices illustrated in \nFIG.', '11\n may be combined, divided, re-arranged, omitted, eliminated and/or implemented in any other way.', 'Further, the example sensor interface \n1208\n, the example signal generator \n1110\n, the example parameter determiner \n1112\n, the example report generator \n1114\n, the example command generator \n1116\n, the example database \n1118\n, the example fluid parameter(s) \n1120\n and/or, more generally, the example flowmeter controller \n104\n of \nFIGS.', '1\n, \n2\n, and/or \n11\n may be implemented by hardware, software, firmware and/or any combination of hardware, software and/or firmware.', 'Thus, for example, any of the example sensor interface \n1108\n, the example signal generator \n1110\n, the example parameter determiner \n1112\n, the example report generator \n1114\n, the example command generator \n1116\n, the example database \n1118\n, the example fluid parameter(s) \n1120\n and/or, more generally, the example flowmeter controller \n104\n could be implemented by one or more analog or digital circuit(s), logic circuits, programmable processor(s), programmable controller(s), graphics processing unit(s) (GPU(s)), digital signal processor(s) (DSP(s)), application specific integrated circuit(s) (ASIC(s)), programmable logic device(s) (PLD(s)), field programmable gate array(s) (FPGA(s)) and/or field programmable logic device(s) (FPLD(s)).', 'When reading any of the apparatus or system claims of this patent to cover a purely software and/or firmware implementation, at least one of the example, sensor interface \n1108\n, the example signal generator \n1110\n, the example parameter determiner \n1112\n, the example report generator \n1114\n, the example command generator \n1116\n, the example database \n1118\n, the example fluid parameter(s) \n1120\n is/are hereby expressly defined to include a non-transitory computer readable storage device or storage disk such as a memory, a digital versatile disk (DVD), a compact disk (CD), a Blu-ray disk, etc. including the software and/or firmware.', 'Further still, the example flowmeter controller \n104\n of \nFIGS.', '1\n, \n2\n, and/or \n10\n may include one or more elements, processes and/or devices in addition to, or instead of, those illustrated in \nFIG. \n11\n, and/or may include more than one of any or all of the illustrated elements, processes and devices.', 'As used herein, the phrase “in communication,” including variations thereof, encompasses direct communication and/or indirect communication through one or more intermediary components, and does not require direct physical (e.g., wired) communication and/or constant communication, but rather additionally includes selective communication at periodic intervals, scheduled intervals, aperiodic intervals, and/or one-time events.', 'A flowchart representative of example hardware logic, machine readable instructions, hardware implemented state machines, and/or any combination thereof for implementing the example flowmeter controller \n104\n of \nFIGS.', '1\n, \n2\n, \n10\n, and/or \n11\n is shown in \nFIG. \n12\n.', 'The machine readable instructions may be one or more executable programs or portion(s) of an executable program for execution by a computer processor and/or processor circuitry, such as the processor \n1312\n shown in the example flowmeter controller \n104\n discussed below in connection with \nFIG.', '13\n.', 'The program may be embodied in software stored on a non-transitory computer readable storage medium such as a CD-ROM, a floppy disk, a hard drive, a DVD, a Blu-ray disk, or a memory associated with the processor \n1312\n, but the entire program and/or parts thereof could alternatively be executed by a device other than the processor \n1312\n and/or embodied in firmware or dedicated hardware.', 'Further, although the example program is described with reference to the flowchart illustrated in \nFIG.', '12\n, many other methods of implementing the example flowmeter controller \n104\n may alternatively be used.', 'For example, the order of execution of the blocks may be changed, and/or some of the blocks described may be changed, eliminated, or combined.', 'Additionally or alternatively, any or all of the blocks may be implemented by one or more hardware circuits (e.g., discrete and/or integrated analog and/or digital circuitry, an FPGA, an ASIC, a comparator, an operational-amplifier (op-amp), a logic circuit, etc.) structured to perform the corresponding operation without executing software or firmware.', 'The processor circuitry may be distributed in different network locations and/or local to one or more devices (e.g., a multi-core processor in a single machine, multiple processors distributed across a server rack, etc.).', 'The machine readable instructions described herein may be stored in one or more of a compressed format, an encrypted format, a fragmented format, a compiled format, an executable format, a packaged format, etc.', 'Machine readable instructions as described herein may be stored as data or a data structure (e.g., portions of instructions, code, representations of code, etc.) that may be utilized to create, manufacture, and/or produce machine executable instructions.', 'For example, the machine readable instructions may be fragmented and stored on one or more storage devices and/or computing devices (e.g., servers) located at the same or different locations of a network or collection of networks (e.g., in the cloud, in edge devices, etc.).', 'The machine readable instructions may require one or more of installation, modification, adaptation, updating, combining, supplementing, configuring, decryption, decompression, unpacking, distribution, reassignment, compilation, etc. in order to make them directly readable, interpretable, and/or executable by a computing device and/or other machine.', 'For example, the machine readable instructions may be stored in multiple parts, which are individually compressed, encrypted, and stored on separate computing devices, wherein the parts when decrypted, decompressed, and combined form a set of executable instructions that implement one or more functions that may together form a program such as that described herein.', 'In another example, the machine readable instructions may be stored in a state in which they may be read by processor circuitry, but require addition of a library (e.g., a dynamic link library (DLL)), a software development kit (SDK), an application programming interface (API), etc.', 'in order to execute the instructions on a particular computing device or other device.', 'In another example, the machine readable instructions may need to be configured (e.g., settings stored, data input, network addresses recorded, etc.)', 'before the machine readable instructions and/or the corresponding program(s) can be executed in whole or in part.', 'Thus, machine readable media, as used herein, may include machine readable instructions and/or program(s) regardless of the particular format or state of the machine readable instructions and/or program(s) when stored or otherwise at rest or in transit.', 'The machine readable instructions described herein can be represented by any past, present, or future instruction language, scripting language, programming language, etc.', 'For example, the machine readable instructions may be represented using any of the following languages: C, C++, Java, C#, Perl, Python, JavaScript, HyperText Markup Language (HTML), Structured Query Language (SQL), Swift, etc.', 'As mentioned above, the example process of \nFIG.', '12\n may be implemented using executable instructions (e.g., computer and/or machine readable instructions) stored on a non-transitory computer and/or machine readable medium such as a hard disk drive, a flash memory, a read-only memory, a compact disk, a digital versatile disk, a cache, a random-access memory and/or any other storage device or storage disk in which information is stored for any duration (e.g., for extended time periods, permanently, for brief instances, for temporarily buffering, and/or for caching of the information).', 'As used herein, the term non-transitory computer readable medium is expressly defined to include any type of computer readable storage device and/or storage disk and to exclude propagating signals and to exclude transmission media.', '“Including” and “comprising” (and all forms and tenses thereof) are used herein to be open ended terms.', 'Thus, whenever a claim employs any form of “include” or “comprise” (e.g., comprises, includes, comprising, including, having, etc.) as a preamble or within a claim recitation of any kind, it is to be understood that additional elements, terms, etc. may be present without falling outside the scope of the corresponding claim or recitation.', 'As used herein, when the phrase “at least” is used as the transition term in, for example, a preamble of a claim, it is open-ended in the same manner as the term “comprising” and “including” are open ended.', 'The term “and/or” when used, for example, in a form such as A, B, and/or C refers to any combination or subset of A, B, C such as (1) A alone, (2) B alone, (3) C alone, (4) A with B, (5) A with C, (6) B with C, and (7) A with B and with C. As used herein in the context of describing structures, components, items, objects and/or things, the phrase “at least one of A and B” is intended to refer to implementations including any of (1) at least one A, (2) at least one B, and (3) at least one A and at least one B. Similarly, as used herein in the context of describing structures, components, items, objects and/or things, the phrase “at least one of A or B” is intended to refer to implementations including any of (1) at least one A, (2) at least one B, and (3) at least one A and at least one B.', 'As used herein in the context of describing the performance or execution of processes, instructions, actions, activities and/or steps, the phrase “at least one of A and B” is intended to refer to implementations including any of (1) at least one A, (2) at least one B, and (3) at least one A and at least one B. Similarly, as used herein in the context of describing the performance or execution of processes, instructions, actions, activities and/or steps, the phrase “at least one of A or B” is intended to refer to implementations including any of (1) at least one A, (2) at least one B, and (3) at least one A and at least one B.\n \nAs used herein, singular references (e.g., “a”, “an”, “first”, “second”, etc.) do not exclude a plurality.', 'The term “a” or “an” entity, as used herein, refers to one or more of that entity.', 'The terms “a” (or “an”), “one or more”, and “at least one” can be used interchangeably herein.', 'Furthermore, although individually listed, a plurality of means, elements or method actions may be implemented by, e.g., a single unit or processor.', 'Additionally, although individual features may be included in different examples or claims, these may possibly be combined, and the inclusion in different examples or claims does not imply that a combination of features is not feasible and/or advantageous.\n \nFIG.', '12\n is a flowchart representative of example machine-readable instructions \n1200\n that can be executed to implement the flowmeter controller \n104\n of \nFIGS.', '1\n, \n2\n, \n10\n, and/or \n11\n to determine physical properties of a multiphase fluid in the vessel \n105\n of \nFIGS.', '1\n and/or \n2\n.', 'At block \n1202\n, the flowmeter controller \n104\n selects a frequency of interest to the process.', 'For example, the command generator \n1116\n (\nFIG.', '11\n) can communicate the frequency to the RF signal generator \n1110\n (\nFIG. \n11\n) of the flowmeter controller \n104\n.', 'In some examples, the frequency of interest to the process is based on fluid parameters determined by previous measurements.', 'At block \n1204\n, the flowmeter controller \n104\n transmits the electromagnetic signal through the fluid in the throat section \n107\n of the vessel \n105\n based on the selected frequency.', 'For example, the signal generator \n1110\n (\nFIG.', '11\n) can generate the electromagnetic signal to be transmitted based on the selected frequency.', 'In such examples, the signal generator \n1110\n transmits, via the electrical RF cable(s) with associated RF connector(s) \n110\n (\nFIG.', '10\n), the electromagnetic signal to the signal transmitter(s) (e.g., radiating element \n204\nA) \n1102\n (\nFIG.', '11\n).', 'In some such examples, the signal transmitter(s) \n1102\n then transmits the signal through the fluid in the throat section \n107\n of the vessel \n105\n.', 'At block \n1206\n, the flowmeter controller \n104\n receives a reflected signal from the first radiating element \n204\nA (\nFIG. \n10\n).', 'For example, the reflected signal receiver(s) \n1104\n (\nFIG.', '11\n)', '(e.g., radiating element \n204\nA) receive the electromagnetic signal after it reflects off a fluid near the reflected signal receiver(s) \n1104\n.', 'In some such examples, the reflected signal receiver(s) \n1104\n can communicate the reflected signal to the sensor interface \n1108\n of the flowmeter controller \n104\n.', 'Specifically, the first radiating element \n204\nA can transmit the signal received from the signal generator \n1110\n and receive a reflection signal after the electromagnetic signal reflects off a fluid in the throat section \n107\n of the vessel \n105\n near the PRMW \n212\n associated with the first radiating element \n204\nA.', 'At block \n1208\n, the flowmeter controller \n104\n receives a transmitted signal from the second radiating element \n204\nB (\nFIG. \n10\n).', 'For example, the transmitted signal receiver(s) \n1106\n (\nFIG. \n11\n) (e.g., radiating element \n204\nB) receive the electromagnetic signal after the electromagnetic signal is transmitted across the throat section \n107\n of the vessel \n105\n.', 'In some such examples, the transmitted signal receiver(s) \n1106\n provide the electromagnetic signal to the sensor interface \n1108\n of the flowmeter controller \n104\n.', 'Specifically, the second radiating element \n204\nB is positioned across the throat section \n107\n of the vessel \n105\n from the first radiating element \n204\nA to receive the electromagnetic signal transmitted by the first radiating element', '204\nA after it travels through the fluid in the throat section \n107\n of the vessel \n105\n.', 'At block \n1210\n, the flowmeter controller \n104\n determines magnitude and phase data of the reflected electromagnetic signal.', 'For example, the sensor interface \n1108\n can communicate the reflected electromagnetic signal to the parameter determiner \n1112\n (\nFIG. \n11\n), which processes the reflected electromagnetic signal to determine the magnitude and phase data.', 'In some examples, microwave sensor electronics \n106\n (\nFIG.', '10\n) process the reflected electromagnetic signal to determine the magnitude and phase data.', 'At block \n1212\n, the flowmeter controller \n104\n determines magnitude and phase data of the transmitted electromagnetic signal.', 'For example, the sensor interface \n1108\n can communicate the transmitted electromagnetic signal to the parameter determiner \n1112\n.', 'In some such examples, the parameter determiner \n1112\n can process the transmitted electromagnetic signal received to determine the magnitude and phase data.', 'In some examples, microwave sensor electronics \n106\n process the transmitted electromagnetic signal to determine the magnitude and phase data.', 'At block \n1214\n, the flowmeter controller \n104\n determines a water-liquid ratio, salinity, permittivity, and conductivity based on the magnitude and phase data.', 'For example, the parameter determiner \n1112\n utilizes the magnitude and phase data of the reflected electromagnetic signal to determine a water-liquid ratio.', 'The flowmeter transmitter \n108\n (\nFIGS.', '10\n and \n11\n) communicates the flow pressure, temperature, and differential pressure measured by a pressure sensor, a temperature sensor, and a differential pressure sensor respectively, to the flowmeter controller \n104\n.', 'In some examples, the flowmeter controller \n104\n provides the measurements from the flowmeter transmitter \n108\n and the parameter determiner \n1112\n to the computing device(s) \n114\n (\nFIGS. \n10\n and \n11\n) through the network \n112\n (\nFIG. \n11\n).', 'In some such examples, the computing device(s) \n114\n determines the salinity, permittivity, conductivity, and flow rate of the fluid within the vessel \n105\n based on the magnitude, phase, flow pressure, temperature, and/or differential pressure parameters.', 'Alternatively, in some examples, the parameter determiner \n1112\n utilizes the measurements from the flowmeter transmitter \n108\n to determine the salinity, permittivity, and conductivity, and flow rate of the fluid within the vessel \n105\n.', 'At block \n1216\n, the flowmeter controller \n104\n determines a phase-fraction (e.g., a gas holdup), and a water-liquid ratio based on the magnitude and phase data from two or more radiating elements (e.g., reflected signal receivers \n1104\n, transmitted signal receivers \n1106\n) \n204\n.', 'For example, the parameter determiner \n1112\n utilizes the determined magnitude and phase data for further analysis and determines the phase-fraction and water-liquid ratio of the fluid in the vessel \n105\n.', 'In some examples, the microwave sensor electronics \n106\n determine the water-liquid ratio and phase-fraction based on the magnitude and phase data.', 'At block \n1218\n, the flowmeter controller \n104\n generates and transmits a report to the database \n1118\n (\nFIG.', '11\n).', 'For example, the parameter determiner \n1112\n, the flowmeter transmitter \n108\n, and/or the computing device(s) \n114\n provide determined properties of the fluid within the vessel \n105\n to the report generator \n1114\n (\nFIG. \n11\n) of the flowmeter controller \n104\n.', 'Specifically, the report generator \n1114\n generates a report including the determined properties of the fluid and transmits the report to a database \n1118\n.', 'In some examples, the report generator \n1114\n transmits the report to the process control system \n116\n (\nFIGS.', '10\n and \n11\n).', 'At block \n1220\n, the flowmeter controller \n104\n adjusts fluid parameter(s) based on the report.', 'For example, the report generator \n1114\n provides the report to the command generator \n1116\n (\nFIG. \n11\n).', 'In some such examples, the command generator \n1116\n can transmit a command to the process control system \n116\n based on the determined water-liquid ratio.', 'Further, the process control system \n116\n can adjust a choke valve at the surface to control the flow rate and/or gas volume fraction within the vessel \n105\n based on the measured flow properties.', 'In some examples, the process control system \n116\n can adjust a reservoir water-injection strategy to enhance oil recovery based on the measured flow parameters (e.g., changes in water salinity, changes in WLR) of the multiphase fluid of one or more production wells monitored by flowmeter(s).', 'In some examples, the process control system \n116\n can optimize the production of a well implemented with an artificial lift system and monitored by a flowmeter, by reducing the gas volume fraction experienced by a downhole electric submersible pump, by adjusting the pump operating speed, and/or adjusting the opening of a gas-lift valve.', 'In some examples, the process control system \n116\n may help shut or abandon the well if the well WLR is excessively high and, thus the well has no economic value to continue the production.', 'At block \n1222\n, the machine-readable instruction \n1200\n may be repeated if a long measurement duration is needed.', 'If the long measurement duration is needed, the machine-readable instructions \n1200\n return to block \n1202\n, otherwise the machine-readable instructions continue to block \n1224\n.', 'At block \n1224\n, the flowmeter controller \n104\n determines whether there is another electromagnetic frequency of interest to the process.', 'If there is another frequency of interest to the process, the machine-readable instructions \n1200\n return to block \n1202\n.', 'For example, the flowmeter controller \n104\n compares the determined water-liquid ratio to a threshold to determine if there is another frequency electromagnetic signal of interest to the process.', 'If there is no other frequency of interest to the process, the machine-readable instruction \n1200\n end.', 'For example, if the determined fluid parameters remain relatively consistent after multiple frequencies of the electromagnetic signal have been transmitted, the flowmeter controller \n104\n determines that the fluid within the vessel is in a steady state no further electromagnetic signals are to be transmitted at that time.\n \nFIG.', '13\n is a block diagram of an example processor platform \n1300\n structured to execute the instructions of \nFIG.', '12\n to implement the flowmeter controller \n104\n of \nFIGS.', '1\n, \n2\n, \n10\n, and/or \n11\n.', 'The processor platform \n1300\n can be, for example, a server, a personal computer, a workstation, a self-learning machine (e.g., a neural network), a mobile device (e.g., a cell phone, a smart phone, a tablet such as an iPad™), a headset or other wearable device, or any other type of computing device.', 'The processor platform \n1300\n of the illustrated example includes a processor \n1312\n.', 'The processor \n1312\n of the illustrated example is hardware.', 'For example, the processor \n1312\n can be implemented by one or more integrated circuits, logic circuits, microprocessors, GPUs, DSPs, or controllers from any desired family or manufacturer.', 'The hardware processor may be a semiconductor based (e.g., silicon based) device.', 'In this example, the processor implements the example signal generator \n1110\n, the example parameter determiner \n1112\n, the example command generator \n1116\n, and the example report generator \n1114\n of \nFIG.', '11\n.', 'The processor \n1312\n of the illustrated example includes a local memory \n1313\n (e.g., a cache).', 'The processor \n1312\n of the illustrated example is in communication with a main memory including a volatile memory \n1314\n and a non-volatile memory \n1316\n via a bus \n1318\n.', 'The volatile memory \n1314\n may be implemented by Synchronous Dynamic Random Access Memory (SDRAM), Dynamic Random Access Memory (DRAM), RAMBUS® Dynamic Random Access Memory (RDRAM®) and/or any other type of random access memory device.', 'The non-volatile memory \n1316\n may be implemented by flash memory and/or any other desired type of memory device.', 'Access to the main memory \n1314\n, \n1316\n is controlled by a memory controller.', 'The processor platform \n1300\n of the illustrated example also includes an interface circuit \n1320\n.', 'The interface circuit \n1320\n may be implemented by any type of interface standard, such as an Ethernet interface, a universal serial bus (USB), a Bluetooth® interface, a near field communication (NFC) interface, and/or a PCI express interface.', 'In the illustrated example, the interface circuit \n1320\n implements the example sensor interface \n1108\n of \nFIG.', '11\n.', 'In the illustrated example, one or more input devices \n1322\n are connected to the interface circuit \n1320\n.', 'The input device(s) \n1322\n permit(s) a user to enter data and/or commands into the processor \n1312\n.', 'The input device(s) can be implemented by, for example, an audio sensor, a microphone, a camera (still or video), a keyboard, a button, a mouse, a touchscreen, a track-pad, a trackball, isopoint and/or a voice recognition system.', 'In the illustrated example, the input devices \n1322\n implements the microwave sensor electronics \n106\n of \nFIG.', '1\n.', 'One or more output devices \n1324\n are also connected to the interface circuit \n1320\n of the illustrated example.', 'The output devices \n1324\n can be implemented, for example, by display devices (e.g., a light emitting diode (LED), an organic light emitting diode (OLED), a liquid crystal display (LCD), a cathode ray tube display (CRT), an in-place switching (IPS) display, a touchscreen, etc.), a tactile output device, a printer and/or speaker.', 'In the illustrated example, the output devices \n1324\n include the microwave sensor electronics \n106\n, flowmeter transmitter \n108\n.', 'The interface circuit \n1320\n of the illustrated example, thus, typically includes a graphics driver card, a graphics driver chip and/or a graphics driver processor.', 'The interface circuit \n1320\n of the illustrated example also includes a communication device such as the sensor interface \n1108\n, a transmitter, a receiver, a transceiver, a modem, a residential gateway, a wireless access point, and/or a network interface to facilitate exchange of data with external machines (e.g., computing devices of any kind) via a network \n112\n.', 'The communication can be via, for example, an Ethernet connection, a digital subscriber line (DSL) connection, a telephone line connection, a coaxial cable system, a satellite system, a line-of-site wireless system, a cellular telephone system, etc.', 'In this example, the network \n112\n facilitates communication between the computing device(s) \n114\n and the process control system \n116\n of \nFIG.', '1\n with the processor platform \n1300\n of \nFIG.', '13\n.', 'The processor platform \n1300\n of the illustrated example also includes one or more mass storage devices \n1328\n for storing software and/or data.', 'Examples of such mass storage devices \n1328\n include floppy disk drives, hard drive disks, compact disk drives, Blu-ray disk drives, redundant array of independent disks (RAID) systems, and digital versatile disk (DVD) drives.', 'In the illustrated example, the mass storage device \n1328\n implements the database \n1118\n and the associated fluid parameter(s) \n1120\n of \nFIG.', '11\n.', 'The machine executable instructions \n1200\n of \nFIG.', '12\n may be stored in the mass storage device \n1328\n, in the volatile memory \n1314\n, in the non-volatile memory \n1316\n, and/or on a removable non-transitory computer readable storage medium such as a CD or DVD.', 'From the foregoing, it will be appreciated that the above disclosed methods, apparatus and articles of manufacture relate to example multiphase flowmeters that may be used in any suitable situation such as, for example, subsea operations, topside operations, land-based operations, offshore-platform operations, etc.', 'In some examples, the multiphase flowmeters disclosed herein may be used to measure phase flow rate, phase fraction, pressure, and temperature when the example flowmeters are disposed such that the fluid flows vertically, horizontally, and/or in an inclined manner in which gravity acts substantially asymmetrically on the flow sections, inlet manifold and/or outlet manifold of the multiphase flowmeter.', 'In some examples, the aperture antenna assemblies of the multiphase flowmeters and associated pressure vessel apparatuses disclosed herein may be used to measure phase fraction, pressure, and temperature of fluids without a Venturi throat section (e.g. may be used at a full-bore, uniform diameter, vessel \n105\n).', 'In the specification and appended claims: the terms “connect,” “connection,” “connected,” “in connection with,” and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements;” and the term “set” is used to mean “one element” or “more than one element.”', 'Further, the terms “couple,” “coupling,” “coupled,” “coupled together,” and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements.”', 'As used herein, the terms “up” and “down,” “upper” and “lower,” “upwardly” and downwardly,” “upstream” and “downstream;” “above” and “below;” and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure.', 'The foregoing outlines features of several embodiments so that those skilled in the art may better understand aspects of the present disclosure.', 'Those skilled in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes or achieving the same advantages of the embodiments introduced herein.', 'Those skilled in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions, and alterations herein without departing from the spirit and scope of the present disclosure.', 'Example methods, apparatus, systems, and articles of manufacture to perform flowmeter aperture antenna transmission and pressure retention are disclosed herein.', 'Further examples and combinations thereof include the following:\n \nExample 1 includes an aperture antenna assembly of a multiphase flowmeter to measure properties of a fluid in a vessel, the aperture antenna assembly comprising at least one radiating element to transmit or receive an electromagnetic signal along at least one measurement plane orthogonal to a direction of flow of the fluid in the vessel, and a pressure retaining member to prevent the fluid from entering the aperture antenna assembly through a measurement window of the aperture antenna assembly.', 'At least a portion of the pressure retaining member separates the radiating element and the fluid.', 'The aperture antenna assembly also includes a metal housing (with or without slits), the pressure retaining member being at least partially within the metal housing, and the radiating element being coupled to the metal housing.', 'Example 2 includes the aperture antenna assembly of example 1, wherein the metal housing is coupled to an exterior surface of the vessel by the pressure retaining member.', 'Example 3 includes the aperture antenna assembly of example 1, wherein the pressure retaining member includes at least one of a low-loss dielectric material or a substantially high dielectric constant material.', 'Such material may substantially improve a transmission gain of the electromagnetic signal transmitted or received by the radiating element.', 'Example 4 includes the aperture antenna assembly of example 3, wherein the low-loss dielectric material is polyether ether ketone.', 'Example 5 includes the aperture antenna assembly of example 1, wherein the pressure retaining member includes a high mechanical-strength ceramic material.', 'Such material may improve a pressure-rating and a temperature-rating of the measurement window.', 'Example 6 includes the aperture antenna assembly of example 1, further including a controller to determine fluid properties of the fluid in response to the at least one radiating element receiving the electromagnetic signals.', 'Example 7 includes the aperture antenna assembly of example 1, wherein the at least one radiating element comprises a first and a second radiating elements.', 'The second radiating element may be positioned within the metal housing behind the first radiating element and orthogonally aligned with the first radiating element.', 'Example 8 includes the aperture antenna assembly of example 1, wherein a material of the radiating element includes at least one of beryllium copper, bronze, or brass.', 'Example 9 includes the aperture antenna assembly of example 8, wherein an exterior surface of the radiating element includes a gold plating.', 'Example 10 includes the aperture antenna assembly of example 1, wherein the metal housing is a metal housing with slits, the metal housing with slits including a first section, a second section, and a third section.', 'The second section may be positioned between the first section and the third section, the first section and the third section may be coupled to an exterior surface of the vessel, the second section may be coupled to the first section and the third section, and respective first ends of the first radiating element and the second radiating element may be coupled to the second section.', 'Example 11 includes the aperture antenna assembly of example 10, further including an electrical coaxial connector coupled to a second end of the radiating element.', 'The electrical coaxial connector may be positioned within the second section of the metal housing.', 'Example 12 includes the aperture antenna assembly of example 11, wherein the electrical coaxial connector is removably coupled to the metal housing via a flange-mount and screws, the second section of the metal housing is removable via uncoupling the electrical coaxial connector from the metal housing.', 'Example 13 includes the aperture antenna assembly of example 10, wherein the slits include a first set of slits, the first set of slits including a first gap disposed between the first section and the second section and a second gap disposed between the second section and the third section.', 'The first gaps and the second gaps may be positioned substantially parallel to the radiating element.', 'Example 14 includes the aperture antenna assembly of example 13, wherein the slits include a second set of slits that extend at least partially through the first section and the third section, ones of the second set of slits being substantially orthogonal to the radiating element.', 'Example 15 includes the aperture antenna assembly of example 10, wherein the slits are configured to enhance a transmission gain of the electromagnetic signal via a constructive interference of electromagnetic fields inside the metal housing.', 'Example 16 includes the aperture antenna assembly of example 14, wherein respective ones of the first gaps and the second gaps of the first set of slits have a first width in a range of 0.5 to 2.0 millimeters and respective ones of the second set of slits have a width in a range of 0.5 to 2.0 millimeters.', 'Example 17 includes the aperture antenna assembly of example 1, further including electrical conductor shims disposed between the metal housing and the vessel or at least partially between the pressure retaining member and the vessel to provide electrical shielding among the first radiating element and the second radiating element.', 'Example 18 includes a multiphase flowmeter with a plurality of aperture antenna assemblies to measure properties of a fluid in a vessel, comprising a first aperture antenna assembly according to example 1 (or any of the examples 2-19), wherein the at least one radiating element of the first aperture antenna is at least one first radiating element.', 'The multiphase flowmeter also includes a second aperture antenna assembly according to example 1 (or any of the examples 2-20), wherein the at least one radiating element of the second aperture antenna is at least one second radiating element.', 'The first aperture antenna assembly is coupled to a first side of the vessel and the second aperture antenna assembly is coupled to a second side of the vessel.', 'The at least one second radiating element includes one or more radiating elements respectively having one or more angular displacements with respect to the at least one first radiating element.', 'The at least one first radiating element is configured to transmit an electromagnetic signal through the fluid, the at least one second radiating element is configured to receive the electromagnetic signal, and the at least one first radiating element is configured to receive at least a portion of the electromagnetic signal reflected by the fluid in the vessel.', 'Example 19 includes a pressure vessel apparatus of a multiphase flowmeter comprising a pressure retaining measurement window having an outer face and a shoulder, the outer face flush with an interior wall of a vessel, the outer face to be in fluid communication with a fluid included in the vessel, a seal to radially surround the shoulder of the pressure retaining measurement window, wherein the shoulder is substantially orthogonal to the outer face, an elastic member to provide a resistance force to the pressure retaining measurement window to counteract a fluid pressure within the vessel, a metal housing coupled between the pressure retaining measurement window and the elastic member, and a retaining member coupled to a side of the elastic member opposite the metal housing, the retaining member to maintain a relative position of the elastic member.', 'Example 20 includes the pressure vessel apparatus of example 19, wherein the elastic member is a Belleville washer.', 'Example 21 includes the pressure vessel apparatus of example 19, wherein the elastic member is preloaded to provide the resistance force.', 'Example 22 includes the pressure vessel apparatus of example 21, wherein the elastic member is preloaded with a bolt to be screwed into an opening of the metal housing or a body of the vessel, the bolt to be removed from the pressure vessel apparatus subsequent to applying the preload.', 'Example 23 includes the pressure vessel apparatus of example 19, wherein the retaining member is a retaining ring and the seal is an O-ring.', 'Example 24 includes the pressure vessel apparatus of example 19, wherein the pressure retaining measurement window includes a cavity filler at least partially extending from an inner face of the pressure retaining measurement window positioned opposite the outer face.', 'Example 25 includes the pressure vessel apparatus of example 19, wherein the pressure retaining measurement window and cavity filler include at least one of a low-loss dielectric material or a substantially high dielectric constant material.', 'Example 26 includes the pressure vessel apparatus of example 19, wherein the low-loss dielectric material includes polyether ether ketone.', 'Example 27 includes the pressure vessel apparatus of example 19, wherein the low-loss dielectric material and the substantially high dielectric constant material includes aluminum oxide.', 'Example 28 includes the pressure vessel apparatus of example 19, wherein the substantially high dielectric constant material of the cavity filler at least partially includes titanium dioxide.', 'Example 29 includes the pressure vessel apparatus of example 19, wherein the pressure retaining measurement window includes a high mechanical-strength ceramic material to improve a pressure-rating and a temperature-rating of the measurement window.']

['1.', 'An aperture antenna assembly of a multiphase flowmeter to measure properties of a fluid in a vessel, the aperture antenna assembly comprising:\nat least one radiating element to transmit or receive an electromagnetic signal along at least one measurement plane orthogonal to a direction of flow of the fluid in the vessel;\na pressure retaining member to prevent the fluid from entering the aperture antenna assembly through a measurement window of the aperture antenna assembly, wherein at least a portion of the pressure retaining member separates the radiating element and the fluid, wherein the pressure retaining member includes at least one of a low-loss dielectric material or a substantially high dielectric constant material; and\na metal housing, the pressure retaining member being at least partially within the metal housing, the radiating element being coupled to the metal housing.', '2.', 'The aperture antenna assembly of claim 1, wherein the metal housing is coupled to an exterior surface of the vessel by the pressure retaining member.', '3.', 'The aperture antenna assembly of claim 1, wherein the low-loss dielectric material is polyether ether ketone.', '4.', 'The aperture antenna assembly of claim 1, wherein the pressure retaining member includes a high mechanical-strength ceramic material.', '5.', 'The aperture antenna assembly of claim 1, further including a controller to determine fluid properties of the fluid in response to the at least one radiating element receiving the electromagnetic signals.', '6.', 'The aperture antenna assembly of claim 1, wherein the at least one radiating element comprises a first and a second radiating elements, wherein the second radiating element is positioned within the metal housing behind the first radiating element and orthogonally aligned with the first radiating element.', '7.', 'The aperture antenna assembly of claim 1, wherein the metal housing is a metal housing with slits, the metal housing with slits including a first section, a second section, and a third section, wherein the second section is positioned between the first section and the third section, wherein the first section and the third section are coupled to an exterior surface of the vessel, wherein the second section is coupled to the first section and the third section, and wherein a first end of the at least one radiating element is coupled to the second section.', '8.', 'The aperture antenna assembly of claim 7, further including an electrical coaxial connector coupled to a second end of the at least one radiating element, wherein the electrical coaxial connector is positioned within the second section of the metal housing.', '9.', 'The aperture antenna assembly of claim 7, wherein the slits include a first set of slits, the first set of slits including a first gap disposed between the first section and the second section and a second gap disposed between the second section and the third section, the first gaps and the second gaps being positioned substantially parallel to the radiating element.', '10.', 'The aperture antenna assembly of claim 9, wherein the slits include a second set of slits that extend at least partially through the first section and the third section, ones of the second set of slits being substantially orthogonal to the radiating element.', '11.', 'The aperture antenna assembly of claim 10, wherein respective ones of the first gaps and the second gaps of the first set of slits have a first width in a range of 0.5 to 2.0 millimeters and respective ones of the second set of slits have a width in a range of 0.5 to 2.0 millimeters.', '12.', 'The aperture antenna assembly of claim 1, further including electrical conductor shims disposed between the metal housing and the vessel or at least partially between the pressure retaining member and the vessel.', '13.', 'An aperture antenna assembly of a multiphase flowmeter to measure properties of a fluid in a vessel, the aperture antenna assembly comprising:\nat least one radiating element to transmit or receive an electromagnetic signal along at least one measurement plane orthogonal to a direction of flow of the fluid in the vessel wherein the at least one radiating element comprises a first and a second radiating elements, wherein the second radiating element is positioned within the metal housing behind the first radiating element and orthogonally aligned with the first radiating element;\na pressure retaining member to prevent the fluid from entering the aperture antenna assembly through a measurement window of the aperture antenna assembly, wherein at least a portion of the pressure retaining member separates the radiating element and the fluid; and\na metal housing, the pressure retaining member being at least partially within the metal housing, the radiating element being coupled to the metal housing.', '14.', 'An aperture antenna assembly of a multiphase flowmeter to measure properties of a fluid in a vessel, the aperture antenna assembly comprising:\nat least one radiating element to transmit or receive an electromagnetic signal along at least one measurement plane orthogonal to a direction of flow of the fluid in the vessel;\na pressure retaining member to prevent the fluid from entering the aperture antenna assembly through a measurement window of the aperture antenna assembly, wherein at least a portion of the pressure retaining member separates the radiating element and the fluid; and\na metal housing, the pressure retaining member being at least partially within the metal housing, the radiating element being coupled to the metal housing, wherein the metal housing is a metal housing with slits, the metal housing with slits including a first section, a second section, and a third section, wherein the second section is positioned between the first section and the third section, wherein the first section and the third section are coupled to an exterior surface of the vessel, wherein the second section is coupled to the first section and the third section, and wherein a first end of the at least one radiating element is coupled to the second section.', '15.', 'The aperture antenna assembly of claim 14, further including an electrical coaxial connector coupled to a second end of the at least one radiating element, wherein the electrical coaxial connector is positioned within the second section of the metal housing.', '16.', 'The aperture antenna assembly of claim 15, wherein the slits include a first set of slits, the first set of slits including a first gap disposed between the first section and the second section and a second gap disposed between the second section and the third section, the first gaps and the second gaps being positioned substantially parallel to the radiating element.', '17.', 'The aperture antenna assembly of claim 16, wherein the slits include a second set of slits that extend at least partially through the first section and the third section, ones of the second set of slits being substantially orthogonal to the radiating element.']

['FIG. 1 illustrates an example multiphase flowmeter with a first example aperture antenna assembly with a first example pressure vessel apparatus coupled to an example vessel, and an example flowmeter controller.; FIG.', '2 illustrates another view of the first example aperture antenna assembly of FIG.', '1 and the first example pressure vessel apparatus of the example multiphase flowmeter of FIG.', '1.; FIG. 3 illustrates an example cross-section of a simplified representation of the first example aperture antenna assembly of FIGS.', '1 and/or 2.; FIG.', '4A illustrates a first example metal housing with cross-cut slits of the aperture antenna assembly of FIGS.', '1, 2, and/or 3.; FIG.', '4B illustrates a second example metal housing without slits of the aperture antenna assembly of FIGS.', '1, 2, and/or 3.; FIG.', '5 illustrates an example midsection of the second example metal housing with cross-cut slits of FIG.', '4A.; FIG.', '6 illustrates a simplified cross-section of an example pressure vessel apparatus of the aperture antenna assembly of FIGS. 1 and/or 2.; FIG.', '7 illustrates a second example pressure vessel apparatus of the aperture antenna assembly implemented on the edge of a vessel of FIGS. 1 and/or 2.; FIGS.', '8A-8D illustrate an example process to preload an example pressure vessel apparatus.; FIG.', '9 illustrates an example pressure retaining measurement window that may be included in the example aperture antenna assembly of FIGS.', '1, 2, and/or 3 and the example pressure vessel apparatus of FIGS.', '1, 2, 6, 7, and/or 8.; FIG.', '10 is a block diagram of an example implementation of an aperture antenna assembly on the example vessel of FIGS. 1 and/or 2.; FIG.', '11 is a block diagram of an example flowmeter controller associated with the example aperture antenna assembly of FIGS. 1 and/or 2.; FIG.', '12 is a flowchart representative of example machine-readable instructions that may be executed to implement the flowmeter controller of FIGS.', '1, 2, and/or 11 to determine physical properties of a multiphase fluid in the example vessel of FIGS.', '1 and/or 2.; FIG.', '13 is a block diagram of an example processing platform structured to execute the example machine-readable instructions of FIG.', '12 to implement the flowmeter controller of FIGS.', '1, 2, and/or 11.; FIG.', '1 illustrates an example multiphase flowmeter 100 with a first example aperture antenna assembly 102 coupled to an example throat section 107 of an example vessel 105.', 'The example aperture antenna assembly 102 includes a first example pressure vessel apparatus 103 located at the venturi throat section 107 of the vessel 105 described in further detail in connection with FIG.', '2.', 'The aperture antenna assembly 102 includes an example flowmeter controller 104 including example microwave sensor electronics 106, an example flowmeter transmitter 108, example electrical RF coaxial cables (e.g., RF coaxial cables and associated RF coaxial connectors) 110 with RF coaxial connectors, an example network 112, an example computing device(s) 114, and an example process control system 116.', 'In FIG.', '1, radiating elements of the aperture antenna assembly 102 transmit and receive electromagnetic signals (e.g., radio frequency waves) across the throat section 107 of the vessel 105 as a multiphase fluid from a reservoir flows through the vessel 105.', 'In some examples, a first radiating element transmits the electromagnetic signal through the throat section 107 of the vessel 105 and receives a reflection signal after the fluid in the vessel reflects the signal.', 'Additionally, a second radiating element receives a transmission signal after the electromagnetic signal travels through the multiphase fluid across the throat section 107 of the vessel 105, described in further detail in connection with FIG.', '2.; FIG.', '2 illustrates another view of the first aperture antenna assembly 102 of FIG.', '1 and the first pressure vessel apparatus 103 of the multiphase flowmeter 100 positioned at the throat section 107 of the vessel 105 of FIG.', '1.', 'The aperture antenna assembly 102 includes an example ingress protection cover 217 and example RF cable glands 216 to radially surround and secure the electrical RF coaxial cables (e.g., RF coaxial cables with SubMiniature Version A (SMA) ‘male’ connectors) 110 as they couple to example SMA connectors (e.g., RF SMA ‘female’ connectors) 228.', 'Each SMA connector 228 is removably coupled to an example metal housing (e.g., a metal cavity housing) 205, which is surrounded by an example electrical conductor shield 208.', 'In some examples, the metal housing 205 acts as the electrical conductor shield 208 and provides electrical shielding to protect the electromagnetic signals from interference.', 'In other words, the metal housing 205 and conductor shield 208 are the same structure.', 'Additionally, the aperture antenna assembly 102 includes example radiating elements 204 to transmit and/or receive electromagnetic signals across an example measurement plane 226 orthogonal to a direction of flow of fluid within the throat section 107 of the vessel 105 of FIG.', '1.', 'The pressure vessel apparatus 103 of FIG.', '2 is a pressure retaining member that includes an example pressure retaining measurement window (PRMW) 212, example electrical conductor shims 213, an example seal 214, example cavity fillers 206A, 206B, the metal housing 205, an example elastic member 220, and an example retaining member 222.; FIG.', '3 illustrates an example cross-section A-A of a simplified representation of the first aperture antenna assembly 102 of FIGS. 1 and/or 2.', 'The simplified representation of the aperture antenna assembly 102 includes an example cavity filler 304 and a second example radiating element 306 in addition to the radiating element 204, the metal housing (e.g., the metal housing without any slits) 205, the pressure retaining measurement window (PRMW) 212, and the measurement plane 226 of FIG.', '2.', 'The simplified representation illustrates an example implementation of the aperture antenna of the aperture antenna assembly 102.', 'In FIG.', '3, the radiating element 204 is coupled to the metal housing 205 and the second radiating element 306 is positioned within the metal housing behind and orthogonally aligned with the radiating element 204.', 'In the illustrated example, the radiating element 204 and the second radiating element 306 form a cross-dipole antenna.', 'In some examples, the PRMW 212 functions as a dielectric window and a cavity-plug within an example interior surface 302 of the throat section 107 of the vessel 105 to provide a pressure barrier between the radiating element 204 and the flow within the vessel 105.', 'In some examples, the thickness of the illustrated PRMW 212 is at least 2 mm, but in other examples, the thickness may be less than 2 mm.', 'In the illustrated example, the cavity filler 304 at least partially extends from the PRMW 212 away from the throat section 107 of the vessel 105 and surrounds the radiating element 204 to provide insulation.', 'For example, the cavity filler 304 of FIG.', '3 can be an example implementation of at least one of the cavity filler 206A or the cavity filler 206B of FIG.', '2.', 'In the illustrated example, the radiating element 204 and the associated measurement plane 226 are substantially orthogonal to a direction of flow within the vessel 105.', 'In some examples, the aperture antenna assembly 102 can include multiple radiating elements (e.g., 3 radiating elements, 4 radiating elements, etc.), such as radiating element 204, positioned around the periphery of a measurement plane, with e.g. two receivers at appropriate angular displacements with respect to two transmitters at the measurement plane, to perform drift-free magnitude and phase-shift measurements, as disclosed in the U.S. Pat.', 'No. 8,536,883.', 'Drift-free magnitude and phase-shift measurements may be performed at multiple (e.g. two) measurement planes, and/or across two measurement planes.; FIG.', '4A illustrates a first example implementation of cross-cut slits in the metal housing 205 of the aperture antenna assembly 102 of FIGS.', '1, 2, and/or 3.', 'The first example metal housing 205 includes an example first section 404, an example second section (e.g., a middle section) 402, and an example third section 406.', 'In the illustrated example, the second section 402 is separated from the first section 404 and the third section 406 by the parallel slits 224.', 'In some examples, the second section 402 is coupled to the first section 404 and the third section 406 via a flange-mount and screws in association with the SMA connector 228, as further discussed in association with FIG.', '5.', 'In some such examples, the second section 402 and/or the metal housing 205 is supported by the cavity filler 304 inside the metal housing 205 and supported by a metal (e.g. copper tape with adhesive) shield 420 surrounding a circumference of the metal housing 205.', 'In some examples, the metal shield 420 can be an example implementation of the conductor shield 208, discussed in association with FIG.', '2.', 'The second section 402 of the metal housing 205 includes an example opening 416 that the flange-mount of the SMA connector 228 aligns with so that the electrical RF cable 110 can extend through the metal housing 205 to couple to an end of the radiating element 204.', 'In some examples, screws secure the flange-mount of the SMA connector 228 to the metal housing 205 by coupling to example threaded openings 418 of the first section 404 and the third section 406.; FIG.', '4B illustrates a second example metal housing 205 without slits on the aperture antenna assembly 102 of FIGS.', '1, 2, and/or 3.', 'In the illustrated example, the metal housing 205 includes the opening 416 that the flange-mount of the SMA connector 228 aligns with so that the electrical RF cable 110 can extend through the metal housing 205 to the radiating element 204.', 'Additionally, the metal housing 205 includes the threaded openings 418 to allow screws to couple the flange-mount of the SMA connector 228 to the metal housing 205.; FIG.', '5 illustrates an example midsection (e.g., a middle section) 500 of the second example metal housing 205 of FIG.', '4B. For example, the midsection 500 of FIG.', '5 can correspond to the second section 402 of FIG.', '4B. The midsection 500 of the metal housing 205 includes the electrical RF cable 110 coupled to an example (Male′)', 'SMA connector 502, an example flange-mount (‘female’)', 'SMA connector (e.g., an SMA connector and associated coaxial feedthrough) 503 including example threaded holes 508 for screws to couple the flange-mount SMA connector 503 to the first section 404 and the third section 406 of the metal housing 205.', 'For example, the flange-mount SMA connector 503 can correspond to the SMA connector 228 of FIGS.', '1 and/or 2.', 'The second section 402 of the metal housing 205 further includes the opening 416 to allow the coaxial feedthrough of the SMA connector 503 to couple to the radiating element 204.', 'In the illustrated example, a solder or interference-fit connection 504 couples an end of the coaxial-feedthrough of the SMA connector 503 to a first end of the radiating element 204.', 'In the illustrated example, the second section 402 includes an insulation ring 510 to insulate the connection between a center-conductor of the SMA connector 503 and the radiating element 204 from the metal housing 205.', 'In some such examples, the metal housing 205, or second section 402 thereof, is electrically connected to an outer-conductor of the SMA connectors 502, 503.', 'In some examples, a second end 506 of the radiating element 204 couples to the second section 402 of the metal housing 205, via the interference fit.', 'In the illustrated example, the electrical RF cable 110, coupled with SMA connectors 502, 503 transports electromagnetic signals between the flowmeter controller 104 and the radiating element 204.', 'In some examples, the radiating element 204 includes a gold plating on the exterior surface thereof to prevent oxidation.', '; FIG.', '6 illustrates a simplified cross-section A-A of the pressure vessel apparatus 103 of the aperture antenna assembly of FIGS. 1 and/or 2.', 'The pressure vessel apparatus 103 of FIG.', '6 includes the metal housing 205, the PRMW 212, the seal 214, the elastic member 220, the retaining member 222, and the measurement plane 226 of FIG.', '2.', 'Advantageously, the pressure vessel apparatus 103 provides a relatively compact, low-cost solution to replace the generic bolt-flange assembly that supports the PRMW 212 from displacement.', 'The pressure vessel apparatus 103 can reduce passive interference or cross-talk of the electromagnetic signals that can be caused by the bolt-flange assembly as components deteriorate (e.g., rust).', '; FIG.', '7 illustrates a second example implementation of the pressure vessel apparatus 103 of the aperture antenna assembly 102 implemented on the edge of the vessel 105 of FIGS. 1 and/or 2.', 'The example pressure vessel apparatus 103 includes the PRMW 212, the seal 214, the metal housing 205, the elastic member 220, and the retaining member 222 of FIG.', '2.', 'The pressure vessel apparatus 103 of FIG.', '7 includes the radiating element 204 of FIG.', '2 to transmit and/or receive electromagnetic signals across the measurement plane 226 of FIG.', '2.; FIGS.', '8A-8D illustrate an example process or workflow to preload the pressure vessel apparatus 103 of FIG.', '1.', 'The illustrated example includes an example bolt 802, the elastic member (e.g., a washer, a Belleville washer, etc.) 220, the retaining member (e.g., a retaining ring, a Spirolox® retaining ring, etc.) 222, the metal housing 205, the seal (e.g., an O-ring) 214, and the PRMW 212.', 'In FIG.', '8A, an operator (e.g., a machine, a machine operator, etc.) screws the bolt 802 into an opening of the metal housing 205 with the elastic member 220 radially surrounding a body of the bolt 802 above the metal housing 205.; FIG.', '9 illustrates an example implementation of the pressure retaining measurement window 212 of FIG.', '2 that can be included in the pressure vessel apparatus 103 of FIGS.', '1, 2, 6, 7, and/or 8.', 'In the illustrated example, the PRMW 212 includes an example outer face 902, an example shoulder 904, an example inner face 906, two example flanges (e.g., tabs) 908 on opposite sides of the PRMW 212, an example cavity filler 910, an example primary contact surface 912, and an example secondary contact surface 914.', 'The PRMW 212 includes a low-loss dielectric material and/or a substantially high dielectric constant (ε) material (e.g., ε=3, ε=9, etc.), such as an engineering thermoplastic PEEK, or an aluminum oxide ceramic, for example, to facilitate the transmission and reception of electromagnetic signals by a radiating element 204.; FIG.', '10 is a block diagram 1000 of an example implementation of a multiphase flow meter including a plurality of antenna aperture assemblies 102A, 102B coupled to the vessel 105 of FIGS. 1 and/or 2.', 'The illustrated example includes the measurement plane 226, a transmission radiating element 204A (of a first aperture antenna assembly 102A), a receiving radiating element 204B (of a second aperture antenna assembly 102B), and the pressure vessel apparatus 103A, 103B of the respective aperture antenna assemblies 102A, 102B including the measurement windows (e.g., PRMWs) 212A, 212B, the cavity fillers 304A, 304B, the seals 214A, 214B, the metal housings (e.g., metal cavity housings) 205A, 205B, the conductor shields 208A, 208B, the elastic members 220A, 220B, and the retaining members 222A, 222B of FIG.', '2.', 'The aperture antenna assemblies 102A, respectively 102B, further includes the electrical RF cables with associated RF connectors 110A, respectively 110B.', 'Each aperture antenna assembly 102A, 102B may further comprise a flowmeter transmitter 108, a process control system 116, a computing device(s) 114, and a flowmeter controller 104 including the microwave electronics 106 of FIGS. 1 and/or 2.', 'Alternatively, all or part of the elements 104-116 may not be included in the aperture antenna assemblies.', 'Furthermore, all or part of the elements 104-116 may be connected to both aperture antenna assemblies 102A, 102B and configured to operate, communicate and/or interact with both of the aperture antenna assemblies as explained below.; FIG.', '11 is a block diagram of an example multiphase flowmeter system 1100 including the flowmeter controller 104 of FIG.', '1 associated with the multiphase flowmeter 100 of FIG.', '1.', 'The multiphase flowmeter system 1100 includes the flowmeter transmitter 108, the flowmeter controller 104, the network 112, the computing device(s) 114, the process control system 116, example signal transmitter(s) (e.g., radiating element 204A) 1102, example reflected signal receivers (e.g., radiating element 204A) 1104, and example transmitted signal receiver(s) (e.g., radiating element 204B) 1106.', 'The example implementation of the flowmeter controller 104 depicted in FIG.', '11 includes an example sensor interface 1108, an example signal generator 1110, an example parameter determiner 1112, an example report generator 1114, an example command generator 1116, and an example database 1118 including example fluid parameter(s) 1120.;', 'FIG. 12 is a flowchart representative of example machine-readable instructions 1200 that can be executed to implement the flowmeter controller 104 of FIGS.', '1, 2, 10, and/or 11 to determine physical properties of a multiphase fluid in the vessel 105 of FIGS.', '1 and/or 2.', 'At block 1202, the flowmeter controller 104 selects a frequency of interest to the process.', 'For example, the command generator 1116 (FIG. 11) can communicate the frequency to the RF signal generator 1110 (FIG. 11) of the flowmeter controller 104.', 'In some examples, the frequency of interest to the process is based on fluid parameters determined by previous measurements.; FIG. 13 is a block diagram of an example processor platform 1300 structured to execute the instructions of FIG.', '12 to implement the flowmeter controller 104 of FIGS.', '1, 2, 10, and/or 11.', 'The processor platform 1300 can be, for example, a server, a personal computer, a workstation, a self-learning machine (e.g., a neural network), a mobile device (e.g., a cell phone, a smart phone, a tablet such as an iPad™), a headset or other wearable device, or any other type of computing device.']

US11927086

Split stream oilfield pumping systems

Jan 7, 2019

Rod Shampine, Paul Dwyer, Ronnie Stover, Mike Lloyd, Jean-Louis Pessin, Edward Kent Leugemors, Larry D. Welch, Joe Hubenschmidt, Philippe Gambier, William Troy Huey, Thomas Allan

Schlumberger Technology Corporation

NPL References not found.

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2117764; August 1998; RU; 1566046; May 1990; SU

['A method of pumping an oilfield fluid from a well surface to a wellbore is provided that includes providing a clean stream; operating one or more clean pumps to pump the clean stream from the well surface to the wellbore; providing a dirty stream including a solid material disposed in a fluid carrier; and operating one or more dirty pumps to pump the dirty stream from the well surface to the wellbore, wherein the clean stream and the dirty stream together form said oilfield fluid.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application is a continuation of U.S. patent application Ser.', 'No. 14/666,519, filed on Mar. 24, 2015, now U.S. Pat.', 'No. 10,174,599, which is a continuation of U.S. patent application Ser.', 'No. 14/079,794, filed Nov. 14, 2013, now U.S. Pat.', 'No. 9,016,383, which is a continuation of U.S. patent application Ser.', 'No. 13/711,219, filed on Dec. 11, 2012, now U.S. Pat.', 'No. 8,851,186, which is a continuation of U.S. patent application Ser.', 'No. 13/235,699, filed on Sep. 19, 2011, now U.S. Pat.', 'No. 8,336,631, which is a continuation of U.S. patent application Ser.', 'No. 12/958,716, filed on Dec. 2, 2010, now U.S. Pat.', 'No. 8,056,635, which is a continuation of U.S. patent application Ser.', 'No. 11/754,776, filed on May 29, 2007, now U.S. Pat.', 'No. 7,845,413, which claims priority under 35 U.S.C. § 119(e) to U.S. Provisional Application Ser.', 'No. 60/803,798, filed on Jun. 2, 2006, which is incorporated herein by reference.\n \nFIELD OF THE INVENTION', 'The present invention relates generally to a pumping system for pumping a fluid from a surface of a well to a wellbore at high pressure, and more particularly to a such a system that includes splitting the fluid into a clean stream having a minimal amount of solids and a dirty stream having solids in a fluid carrier.', 'BACKGROUND', 'In special oilfield applications, pump assemblies are used to pump a fluid from the surface of the well to a wellbore at extremely high pressures.', 'Such applications include hydraulic fracturing, cementing, and pumping through coiled tubing, among other applications.', 'In the example of a hydraulic fracturing operation, a multi-pump assembly is often employed to direct an abrasive containing fluid, or fracturing fluid, through a wellbore and into targeted regions of the wellbore to create side “fractures” in the wellbore.', 'To create such fractures, the fracturing fluid is pumped at extremely high pressures, sometimes in the range of 10,000 to 15,000 psi or more.', 'In addition, the fracturing fluid contains an abrasive proppant which both facilitates an initial creation of the fracture and serves to keep the fracture “propped” open after the creation of the fracture.', 'These fractures provide additional pathways for underground oil and gas deposits to flow from underground formations to the surface of the well.', 'These additional pathways serve to enhance the production of the well.', 'Plunger pumps are typically employed for high pressure oilfield pumping applications, such as hydraulic fracturing operations.', 'Such plunger pumps are sometimes also referred to as positive displacement pumps, intermittent duty pumps, triplex pumps or quintuplex pumps.', 'Plunger pumps typically include one or more plungers driven by a crankshaft toward and away from a chamber in a pressure housing (typically referred to as a “fluid end”) in order to create pressure oscillations of high and low pressures in the chamber.', 'These pressure oscillations allow the pump to receive a fluid at a low pressure and discharge it at a high pressure via one way valves (also called check valves).', 'Multiple plunger pumps are often employed simultaneously in large scale hydraulic fracturing operations.', 'These pumps may be linked to one another through a common manifold, which mechanically collects and distributes the combined output of the individual pumps.', 'For example, hydraulic fracturing operations often proceed in this manner with perhaps as many as twenty plunger pumps or more coupled together through a common manifold.', 'A centralized computer system may be employed to direct the entire system for the duration of the operation.', 'However, the abrasive nature of fracturing fluids is not only effective in breaking up underground rock formations to create fractures therein, it also tends to wear out the internal components of the plunger pumps that are used to pump it.', 'Thus, when plunger pumps are used to pump fracturing fluids, the repair, replacement and/or maintenance expenses for the internal components of the pumps are extremely high, and the overall life expectancy of the pumps is low.', 'For example, when a plunger pump is used to pump a fracturing fluid, the pump fluid end, valves, valve seats, packings, and plungers require frequent maintenance and/or replacement.', 'Such a replacement of the fluid end is extremely expensive, not only because the fluid end itself is expensive, but also due to the difficulty and timeliness required to perform the replacement.', 'Valves, on the other hand are relatively inexpensive and relatively easy to replace, but require such frequent replacements that they comprise a large percentage of plunger pump maintenance expenses.', 'In addition, when a valve fails, the valve seat is often damaged as well, and seats are much more difficult to replace than valves due to the very large forces required to pull them out of the fluid end.', 'Accordingly, a need exists for an improved system and method of pumping fluids from a well surface to a wellbore.', 'SUMMARY\n \nIn one embodiment, the present invention includes splitting a fracturing fluid stream into a clean stream having a minimal amount of solids and a dirty stream having solids in a fluid carrier, wherein the clean stream is pumped from the well surface to a wellbore by one or more clean pumps and the dirty stream is pumped from the well surface to a wellbore by one or more dirty pumps, thus greatly increasing the useful life of the clean pumps.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThese and other features and advantages of the present invention will be better understood by reference to the following detailed description when considered in conjunction with the accompanying drawings wherein:\n \nFIG.', '1\n is side view of a plunger pump for use in a pump system according to one embodiment of the present invention;\n \nFIG.', '2\n is a schematic representation of a pump system for performing a hydraulic fracturing operation on a well according to one embodiment of the prior art;\n \nFIG.', '3\n is a schematic representation of a pump system for pumping a fluid from a well surface to a wellbore according to one embodiment of the present invention, wherein the fluid is split into a clean stream, pumped by one or more plunger pumps and a dirty stream also pumped by one or more plunger pumps;\n \nFIG.', '4\n is a side cross-sectional view of a multistage centrifugal pump;\n \nFIGS.', '5\n, \n7\n, and \n9\n each show a schematic representation of a pump system for pumping a fluid from a well surface to a wellbore according to one embodiment of the present invention, wherein the fluid is split into a clean stream, pumped by one or more multistage centrifugal pumps, and a dirty stream pumped by one or more plunger pumps;\n \nFIGS.', '6\n, \n8\n and \n10\n each show a top perspective view of a multistage centrifugal pump for use in a pump system according to one embodiment of the present invention;\n \nFIG.', '11\n is a side cross-sectional view of a progressing cavity pump; and\n \nFIG.', '12\n is a schematic representation of a pump system for pumping a fluid from a well surface to a wellbore according to one embodiment of the present invention, wherein the fluid is split into a clean stream pumped by one or more clean pumps that are remotely located from the wellbore, and a dirty stream.', 'DETAILED DESCRIPTION OF EMBODIMENTS OF THE INVENTION\n \nEmbodiments of the present invention relate generally to a pumping system for pumping a fluid from a surface of a well to a wellbore at high pressures, and more particularly to such a system that includes splitting the fluid into a clean stream having a minimal amount of solids and a dirty stream having solids in a fluid carrier.', 'In one embodiment, both the clean stream and the dirty stream are pumped by the same type of pump.', 'For example, in one embodiment one or more plunger pumps are used to pump each fluid stream.', 'In another embodiment, the clean stream and the dirty stream are pumped by different types of pumps.', 'For example, in one embodiment one or more plunger pumps are used to pump the dirty stream and one or more horizontal pumps (such as a centrifugal pump or a progressive cavity pump) are used to pump the clean fluid stream.', 'FIG.', '1\n shows a plunger pump \n101\n for pumping a fluid from a well surface to a wellbore.', 'As shown, the plunger pump \n101\n is mounted on a standard trailer \n102\n for ease of transportation by a tractor \n104\n.', 'The plunger pump \n101\n includes a prime mover \n106\n that drives a crankshaft through a transmission \n110\n and a drive shaft \n112\n.', 'The crankshaft, in turn, drives one or more plungers toward and away from a chamber in the pump fluid end \n108\n in order to create pressure oscillations of high and low pressures in the chamber.', 'These pressure oscillations allow the pump to receive a fluid at a low pressure and discharge it at a high pressure via one way valves (also called check valves).', 'Also connected to the prime mover \n106\n is a radiator \n114\n for cooling the prime mover \n106\n.', 'In addition, the plunger pump fluid end \n108\n includes an intake pipe \n116\n for receiving fluid at a low pressure and a discharge pipe \n118\n for discharging fluid at a high pressure.\n \nFIG.', '2\n shows an prior art pump system \n200\n for pumping a fluid from a surface \n118\n of a well \n120\n to a wellbore \n122\n during an oilfield operation.', 'In this particular example, the operation is a hydraulic fracturing operation, and hence the fluid pumped is a fracturing fluid.', 'As shown, the pump system \n200\n includes a plurality of water tanks \n221\n, which feed water to a gel maker \n223\n.', 'The gel maker \n223\n combines water from the tanks \n221\n with a gelling agent to form a gel.', 'The gel is then sent to a blender \n225\n where it is mixed with a proppant from a proppant feeder \n227\n to form a fracturing fluid.', 'The gelling agent increases the viscosity of the fracturing fluid and allows the proppant to be suspended in the fracturing fluid.', 'It may also act as a friction reducing agent to allow higher pump rates with less frictional pressure.', 'The fracturing fluid is then pumped at low pressure (for example, around 60 to 120 psi) from the blender \n225\n to a plurality of plunger pumps \n201\n as shown by solid lines \n212\n.', 'Note that each plunger pump \n201\n in the embodiment of \nFIG.', '2\n may have the same or a similar configuration as the plunger pump \n101\n shown in \nFIG.', '1\n.', 'As shown in \nFIG.', '2\n, each plunger pump \n201\n receives the fracturing fluid at a low pressure and discharges it to a common manifold \n210\n (sometimes called a missile trailer or missile) at a high pressure as shown by dashed lines \n214\n.', 'The missile \n210\n then directs the fracturing fluid from the plunger pumps \n201\n to the wellbore \n122\n as shown by solid line \n215\n.', 'In a typical hydraulic fracturing operation, an estimate of the well pressure and the flow rate required to create the desired side fractures in the wellbore is calculated.', 'Based on this calculation, the amount of hydraulic horsepower needed from the pumping system in order to carry out the fracturing operation is determined.', 'For example, if it is estimated that the well pressure and the required flow rate are 6000 psi (pounds per square inch) and 68 BPM (Barrels Per Minute), then the pump system \n200\n would need to supply 10,000 hydraulic horsepower to the fracturing fluid (i.e., 6000*68/40.8).', 'In one embodiment, the prime mover \n106\n in each plunger pump \n201\n is an engine with a maximum rating of 2250 brake horsepower, which, when accounting for losses (typically about 3% for plunger pumps in hydraulic fracturing operations), allows each plunger pump \n201\n to supply a maximum of about 2182 hydraulic horsepower to the fracturing fluid.', 'Therefore, in order to supply 10,000 hydraulic horsepower to a fracturing fluid, the pump system \n200\n of \nFIG.', '2\n would require at least five plunger pumps \n201\n.', 'However, in order to prevent an overload of the transmission \n110\n, between the engine \n106\n and the fluid end \n108\n of each plunger pump \n201\n, each plunger pump \n201\n is normally operated well under is maximum operating capacity.', 'Operating the pumps under their operating capacity also allows for one pump to fail and the remaining pumps to be run at a higher speed in order to make up for the absence of the failed pump.', 'As such in the example of a fracturing operation requiring 10,000 hydraulic horsepower, bringing ten plunger pumps \n201\n to the wellsite enables each pump engine \n106\n to be operated at about 1030 brake horsepower (about half of its maximum) in order to supply 1000 hydraulic horsepower individually and 10,000 hydraulic horsepower collectively to the fracturing fluid.', 'On the other hand, if only nine pumps \n201\n are brought to the wellsite, or if one of the pumps fails, then each of the nine pump engines \n106\n would be operated at about 1145 brake horsepower in order to supply the required 10,000 hydraulic horsepower to the fracturing fluid.', 'As shown, a computerized control system \n229\n may be employed to direct the entire pump system \n200\n for the duration of the fracturing operation.', 'As discussed above, a problem with this pump system \n200\n is that each plunger pump \n201\n is exposed to the abrasive proppant of the fracturing fluid.', 'Typically the concentration of the proppant in the fracturing fluid is about 2 to 12 pounds per gallon.', 'As mentioned above, the proppant is extremely destructive to the internal components of the plunger pumps \n201\n and causes the useful life of these pumps \n201\n to be relatively short.', 'In response to the problems of the above pump system \n200\n, \nFIG.', '3\n shows a pump system \n300\n according to one embodiment of the present invention.', 'In such an embodiment, the fluid that is pumped from the well surface \n118\n to the wellbore \n122\n is split into a clean side \n305\n containing primarily water that is pumped by one or more clean pumps \n301\n, and a dirty side \n305\n′ containing solids in a fluid carrier that is pumped by one or more dirty pumps \n301\n′. For example, in a fracturing operation the dirty side \n305\n′ contains a proppant in a fluid carrier (such as a gel).', 'As is explained in detail below, such a pump system \n300\n greatly increases the useful life of the clean pumps \n301\n, as the clean pumps \n301\n are not exposed to abrasive fluids.', 'Note that each clean pump \n301\n and each dirty pump \n301\n′ in the embodiment of \nFIG.', '3\n may have the same or a similar configuration as the plunger pump \n101\n shown in \nFIG. \n1\n.', 'In the pump system \n300\n of \nFIG.', '3\n, the dirty pumps \n301\n′ receive a dirty fluid in a similar manner to that described with respect to \nFIG.', '2\n.', 'That is, in the embodiment of \nFIG.', '3\n, the pump system \n300\n includes a plurality of water tanks \n321\n, which feed water to a gel maker \n323\n.', 'The gel maker \n323\n combines water from the tanks \n321\n with a gelling agent and forms a gel, which is sent to a blender \n325\n where it is mixed with a proppant from a proppant feeder \n327\n to form a dirty fluid, in this case a fracturing fluid.', 'Exemplary proppants include sand grains, resin-coated sand grains, polylactic acids, or high-strength ceramic materials such as sintered bauxite, among other appropriate proppants.', 'The dirty fluid is then pumped at low pressure (for example, around 60-120 psi) from the blender \n325\n to the dirty pumps \n301\n′ as shown by solid lines \n312\n′, and discharged by the dirty pumps \n301\n′ at a high pressure to a common manifold or missile \n310\n as shown by dashed lines \n314\n′.\n \nOn the clean side \n305\n, water from the water tanks \n321\n is pumped at low pressure (for example, around 60-120 psi) directly to the clean pumps \n301\n by a transfer pump \n331\n as shown by solid lines \n312\n, and discharged at a high pressure to the missile \n310\n as shown by dashed lines \n314\n.', 'The missile \n310\n receives both the clean and dirty fluids and directs their combination, which forms a fracturing fluid, to the wellbore \n122\n as shown by solid line \n315\n.', 'If the pump system \n300\n shown in \nFIG.', '3\n were used in place of the pump system \n200\n shown in \nFIG.', '2\n (that is, in a well \n120\n requiring 10,000 hydraulic horsepower), and assuming that each clean pump \n301\n and each dirty pump \n301\n′ contains an engine \n106\n with a maximum rating of \n2250\n brake horsepower, then as in the pump system \n200\n of \nFIG.', '2\n, each pump engine \n106\n in each clean and dirty pump \n301\n/\n301\n′ could be operated at about \n1030\n brake horsepower in order to supply the required 10,000 hydraulic horsepower to the fracturing fluid.', 'Also, as with the pump system \n200\n of \nFIG. \n2\n, the number of total number of pumps \n301\n/\n301\n′ in the pump system \n300\n of \nFIG.', '3\n may be reduced if the pump engines \n106\n are run at a higher brake horsepower.', 'For example, if one of the pumps fail on either the clean side \n305\n or the dirty side \n305\n′, then the remaining pumps may be run at a higher speed in order to make up for the absence of the failed pump.', 'In addition, a computerized control system \n329\n may be employed to direct the entire pump system \n300\n for the duration of the fracturing operation.', 'With the pump system \n300\n of \nFIG.', '3\n, the clean pumps \n301\n are not exposed proppants.', 'As a result, it is estimated that the clean pumps \n301\n in the pump system \n300\n of \nFIG.', '3\n will have a useful life of about ten times the useful life of the pumps \n201\n in the pump system \n200\n of \nFIG.', '2\n.', 'However, in order to compensate for the fact that the fluid received and discharged from the clean pumps \n301\n lacks proppant, the dirty pumps \n301\n′ in the pump system \n300\n of \nFIG.', '3\n are exposed to a greater concentration of proppant in order to obtain the same results as the pump system \n200\n of \nFIG.', '2\n.', 'That is, in an operation requiring a fracturing fluid with a proppant concentration of about 2 pounds per gallon to be pumped through the pumps \n201\n in \nFIG.', '2\n, the dirty pumps \n301\n′ in the pump system \n300\n of \nFIG.', '3\n would need to pump a fracturing fluid with a proppant concentration of about 10 pounds per gallon.', 'As a result, it is estimated that the useful life of the pumps \n301\n′ on the dirty side \n305\n′ of the pump system \n300\n of \nFIG.', '3\n would be about ⅕th the useful life of the pumps \n201\n in the pump system \n200\n of \nFIG.', '2\n.', 'However, comparing the pump systems \n200\n/\n300\n from \nFIGS.', '2\n and \n3\n, and assuming the use of the same total number of pumps in each pump system \n200\n/\n300\n for pumping the same concentration of proppant at the same hydraulic horsepower, the eight clean pumps \n301\n in the pump system \n300\n of \nFIG.', '3\n having a useful life of about ten times as long as the pumps \n201\n in the pump system \n200\n of \nFIG.', '2\n, far outweighs the useful life of the two dirty pumps \n301\n′ in the pump system \n300\n of \nFIG.', '3\n being about ⅕th as long as the pumps \n201\n in the pump system \n200\n of \nFIG.', '2\n.', 'As such, the overall useful life of the pump system \n300\n of \nFIG.', '3\n is much greater than that of the pump system \n200\n of \nFIG.', '2\n.', 'Note that it was assumed that the pump system \n300\n of \nFIG.', '3\n was used on a well \n120\n requiring 10,000 hydraulic horsepower.', 'This was assumed merely to form a direct comparison of how the pump system \n300\n of \nFIG.', '3\n would perform versus how the pump system \n200\n of \nFIG.', '2\n would perform when acting on the same well \n120\n.', 'This same 10,000 hydraulic horsepower well requirement will be assumed for the pump systems \n500\n/\n700\n/\n900\n (described below) for the same comparative purpose.', 'However, as described further below, it is to be understood that each of the pump systems described herein \n300\n/\n500\n/\n700\n/\n900\n/\n1200\n may supply any desired amount of hydraulic horsepower to a well.', 'For example, various wells might have hydraulic horsepower requirements in the range of about 500 hydraulic horsepower to about 100,000 hydraulic horsepower, or even more.', 'As such, although \nFIG.', '3\n shows the pump system \n300\n as having eight dirty pumps \n301\n′ and two clean pumps \n301\n, in alternative embodiments the pump system \n300\n may contain any appropriate number of dirty pumps \n301\n′, and any appropriate number of clean pumps \n301\n, dependent on the hydraulic horsepower required by the well \n120\n, the percent capacity at which it is desired to run the pump engines \n106\n, and the amount of proppant desired to be pumped.', 'Also note that although two dirty pumps \n301\n′ are shown in the embodiment of \nFIG.', '3\n, the pump system \n300\n may contain more or even less than two dirty pumps \n301\n′, the trade off being that the less dirty pumps \n301\n′ the pump system \n300\n has, the higher the concentration of proppant that must be pumped by each dirty pump \n301\n′; the result of the higher concentration of proppant being the expedited deterioration of the useful life of the dirty pumps \n301\n′. On the other hand, the fewer the dirty pumps \n301\n′, the more clean pumps \n301\n that can be used to obtain the same results, and as mentioned above, the expedited deterioration of the useful life of the dirty pumps \n301\n′ is far outweighed by the increased useful life of the clean pumps \n301\n.', 'In the embodiment of \nFIG.', '3\n, two dirty pumps \n301\n′ are shown.', 'Although the pump system \n300\n could work with only one dirty pump \n301\n′, in this embodiment the pump system \n300\n includes two dirty pumps \n301\n′', 'so that if one of the dirty pumps fails, the proppant concentration in the remaining dirty pump can be doubled to make up for the absence of the failed dirty side pump.', 'Although the pump system \n300\n of \nFIG.', '3\n achieves the goal of having a longer overall useful life than the pump system \n200\n of \nFIG.', '2\n, the pump system \n300\n of \nFIG.', '3\n still uses plunger pumps.', 'Although this is a perfectly acceptable embodiment, a problem with plunger pumps is that they continually oscillate between high pressure operating conditions and low pressure operating conditions.', 'That is, when a plunger is moved away from its fluid end, the fluid end experiences a low pressure; and when a plunger is moved toward its fluid end, the fluid end experiences a high pressure.', 'This oscillating pressure on the fluid end places the fluid end (as well as it internal components) under a tremendous amount of strain which eventually results in fatigue failures in the fluid end.', 'In addition, plunger pumps generate torque pulsations and pressure pulsations, these pulsations being proportional to the number of plungers in the pump, with the higher the number of plungers, the lower the pulsations.', 'However, increasing the number of plungers comes at a significant cost in terms of mechanical complexity and increased cost to replace the valves, valve seats, packings, plungers, etc.', 'On the other hand, the pulsations created by plunger pumps are the main cause of transmission \n110\n failures, which fail fairly frequently, and the transmission \n110\n is even more difficult to replace than the pump fluid end \n108\n and is comparable in cost.', 'The pressure pulses in plunger pumps are large enough that if the high pressure pump system goes into resonance, parts of the pumping system will fail in the course of a single job.', 'That is, components such as the missile or treating iron can fail catastrophically.', 'This pressure pulse problem is even worse when multiple pumps are run at the same or very similar speeds.', 'As such, in a system using multiple plunger pumps, considerable effort has to be devoted to running all of the pumps at different speeds to prevent resonance, and the potential for catastrophic failure.', 'Multistage centrifugal pumps, on the other hand, can receive fluid at a low pressure and discharge it at a high pressure while exposing its internal components to a fairly constant pressure with minimal variation at each stage along its length.', 'The lack of large pressure variations means that the pressure housing of the centrifugal pump does not experience significant fatigue damage while pumping.', 'As a result, when pumping clean fluids, multistage centrifugal pump systems generally exhibit higher life expectancy, and lower operational costs than plunger pumps.', 'In addition, multistage centrifugal pump systems also tend to wear out and lose efficiency gradually, rather than failing catastrophically as is more typical with plunger pumps and their associated transmissions.', 'Therefore, in some situations when pumping a clean fluid it may be desired to use multistage centrifugal pumps rather than plunger pumps.\n \nFIG. \n4\n shows an example of a multistage centrifugal pump \n424\n.', 'As shown, the multistage centrifugal pump \n424\n receives a fluid through an intake pipe \n426\n at a low pressure and discharges it through a discharge pipe \n428\n at a high pressure by passing the fluid (as shown by the arrows) along a long cylindrical pipe or barrel \n430\n having a series of impellers or rotors \n432\n.', 'That is, as the fluid is propelled by each successive impeller \n432\n, it gains more and more pressure until it exits the pump at a much higher pressure than it entered.', 'To create a multistage centrifugal pump with a greater pressure output, the diameter of the impellers \n432\n may be increased and/or the number of impellers \n432\n (also referred to as the number of stages of the pump) may be increased.', 'As such it may be desirable to create a pumping system similar to that of \nFIG.', '3\n, but using multistage centrifugal pumps as the clean pumps rather than plunger pumps as the clean pumps.', 'Such a configuration in shown in the pump system \n500\n of \nFIG.', '5\n.', 'Note that many portions of the pump system \n500\n of \nFIG.', '5\n may generally operate in the same manner as described above with respect to the pump system \n300\n of \nFIG.', '3\n.', 'Therefore, the operations of the pump system \n500\n of \nFIG.', '5\n that are similar to the operations described above with respect to the pump system \n300\n of \nFIG.', '3\n are not repeated here to avoid duplicity.', 'However, as mentioned above, a difference between the pump system \n500\n of \nFIG.', '5\n and the pump system \n300\n of \nFIG.', '3\n is that the clean pumps \n501\n on the clean side \n305\n of the pump system \n500\n of \nFIG.', '5\n are multistage centrifugal pumps rather than plunger pumps.', 'In this embodiment, each clean pump \n501\n may have the same or a similar configuration as the multistage centrifugal pump \n501\n shown in \nFIG. \n6\n.', 'As shown in \nFIG. \n6\n, the multistage centrifugal pump \n501\n is mounted on a standard trailer \n102\n for ease of transportation by a tractor \n104\n.', 'The multistage centrifugal pump \n501\n includes a prime mover \n506\n that drives the impellers contained therein through a gearbox \n511\n.', 'Also connected to the prime mover \n506\n is a radiator \n514\n for cooling the prime mover \n506\n.', 'In addition, the multistage centrifugal pump \n501\n includes four centrifugal pump barrels \n530\n connected in series by a high pressure interconnecting manifold \n509\n.', 'In this embodiment, each pump barrel \n530\n contains forty impellers having a diameter of approximately 5-11 inches.', 'An example of such a pump barrel \n530\n is commercially available from Reda Pump Co. of Singapore (i.e., a Reda 675 series HPS pump barrel with 40 stages.)', 'In one embodiment, the prime mover \n506\n in each multistage centrifugal pump \n501\n in the pump system \n500\n of \nFIG.', '5\n is a diesel engine with a maximum rating of 2250 brake horsepower, which when accounting for losses (typically about 30% for multistage centrifugal pumps in hydraulic fracturing operations), allows each clean pump \n501\n in the pump system \n500\n of \nFIG.', '5\n to supply a maximum of about 1575 hydraulic horsepower to the fracturing fluid.', 'Therefore, in order to supply 10,000 hydraulic horsepower to a fracturing fluid, assuming each dirty pump \n301\n′ supplies about 1000 hydraulic horsepower to the fracturing fluid (as assumed in the pump systems \n200\n and \n300\n of \nFIGS. \n2\n and \n3\n), the pump system \n500\n of \nFIG.', '5\n would require six multistage centrifugal pump \n501\n, each supplying \n1575\n hydraulic horsepower to obtain a total of about 11,450 hydraulic horsepower.', 'Note that the excess available 1,450 hydraulic horsepower over the required 10,000 hydraulic horsepower allows one of the pumps \n501\n/\n301\n′ in the pump system \n500\n of \nFIG.', '5\n to fail with the remaining pumps \n501\n/\n301\n′ making up for the absence of the failed pump,', 'and/or allows the clean pumps \n501\n to operate at less than full power.', 'Note, however, that since the multistage centrifugal pumps \n501\n of \nFIG.', '5\n do not contain a transmission, they can be run at full power without fear of failure.', 'As such, in order for the pump system \n500\n of \nFIG.', '5\n to pump the same concentration of proppant at the same hydraulic horsepower as the pump system \n200\n of \nFIG.', '2\n, two less total pumps are required.', 'In addition, the clean pumps \n501\n in the pump system \n500\n of \nFIG.', '5\n are likely to last longer than the pumps \n201\n in the pump system \n200\n of \nFIG.', '2\n.\n \nFIG.', '7\n shows an embodiment similar to that shown in \nFIG.', '5\n, but with differently configured clean pumps \n701\n.', 'Note that many portions of the pump system \n700\n of \nFIG.', '7\n may generally operate in the same manner as described above with respect to the pump system \n300\n of \nFIG.', '3\n.', 'Therefore, the operations of the pump system \n700\n of \nFIG.', '7\n that are similar to the operations described above with respect to the pump system \n300\n of \nFIG.', '3\n are not repeated here to avoid duplicity.', 'However, as mentioned above, a difference between the pump system \n700\n of \nFIG.', '7\n and the pump system \n300\n of \nFIG.', '3\n is that the clean pumps \n701\n on the clean side \n305\n of the pump system \n700\n of \nFIG.', '7\n are multistage centrifugal pumps rather than plunger pumps.', 'In addition, although the clean pumps \n501\n/\n701\n in the pump systems \n500\n/\n700\n of both \nFIGS.', '5\n and \n7\n are multistage centrifugal pumps, the multistage centrifugal pumps in the pump system \n700\n of \nFIG.', '7\n are configured differently than the multistage centrifugal pumps of \nFIG.', '5\n.', 'For example, in the embodiment of \nFIG.', '7\n, each clean pump \n701\n may have the same or a similar configuration as the multistage centrifugal pump \n701\n shown in \nFIG. \n8\n.', 'As shown in \nFIG. \n8\n, the multistage centrifugal pump \n701\n is mounted on a standard trailer \n102\n for ease of transportation by a tractor \n104\n.', 'The multistage centrifugal pump \n701\n includes a prime mover \n706\n that drives the impellers contained therein through a gearbox \n711\n and a transfer box \n713\n.', 'In addition, the multistage centrifugal pump \n701\n includes two centrifugal pump barrels \n730\n connected in series by a high pressure interconnecting manifold \n709\n.', 'In this embodiment, each pump barrel \n730\n contains 76 impellers having a diameter of approximately 5-11 inches.', 'An example of such a pump barrel \n730\n is commercially available from Reda Pump Co. of Singapore (i.e., a Reda series 862 HM520AN HPS pump barrel with 76 stages.)', 'In one embodiment, the prime mover \n706\n in each multistage centrifugal pump \n701\n in the pump system \n700\n of \nFIG.', '7\n is an electric motor with a maximum rating of 3500 brake horsepower, which when accounting for losses (typically about 30% for multistage centrifugal pumps in hydraulic fracturing operations), allows each clean pump \n701\n in the pump system \n700\n of \nFIG.', '7\n to supply a maximum of about 2450 hydraulic horsepower to the fracturing fluid.', 'Therefore, in order to supply 10,000 hydraulic horsepower to a fracturing fluid, assuming each dirty pump \n301\n′ supplies about 1000 hydraulic horsepower to the fracturing fluid (as assumed in the pump systems \n200\n and \n300\n of \nFIGS. \n2\n and \n3\n), the pump system \n700\n of \nFIG.', '7\n would require four multistage centrifugal pumps \n701\n each supplying 2450 hydraulic horsepower in order to obtain a total of about 11,880 hydraulic horsepower.', 'Note that the excess available 1,880 hydraulic horsepower over the required 10,000 hydraulic horsepower allows one of the pumps \n701\n/\n301\n′ in the pump system \n700\n of \nFIG.', '7\n to fail with the remaining pumps \n701\n/\n301\n′ making up for the absence of the failed pump,', 'and/or allows the clean pumps \n701\n to operate at less than full power.', 'Note, however, that since the multistage centrifugal pumps \n701\n of \nFIG.', '7\n do not contain a transmission, they can be run at full power without fear of failure.', 'As such, in order for the pump system \n700\n of \nFIG.', '7\n to pump the same concentration of proppant at the same hydraulic horsepower as the pump system \n200\n of \nFIG.', '2\n, four less total pumps are required.', 'In addition, the clean pumps \n701\n in the pump system \n700\n of \nFIG.', '7\n are likely to last longer than the pumps \n201\n in the pump system \n200\n of \nFIG.', '2\n.', 'FIG.', '9\n shows an embodiment similar to that shown in \nFIG.', '5\n, but with yet another configuration of clean pumps \n901\n.', 'Note that many portions of the pump system \n900\n of \nFIG.', '9\n may generally operate in the same manner as described above with respect to the pump system \n300\n of \nFIG.', '3\n.', 'Therefore, the operations of the pump system \n900\n of \nFIG.', '9\n that are similar to the operations described above with respect to the pump system \n300\n of \nFIG.', '3\n are not repeated here to avoid duplicity.', 'However, as mentioned above, a difference between the pump system \n900\n of \nFIG.', '9\n and the pump system \n300\n of \nFIG.', '3\n is that the clean pumps \n901\n on the clean side \n305\n of the pump system \n900\n of \nFIG.', '9\n are multistage centrifugal pumps rather than plunger pumps.', 'In addition, although the clean pumps \n501\n/\n901\n in the pump systems \n500\n/\n900\n of both \nFIGS.', '5\n and \n9\n are multistage centrifugal pumps, the multistage centrifugal pumps in the pump system \n900\n of \nFIG.', '9\n are configured differently than the multistage centrifugal pumps of \nFIG.', '5\n.', 'For example, in the embodiment of \nFIG.', '9\n, each clean pump \n901\n may have the same or a similar configuration as the multistage centrifugal pump \n901\n shown in \nFIG. \n10\n.', 'As shown in \nFIG. \n10\n, the multistage centrifugal pump \n901\n is mounted on a standard trailer \n102\n for ease of transportation by a tractor \n104\n.', 'The multistage centrifugal pump \n901\n includes a prime mover \n906\n that drives the impellers contained therein through a gearbox \n911\n.', 'In addition, the multistage centrifugal pump \n901\n includes two centrifugal pump barrels \n930\n connected in series by a high pressure interconnecting manifold \n909\n.', 'In this embodiment, each pump barrel \n930\n contains 76 impellers having a diameter of approximately 5-11 inches.', 'An example of such a pump barrel \n930\n is commercially available from Reda Pump Co. of Singapore (i.e., a Reda series 862 HM520AN HPS pump barrel with 76 stages.)', 'In one embodiment, the prime mover \n906\n in each multistage centrifugal pump \n901\n in the pump system \n900\n of \nFIG.', '9\n is a turbine engine with a maximum rating of 3500 brake horsepower, which when accounting for losses (typically about 30% for multistage centrifugal pumps in hydraulic fracturing operations), allows each clean pump \n901\n in the pump system \n900\n of \nFIG.', '9\n to supply a maximum of about 2450 hydraulic horsepower to the fracturing fluid.', 'Therefore, in order to supply 10,000 hydraulic horsepower to a fracturing fluid, assuming each dirty pump \n301\n′ supplies about 1000 hydraulic horsepower to the fracturing fluid (as assumed in the pump systems \n200\n and \n300\n of \nFIGS. \n2\n and \n3\n), the pump system \n900\n of \nFIG.', '9\n would require four multistage centrifugal pumps \n901\n each supplying 2450 hydraulic horsepower to obtain a total of about 11,880 hydraulic horsepower.', 'Note that the excess available 1,880 hydraulic horsepower over the required 10,000 hydraulic horsepower allows one of the pumps \n901\n/\n301\n′ in the pump system \n900\n of \nFIG.', '9\n to fail with the remaining pumps \n901\n/\n301\n′ making up for the absence of the failed pump,', 'and/or allows the clean pumps \n901\n to operate at less than full power.', 'However, note that since the multistage centrifugal pumps \n901\n of \nFIG.', '9\n do not contain a transmission, they can be run at full power without fear of failure.', 'As such, in order for the pump system \n900\n of \nFIG. \n9\n to pump the same concentration of proppant at the same hydraulic horsepower as the pump system \n200\n of \nFIG.', '2\n, four less total pumps are required.', 'In addition, the clean pumps \n901\n in the pump system \n900\n of \nFIG.', '9\n are likely to last longer than the pumps \n201\n in the pump system \n200\n of \nFIG.', '2\n.', 'Note, in each of the embodiments of \nFIGS.', '5\n, \n7\n and \n9\n, the pump barrels \n530\n/\n730\n/\n930\n are shown connected in series, however, in alternative embodiments the pump barrels \n530\n/\n730\n/\n930\n in any of the embodiments of \nFIGS.', '5\n, \n7\n, and \n9\n may be connected in parallel, or in any combination of series and parallel.', 'However, an advantage of having the barrels \n530\n/\n730\n/\n930\n arranged successive barrel \n530\n/\n730\n/\n930\n at a higher pressure, whereas in a parallel configuration the fluid leaves each barrel \n530\n/\n730\n/\n930\n at the same pressure.', 'Progressing cavity pumps have characteristics very similar to multistage centrifugal pumps, and therefore may be desirable for use in pump systems according to the present invention.', 'FIG.', '11\n shows an example of a progressing cavity pump \n1140\n.', 'As shown, the progressing cavity pump \n1140\n receives a fluid through an intake pipe \n1142\n at a low pressure and discharges it through a discharge pipe \n1144\n at a high pressure by passing the fluid along a long cylindrical pipe or barrel \n1130\n having a series of twists \n1146\n (also referred to as turns or stages).', 'That is, as the fluid is propelled by each successive twist \n1146\n, it gains more and more pressure until it exits the pump \n1140\n at a much higher pressure than it entered.', 'To create a progressing cavity pump with a greater pressure output, the diameter of the twists \n432\n may be increased and/or the number of twist \n432\n (also referred to as the number of stages of the pump) may be increased.', 'Suitable progressing cavity pumps for oilwell operations, such as hydraulic fracturing operations, include the Moyno 962ERT6743, and the Moyno 108-T-315, among other appropriate pumps.', 'As such, in any of the embodiments described above, the clean pumps \n301\n may be replaced with progressing cavity pumps.', 'In addition, progressing cavity pumps are capable of handling very high solids loadings, such as the proppant concentrations in typical hydraulic fracturing operations.', 'Consequently, in any of the embodiments described above, the dirty pumps \n301\n′ may be replaced with progressing cavity pumps.', 'In addition, in any of the embodiments described above, the clean pumps \n301\n may include any combination of plunger pumps, multistage centrifugal pumps and progressing cavity pumps; and the dirty pumps may similarly include any combination of plunger pumps, multistage centrifugal pumps and progressing cavity pumps.', 'Note also that in each of the above pump system embodiments \n200\n/\n300\n/\n500\n/\n700\n/\n900\n it was assumed that the accompanying well \n120\n required 10,000 hydraulic horsepower.', 'This was assumed so that each of the pump systems \n200\n/\n300\n/\n500\n/\n700\n/\n900\n could be directly compared to each other.', 'However, in each of the pump systems \n300\n/\n500\n/\n700\n/\n900\n described above the total output hydraulic horsepower may be increased/decreased by using a prime mover \n106\n/\n506\n/\n706\n/\n906\n with a larger/smaller horsepower output, and/or by increasing/decreasing the total number of pumps in the pump system \n300\n/\n500\n/\n700\n/\n900\n.', 'With these modifications, each of the pump systems \n300\n/\n500\n/\n700\n/\n900\n described above may supply a hydraulic horsepower in the range of about 500 hydraulic horsepower to about 100,000 hydraulic horsepower, or even more if needed.', 'In various embodiments, the prime mover \n106\n/\n506\n/\n706\n/\n906\n in any of the above described pump systems \n300\n/\n500\n/\n700\n/\n900\n may be a diesel engine, a gas turbine, a steam turbine, an AC electric motor, a DC electric motor.', 'In addition, any of these prime movers \n106\n/\n506\n/\n706\n/\n906\n may have any appropriate power rating.\n \nFIG.', '12\n shows another embodiment of a pump system \n1200\n according to the present invention wherein the fluid to be pumped (such as a fracturing fluid) is split into a clean side \n305\n containing primarily water that is pumped by one or more clean pumps \n1201\n, and a dirty side \n305\n′ containing solids in a fluid carrier (for example, a proppant in a gelled water) that is pumped by one or more dirty pumps \n1201\n′.\n \nIn the embodiment of \nFIG. \n12\n, the clean side pumps \n1201\n may operate in the same manner as any of the embodiments for the clean side pumps \n301\n/\n501\n/\n701\n/\n901\n described above, and therefore may contain one or more plunger pumps \n301\n; one or more multistage centrifugal pumps \n501\n/\n701\n/\n901\n; one or more progressing cavity pumps \n1140\n; or any appropriate combination thereof.', 'Similarly, the dirty side pumps \n1201\n′ may operate in the same manner as any of the embodiments of the dirty side pumps \n301\n′ described above, and therefore may contain one or more plunger pumps \n301\n; one or more multistage centrifugal pumps \n501\n/\n701\n/\n901\n; one or more progressing cavity pumps \n1140\n; or any appropriate combination thereof.', 'However, in contrast to the embodiments disclosed above, in the pump system \n1200\n of \nFIG. \n12\n, the clean side pumps \n1201\n may be remotely located from the dirty side pumps \n1201\n′/\n1201\n″.', 'In addition, the clean side pumps \n1201\n may be used to supply a clean fluid to more than one wellbore.', 'For example, in the embodiment of \nFIG. \n12\n, the clean side pumps \n1201\n are shown remotely located from, and supplying a clean fluid to, the wellbores \n1222\n and \n1222\n′ of both a first well \n1220\n and a second well \n1220\n′. Such a configuration significantly reduces the required footprint in the area around the wells \n1218\n and \n1218\n″ since only one set of clean side pumps \n1201\n is used to treat both wellbores \n1222\n and \n1222\n″.\n \nHowever, it should be noted that in alternative embodiments, the clean side pumps \n1201\n may be remotely connected to a single well, or remotely connected to any desired number of multiple wells, with each of the multiple wells being either directly connected to one or more dedicated dirty side pumps or remotely connected to one or more remotely located dirty side pumps.', 'In addition, in further embodiments, one or more dirty pumps may be remotely connected to a single well or remotely connected to any desired number of multiple wells.', 'Also, the well treating lines \n1250\n and \n1250\n″ used to connect the pumps \n1201\n/\n1201\n′/\n1201\n″ to the wellbores \n1222\n/\n1222\n″ may be used as production lines when it is desired to produce the well.', 'In one embodiment, the clean side pumps \n1201\n may be remotely located by a distance anywhere in the range of about one thousand feet to several miles from the well(s) \n1201\n/\n1201\n′ to which they supply a clean fluid.', 'Although the above described embodiments focus primarily on pump systems that use dirty pumps to pump a fracturing fluid during a hydraulic fracturing operation, in any of the embodiments of the pump systems described above the dirty pumps may be used to pump any fluid or gas that may be considered to be more corrosive to the dirty pumps than water, such as acids, petroleum, petroleum distillates (such as diesel fuel), liquid Carbon Dioxide, liquid propane, low boiling point liquid hydrocarbons, Carbon Dioxide, an Nitrogen, among others.', 'In addition, the dirty pumps in any of the embodiments described above may be used to pump minor additives to change the characteristics of the fluid to be pumped, such as materials to increase the solids carrying capacity of the fluid, foam stabilizers, pH changers, corrosion preventers, and/or others.', 'Also, the dirty pumps in any of the embodiments described above may be used to pump solid materials other than proppants, such as particles, fibers, and materials having manufactured shapes, among others.', 'In addition, either the clean or the dirty pumps in any of the embodiments described above may be used to pump production chemicals, which includes any chemicals used to modify a characteristic of the well formation of a production fluid extracted therefore, such as scale inhibitors, or detergents, among other appropriate production chemicals.', 'The preceding description has been presented with reference to presently preferred embodiments of the invention.', 'Persons skilled in the art and technology to which this invention pertains will appreciate that alterations and changes in the described structures and methods of operation can be practiced without meaningfully departing from the principle, and scope of this invention.', 'Accordingly, the foregoing description should not be read as pertaining only to the precise structures described and shown in the accompanying drawings, but rather should be read as consistent with and as support for the following claims, which are to have their fullest and fairest scope.']

['1.', 'A method comprising:\noperating one or more clean pumps to pump a non-gel fluid having no proppant added thereto; and\noperating one or more dirty pumps to pump the dirty stream, the dirty stream comprising a solid material disposed in a fluid carrier, wherein the solid material is a proppant with a concentration of the proppant in the fluid carrier of about 2 to 12 pounds per gallon, wherein the dirty stream causes a useful life of the one or more dirty pumps to be shortened relative to a reduction in a useful lie of the one or more clean pumps due to the non-gel fluid, wherein a manifold receives the non-gel fluid downstream of the one or more clean pumps, the non-gel fluid received by the manifold is discharged directly from the one or more clean pumps, the non-gel fluid and the dirty steam are combined at the manifold and together form an oilfield fluid to be transmitted from a well surface to a wellbore.', '2.', 'The method of claim 1, wherein each of the one or more clean pumps is a first type of pump and each of the one or more dirty pumps is a second type of pump, and wherein the first type of pump is a same type of pump as the second type of pump.', '3.', 'The method of claim 2, wherein the first type of pump and the second type of pump are each plunger pumps.', '4.', 'The method of claim 1, wherein each of the one or more clean pumps is a first type of pump and each of the one or more dirty pumps is a second type of pump, and wherein the first type of pump is a different type of pump as the second type of pump.', '5.', 'The method of claim 4, wherein the first type of pump is a multistage centrifugal pump and the second type of pump is a plunger pump.', '6.', 'The method of claim 4, wherein the first type of pump is a progressing cavity pump and the second type of pump is a plunger pump.', '7.', 'The method of claim 1, wherein each of the one or more clean pumps is a multistage centrifugal pump.', '8.', 'The method of claim 1, wherein each of the one or more clean pumps is a progressing cavity pump.', '9.', 'The method of claim 1, wherein each of the one or more clean pumps is a plunger pump.', '10.', 'The method of claim 1, wherein the one or more clean pumps comprise any combination of one or more multistage centrifugal pumps, one or more progressing cavity pumps and one or more plunger pumps.', '11.', 'The method of claim 1, wherein each of the one or more dirty pumps is a progressing cavity pump.\n\n\n\n\n\n\n12.', 'The method of claim 1, wherein each of the one or more dirty pumps is a plunger pump.', '13.', 'The method of claim 1, wherein the one or more dirty pumps comprise any combination of one or more multistage centrifugal pumps, one or more progressing cavity pumps and one or more plunger pumps.', '14.', 'The method of claim 1, wherein each of the one or more clean pumps comprises a prime mover for supplying power, and wherein the prime mover is chosen from the group consisting of a diesel engine, a gas turbine, a steam turbine, an AC electric motor, and a DC electric motor.', '15.', 'The method of claim 1, wherein the one or more clean pumps are disposed remotely from the wellbore.', '16.', 'The method of claim 1, wherein the oilfield fluid is a fracturing fluid.', '17.', 'The method of claim 1, wherein the dirty stream further comprises one of an additive to change the characteristics of the oilfield fluid and a production chemical.', '18.', 'A pump system for pumping an oilfield fluid from a well surface to a wellbore comprising:\none or more clean pumps, which pump a non-gel fluid having no proppant added thereto;\none or more dirty pumps, which pump a dirty stream, comprising a solid material disposed in a fluid carrier, as a proppant with a concentration of the proppant in the fluid carrier of about 2 to 12 pounds per gallon, wherein the dirty stream causes a useful life of the one or more dirty pumps to be shortened relative to a reduction in a useful life of the one or more clean pumps due to the non-gel fluid; and\na manifold coupled to the one or more clean pumps and to the one or more dirty pumps such that, in operation, the manifold receives the non-gel fluid downstream of the one or more clean pumps, the non-gel fluid received by the manifold is fluid discharged directly from the one or more clean pumps, and the non-gel fluid and the dirty steam are combined by the manifold and together form an oilfield to be transmitted from the well surface to the wellbore.', '19.', 'The pump system of claim 18, wherein each of the one or more clean pumps is a plunger pump and each of the one or more dirty pumps is plunger pump.', '20.', 'The pump system of claim 18, wherein each of the one or more clean pumps is a multistage centrifugal pump and each of the one or more dirty pumps is plunger pump.', '21.', 'The pump system of claim 18, wherein each of the one or more clean pumps comprises any combination of one or more multistage centrifugal pumps, one or more progressing cavity pumps and one or more plunger pumps; and wherein each of the one or more dirty pumps comprises any combination of one or more multistage centrifugal pumps, one or more progressing cavity pumps and one or more plunger pumps.', '22.', 'The pump system of claim 18, wherein each of the one or more clean pumps comprises a prime mover for supplying power, and wherein the prime mover is chosen from the group consisting of a diesel engine, a gas turbine, a steam turbine, an AC electric motor, and a DC electric motor.', '23.', 'The pump system of claim 18, wherein the one or more clean pumps are disposed remotely from the wellbore.', '24.', 'The pump system claim 18, wherein the solid material is a proppant and wherein the oilfield fluid is a fracturing fluid.', '25.', 'A method comprising:\nproviding a non-gel fluid having no proppant added thereto;\noperating one or more clean pumps to pump the non-gel fluid;\nproviding a dirty stream comprising a corrosive material, wherein the dirty stream comprises a gel having proppant added thereto with a concentration of the proppant in the gel of about 2 to 12 pounds per gallon; and\noperating one or more dirty pumps to pump the dirty stream, wherein the non-gel fluid and the dirty steam together form an oilfield fluid pumped to a wellbore.\n\n\n\n\n\n\n26.', 'The method of claim 25, wherein each of the one or more clean pumps is a plunger pump and each of the one or more dirty pumps is plunger pump.', '27.', 'The of claim 25, wherein each of the one or more clean pumps is a multistage centrifugal pump and each of the one or more dirty pumps is plunger pump.', '28.', 'The of claim 25, wherein each of the one or more clean pumps comprises any combination of one or more multistage centrifugal pumps, one or more progressing cavity pumps and one or more plunger pumps; and wherein each of the one or more dirty pumps comprises any combination of one or more multistage centrifugal pumps, one or more progressing cavity pumps and one or more plunger pumps.', '29.', 'The of claim 25, wherein each of the one or more clean pumps comprises a prime mover for supplying power, and wherein the prime mover is chosen from the group consisting of a diesel engine, a gas turbine, a steam turbine, an AC electric motor, and a DC electric motor.', '30.', 'The of claim 25, wherein the one or more clean pumps are disposed remotely from the wellbore.', '31.', 'The claim 25, wherein the corrosive material is chosen from the group consisting of acids, petroleum, petroleum distillates, liquid Carbon Dioxide, liquid propane, low boiling point liquid hydrocarbons, Carbon Dioxide, and Nitrogen.']

['FIG. 1 is side view of a plunger pump for use in a pump system according to one embodiment of the present invention;; FIG.', '2 is a schematic representation of a pump system for performing a hydraulic fracturing operation on a well according to one embodiment of the prior art;; FIG.', '3 is a schematic representation of a pump system for pumping a fluid from a well surface to a wellbore according to one embodiment of the present invention, wherein the fluid is split into a clean stream, pumped by one or more plunger pumps and a dirty stream also pumped by one or more plunger pumps;; FIG.', '4 is a side cross-sectional view of a multistage centrifugal pump;; FIGS.', '5, 7, and 9 each show a schematic representation of a pump system for pumping a fluid from a well surface to a wellbore according to one embodiment of the present invention, wherein the fluid is split into a clean stream, pumped by one or more multistage centrifugal pumps, and a dirty stream pumped by one or more plunger pumps;; FIGS. 6, 8 and 10 each show a top perspective view of a multistage centrifugal pump for use in a pump system according to one embodiment of the present invention;; FIG.', '11 is a side cross-sectional view of a progressing cavity pump; and; FIG.', '12 is a schematic representation of a pump system for pumping a fluid from a well surface to a wellbore according to one embodiment of the present invention, wherein the fluid is split into a clean stream pumped by one or more clean pumps that are remotely located from the wellbore, and a dirty stream.; FIG.', '1 shows a plunger pump 101 for pumping a fluid from a well surface to a wellbore.', 'As shown, the plunger pump 101 is mounted on a standard trailer 102 for ease of transportation by a tractor 104.', 'The plunger pump 101 includes a prime mover 106 that drives a crankshaft through a transmission 110 and a drive shaft 112.', 'The crankshaft, in turn, drives one or more plungers toward and away from a chamber in the pump fluid end 108 in order to create pressure oscillations of high and low pressures in the chamber.', 'These pressure oscillations allow the pump to receive a fluid at a low pressure and discharge it at a high pressure via one way valves (also called check valves).', 'Also connected to the prime mover 106 is a radiator 114 for cooling the prime mover 106.', 'In addition, the plunger pump fluid end 108 includes an intake pipe 116 for receiving fluid at a low pressure and a discharge pipe 118 for discharging fluid at a high pressure.', '; FIG.', '2 shows an prior art pump system 200 for pumping a fluid from a surface 118 of a well 120 to a wellbore 122 during an oilfield operation.', 'In this particular example, the operation is a hydraulic fracturing operation, and hence the fluid pumped is a fracturing fluid.', 'As shown, the pump system 200 includes a plurality of water tanks 221, which feed water to a gel maker 223.', 'The gel maker 223 combines water from the tanks 221 with a gelling agent to form a gel.', 'The gel is then sent to a blender 225 where it is mixed with a proppant from a proppant feeder 227 to form a fracturing fluid.', 'The gelling agent increases the viscosity of the fracturing fluid and allows the proppant to be suspended in the fracturing fluid.', 'It may also act as a friction reducing agent to allow higher pump rates with less frictional pressure.; FIG.', '4 shows an example of a multistage centrifugal pump 424.', 'As shown, the multistage centrifugal pump 424 receives a fluid through an intake pipe 426 at a low pressure and discharges it through a discharge pipe 428 at a high pressure by passing the fluid (as shown by the arrows) along a long cylindrical pipe or barrel 430 having a series of impellers or rotors 432.', 'That is, as the fluid is propelled by each successive impeller 432, it gains more and more pressure until it exits the pump at a much higher pressure than it entered.', 'To create a multistage centrifugal pump with a greater pressure output, the diameter of the impellers 432 may be increased and/or the number of impellers 432 (also referred to as the number of stages of the pump) may be increased.', '; FIG.', '7 shows an embodiment similar to that shown in FIG.', '5, but with differently configured clean pumps 701.', 'Note that many portions of the pump system 700 of FIG.', '7 may generally operate in the same manner as described above with respect to the pump system 300 of FIG.', '3.', 'Therefore, the operations of the pump system 700 of FIG.', '7 that are similar to the operations described above with respect to the pump system 300 of FIG.', '3 are not repeated here to avoid duplicity.', 'However, as mentioned above, a difference between the pump system 700 of FIG.', '7 and the pump system 300 of FIG.', '3 is that the clean pumps 701 on the clean side 305 of the pump system 700 of FIG.', '7 are multistage centrifugal pumps rather than plunger pumps.', 'In addition, although the clean pumps 501/701 in the pump systems 500/700 of both FIGS. 5 and 7 are multistage centrifugal pumps, the multistage centrifugal pumps in the pump system 700 of FIG.', '7 are configured differently than the multistage centrifugal pumps of FIG.', '5.; FIG. 9 shows an embodiment similar to that shown in FIG.', '5, but with yet another configuration of clean pumps 901.', 'Note that many portions of the pump system 900 of FIG.', '9 may generally operate in the same manner as described above with respect to the pump system 300 of FIG.', '3.', 'Therefore, the operations of the pump system 900 of FIG.', '9 that are similar to the operations described above with respect to the pump system 300 of FIG.', '3 are not repeated here to avoid duplicity.', 'However, as mentioned above, a difference between the pump system 900 of FIG.', '9 and the pump system 300 of FIG.', '3 is that the clean pumps 901 on the clean side 305 of the pump system 900 of FIG.', '9 are multistage centrifugal pumps rather than plunger pumps.', 'In addition, although the clean pumps 501/901 in the pump systems 500/900 of both FIGS.', '5 and 9 are multistage centrifugal pumps, the multistage centrifugal pumps in the pump system 900 of FIG.', '9 are configured differently than the multistage centrifugal pumps of FIG.', '5.; FIG.', '12 shows another embodiment of a pump system 1200 according to the present invention wherein the fluid to be pumped (such as a fracturing fluid) is split into a clean side 305 containing primarily water that is pumped by one or more clean pumps 1201, and a dirty side 305′ containing solids in a fluid carrier (for example, a proppant in a gelled water) that is pumped by one or more dirty pumps 1201′.']

US11927064

Unified setting tool and wireline adapter kit

Sep 14, 2021

Bhushan Pendse, Laurent Alteirac, Robert M. Graham

SCHLUMBERGER TECHNOLOGY CORPORATION

Notice of Allowance issued in U.S. Appl. No. 16/599,381 dated Apr. 12, 2022, 12 pages.; Action issued in the related U.S. Appl. No. 16/599,381, dated Nov. 5, 2021 (8 pages).; Office Action issued in the related U.S. Appl. No. 16/599,381, dated Jan. 28, 2022, 9 pages.

3002559; October 1961; Hanes; 3387659; June 1968; Current; 9810035; November 7, 2017; Carr et al.; 10927627; February 23, 2021; Eitschberger; 10934794; March 2, 2021; Knight et al.; 10934795; March 2, 2021; Wells; 11047188; June 29, 2021; Wells; 11066886; July 20, 2021; Mickey; 11255147; February 22, 2022; Eitschberger; 11280143; March 22, 2022; Robicheaux; 11401761; August 2, 2022; Flores Perez; 11578549; February 14, 2023; Eitschberger; 20070151722; July 5, 2007; Lehr et al.; 20190277103; September 12, 2019; Wells; 20200095838; March 26, 2020; Baker; 20200115977; April 16, 2020; Norrid et al.; 20220127919; April 28, 2022; Gleason

Foreign Citations not found.

['A system includes a setting tool, which includes a housing, a piston, and an inner mandrel, and a settable device.', 'The housing includes a first section configured as a setting sleeve, an intermediate section, and a second section.', 'The piston includes an interior power charge chamber and a piston housing including at least one passage in fluid communication with the power charge chamber that interfaces with a top face of the intermediate section of the housing.', 'The piston is mounted within a second bore of the second section via an anti-present mechanism.', 'The inner mandrel is received in the second bore within a bottom recess of the piston housing and extends longitudinally through bores of the intermediate and first sections.', 'At least a portion of the system is adjustable to eliminate a gap between the setting sleeve and a top of the settable device mounted on the inner mandrel.']

['Description\n\n\n\n\n\n\nCROSS REFERENCE TO RELATED APPLICATIONS', 'The present application claims priority benefit of U.S. Provisional Application No. 63/077,767, filed Sep. 14, 2020, the entirety of which is incorporated by reference herein and should be considered part of this specification.', 'BACKGROUND', 'In many hydrocarbon well applications, various types of tools may be delivered downhole and set in a wellbore.', 'For example, frac plugs or other types of sealing devices may be delivered downhole via wireline and set against a surrounding wellbore surface.', 'The setting may be accomplished by a wireline adapter kit coupled with a wireline setting tool.', 'A firing head, coupled with the wireline, is used to actuate an explosive which drives the setting tool so as to set the sealing device, e.g. plug, in the wellbore via the wireline adapter kit.', 'However, the combination of the wireline adapter kit and the separate setting tool may introduce complexity and cause inconsistent setting of the sealing device.', 'Accordingly, there is a need to streamline the setting tool and improve the setting of sealing devices in a wellbore.', 'SUMMARY', 'According to one or more embodiments of the present disclosure, a system to facilitate actuation in a borehole includes: a setting tool including: a housing including: a first section having a first bore therethrough; an intermediate section having an intermediate bore therethrough; and a second section having a second bore therethrough, wherein the first, intermediate, and second sections of the housing are integrated into a single piece, and wherein the first section is configured as a setting sleeve; a piston including: a piston housing; and an interior power charge chamber, wherein the piston housing comprises at least one passage in fluid communication with the power charge chamber that interfaces with a top face of the intermediate section of the housing, and wherein the piston is mounted within the second bore via an anti-preset mechanism affixed between the second section of the housing and an outer surface of the piston housing; and an inner mandrel slidably received in the second bore within a bottom recess of the piston housing, the inner mandrel extending longitudinally through the intermediate bore and the first bore, wherein a stem of the inner mandrel extends beyond the first bore; and a settable device mounted on the stem of the inner mandrel, wherein at least a portion of the inner mandrel is adjustable via a spring element to eliminate a gap between the setting sleeve and a top of the settable device mounted on the stem of the inner mandrel.', 'According to one or more embodiments of the present disclosure, a system to facilitate actuation in a borehole includes a setting tool including: a housing; and an inner mandrel fixed to the housing; a settable device mounted on a stem of the inner mandrel; and at least one spacer disposed on the inner mandrel that adjusts for a gap between the housing and the settable device.', 'According to one or more embodiments of the present disclosure, a system to facilitate actuation in a borehole includes a setting tool including: a housing including: a first piece including: a first section having a first bore therethrough; an intermediate section having an intermediate bore therethrough; and a second section having a second bore therethrough; and a second piece comprising a gauge ring positioned over and affixed to the first section of the first piece of the housing, a piston including: a piston housing; and an interior power charge chamber, wherein the piston housing comprises at least one passage in fluid communication with the power charge chamber that interfaces with a top face of the intermediate section of the housing, and wherein the piston is mounted within the second bore via an anti-preset mechanism affixed between the second section of the housing and an outer surface of the piston housing; and an inner mandrel received in the second bore within a bottom recess of the piston housing, the inner mandrel extending longitudinally through the intermediate bore and the first bore, wherein a stem of the inner mandrel extends beyond the first bore; and a settable device mounted on the stem of the inner mandrel, wherein the gauge ring is adjustable to eliminate a gap between the gauge ring and a top of the settable deice mounted on the stem of the inner mandrel.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having an adjustable inner mandrel, according to one or more embodiments of the present disclosure;\n \nFIG.', '2\n is a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having a two piece inner mandrel, according to one or more embodiments of the present disclosure;\n \nFIG.', '3\n is a simplified illustration of a settable device, e.g., a plug, mounted on an inner mandrel, according to one or more embodiments of the present disclosure; and\n \nFIG.', '4\n is a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having a two piece housing, according to one or more embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'The present disclosure generally relates to systems and methods that facilitate improved setting of downhole devices.', 'Examples of such downhole devices include frac plugs, other types of plugs, packers, or other devices which may be deployed via wireline and set downhole.', 'The technique according to one or more embodiments of the present disclosure utilizes a unified setting tool and wireline adapter kit to provide a compact disposable solution for effectively setting downhole devices.', 'Referring now to \nFIG.', '1\n, a cross-sectional view of a settable device, e.g., a plug coupled with a unified setting tool and wireline adapter kit having an adjustable inner mandrel, according to one or more embodiments of the present disclosure is shown.', 'As shown in \nFIG. \n1\n, the system \n10\n according to one or more embodiments of the present disclosure includes a setting tool \n12\n and a settable device \n14\n.', 'Although \nFIG. \n1\n shows that the settable device \n14\n may be a plug, the settable device \n14\n may also be a packer, or other device that may be deployed via wireline and set downhole, for example.', 'Still referring to \nFIG.', '1\n, the setting tool \n12\n may include a housing \n16\n, a piston \n18\n, and an inner mandrel \n20\n, according to one or more embodiments of the present disclosure.', 'As shown in \nFIG. \n1\n, the housing \n16\n of the setting tool \n12\n may include a first section \n16\na\n, a second section \n16\nb\n, and an intermediate section \n16\nc \nbetween the first section \n16\na \nand the second section \n16\nb\n.', 'Further, the first section \n16\na \nmay include a first bore \n17\na \ntherethrough, the second section \n16\nb \nmay include a second bore \n17\nb \ntherethrough, and the intermediate section \n16\nc \nmay include an intermediate bore \n17\nc \ntherethrough.', 'According to one or more embodiments of the present disclosure, the first section \n16\na\n, the second section \n16\nb\n, and the intermediate section \n16\nc \nof the housing \n16\n are integrated into a single piece.', 'Further, the first section \n16\na \nof the housing \n16\n may be configured as a setting sleeve to facilitate setting of the settable device \n14\n in accordance with one or more embodiments of the present disclosure.', 'Still referring to \nFIG.', '1\n, the piston \n18\n of the setting tool \n12\n may include a piston housing \n19\n, and an interior power charge chamber \n22\n according to one or more embodiments of the present disclosure.', 'Further, the piston housing \n19\n of the piston \n18\n may include at least one passage \n24\n in fluid communication with the power charge chamber \n22\n that interfaces with a top face \n26\n of the intermediate section \n16\nc \nof the housing \n16\n of the setting tool \n12\n, in accordance with one or more embodiments of the present disclosure.', 'As further shown in \nFIG.', '1\n, the piston \n18\n may be mounted within the second bore \n17\nb \nof the second section \n16\nb \nof the housing \n16\n via an anti-preset mechanism \n28\n affixed between the second section \n16\nb \nof the housing \n16\n and an outer surface of the piston housing \n19\n.', 'In one or more embodiments of the present disclosure, the anti-preset mechanism \n28\n may be a shear screw or a shear pin, for example.', 'As also shown in \nFIG. \n1\n, at least one seal \n36\n may be disposed between the outer surface of the piston housing \n19\n and the housing \n16\n of the setting tool \n12\n.', 'Still referring to \nFIG.', '1\n, the inner mandrel \n20\n of the setting tool \n12\n may be slidably received in the second bore \n17\nb \nwithin a bottom recess \n30\n of the piston housing \n19\n, and the inner mandrel \n20\n may extend longitudinally through the intermediate bore \n17\nc \nof the intermediate section \n16\nc \nand the first bore \n17\na \nof the first section \n16\na \nof the housing \n16\n.', 'As further shown in \nFIG. \n1\n, at least one seal \n36\n may be disposed between the inner mandrel \n20\n and the intermediate section \n16\nc \nof the housing \n16\n, according to one or more embodiments of the present disclosure.', 'As further shown in \nFIG.', '1\n, a stem \n32\n of the inner mandrel \n20\n may extend beyond the first bore \n17\na \nof the first section \n16\na \nof the housing, in one or more embodiments of the present disclosure, which allows the settable device \n14\n to be mounted on the stem \n32\n of the inner mandrel \n20\n.', 'According to one or more embodiments of the present disclosure, the settable device \n14\n may be mounted on the stem \n32\n of the inner mandrel \n20\n with a fastener \n31\n, such as a nut, for example.', 'In one or more embodiments of the present disclosure, the inner mandrel \n20\n may be a tension mandrel, for example.', 'According to one or more embodiments of the present disclosure, at least a portion of the inner mandrel \n20\n is adjustable via a spring element \n34\n to eliminate a gap between the setting sleeve of the first section \n16\na \nand a top of the settable device \n14\n when the settable device \n14\n is mounted on the stem \n32\n of the inner mandrel \n20\n.', 'According to one or more embodiments of the present disclosure, the spring element \n34\n may be a weak coil, or a wave spring, for example.', 'As shown in \nFIG. \n1\n, the spring element \n34\n may be disposed within the bottom recess \n30\n of the piston housing \n19\n such that the spring element \n34\n contacts a top end of the inner mandrel \n20\n, according to one or more embodiments of the present disclosure.', 'Still referring to \nFIG.', '1\n, the setting tool \n12\n according to one or more embodiments of the present disclosure may also include a firing head adapter \n38\n connected to the piston \n18\n for receiving a firing head, which may ignite a setting charge disposed in the power charge chamber \n22\n.', 'In one or more embodiments of the present disclosure, burning of the setting charge releases pressurized gas into the power charge chamber \n22\n, and the pressurized gas may flow into the at least one passage \n24\n in the piston housing \n19\n.', 'As the pressurized gas fills the at least one passage \n24\n in the piston housing \n19\n, the force of the pressurized gas presses against the top face \n26\n of the intermediate section \n16\nc \nof the housing \n16\n until the force is strong enough to overcome the anti-preset mechanism \n28\n.', 'Once the anti-preset mechanism \n28\n shears, breaks, or bursts, the setting tool \n12\n moves downward, causing the setting sleeve of the first section \n16\na \nto push on the top of the settable device \n14\n, which sets the settable device \n14\n.', 'Referring now to \nFIG.', '2\n, a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having an adjustable two piece inner mandrel, according to one or more embodiments of the present disclosure is shown.', 'For the sake of clarity, only the differences between the system \n10\n shown in \nFIG.', '2\n and the system \n10\n shown in \nFIG.', '1\n will be described here.', 'As shown in \nFIG.', '2\n, the inner mandrel \n20\n according to one or more embodiments of the present disclosure may include a fixed portion \n20\na \nand an adjustable portion \n20\nb\n, and the stem \n32\n of the inner mandrel \n20\n is included in the adjustable portion \n20\nb\n.', 'In such embodiments of the present disclosure, the spring element \n34\n may be disposed between the fixed portion \n20\na \nand the adjustable portion \n20\nb \nof the inner mandrel \n20\n.', 'Due to the adjustability of the adjustable portion \n20\nb \nof the inner mandrel \n20\n via the spring element \n34\n, the system \n10\n may be assembled in such a way as to eliminate any gap between the setting sleeve of the first section \n16\na \nand a top of the settable device \n14\n when the settable device \n14\n is mounted on the stem \n32\n of the inner mandrel \n20\n in one or more embodiments of the present disclosure.', 'Referring now to \nFIG.', '3\n, a simplified illustration of a settable device, e.g., a plug, mounted on an inner mandrel, according to one or more embodiments of the present disclosure is shown.', 'As shown in \nFIG. \n3\n, the system \n10\n includes a setting tool \n12\n including a housing \n16\n and an inner mandrel \n20\n fixed to the housing \n16\n.', 'According to one or more embodiments of the present disclosure, the inner mandrel \n20\n may be a tension mandrel, for example.', 'As further shown in \nFIG.', '3\n, a settable device \n14\n, which may be a plug, a packer, or any other device that may be deployed via wireline and set downhole, is mounted on a stem \n32\n of the inner mandrel \n20\n.', 'In one or more embodiments of the present disclosure, the settable device \n14\n may include a ring \n15\n, such as a brass ring, for example, disposed at a top of the settable device \n14\n.', 'The system \n10\n according to one or more embodiments of the present disclosure may also include at least one spacer \n40\n on the inner mandrel \n20\n that adjusts for a gap between the housing \n16\n and the settable device \n14\n.', 'Referring now to \nFIG.', '4\n, a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having a two piece housing, according to one or more embodiments of the present disclosure is shown.', 'As shown in \nFIG.', '4\n, the system \n10\n according to one or more embodiments of the present disclosure includes a setting tool \n12\n and a settable device \n14\n.', 'Although \nFIG.', '4\n shows that the settable device \n14\n may be a plug, the settable device \n14\n may also be a packer, or other device that may be deployed via wireline and set downhole, for example.', 'Still referring to \nFIG.', '4\n, the setting tool \n12\n may include a housing \n16\n including a first piece \n42\n and a second piece \n44\n.', 'That is, the system \n10\n according to one or more embodiments of the present disclosure includes a setting tool \n12\n having a two piece housing \n16\n.', 'In one or more embodiments of the present disclosure, the first piece \n42\n of the two piece housing \n16\n includes a first section \n16\na\n, a second section \n16\nb\n, and an intermediate section \n16\nc \nbetween the first section \n16\na \nand the second section \n16\nb\n.', 'Further, the first section \n16\na \nmay include a first bore \n17\na \ntherethrough, the second section \n16\nb \nmay include a second bore \n17\nb \ntherethrough, and the intermediate section \n16\nc \nmay include an intermediate bore \n17\nc \ntherethrough.', 'According to one or more embodiments of the present disclosure, the first section \n16\na\n, the second section \n16\nb\n, and the intermediate section \n16\nc \nof the housing \n16\n are integrated into the first piece \n42\n.', 'As also shown in \nFIG. \n4\n, the second piece \n44\n of the housing \n16\n includes a gauge ring positioned over the first section \n16\na \nof the first piece \n42\n of the housing \n16\n and affixed thereto.', 'According to one or more embodiments of the present disclosure, the gauge ring \n44\n is adjustable and may be affixed to the first section \n16\na \nvia at least one fastener \n46\n, such as a set screw, for example.', 'In one or more embodiments of the present disclosure, the gauge ring \n44\n facilitates setting of the settable device \n14\n, as further described below.', 'Moreover, due to the adjustability of the gauge ring \n44\n, the system \n10\n may be assembled in such a way as to eliminate any gap between the gauge ring \n44\n of the second piece of the housing \n16\n and a top of the settable device \n14\n when the settable device \n14\n is mounted on the stem \n32\n of the inner mandrel \n20\n in one or more embodiments of the present disclosure.', 'Still referring to \nFIG.', '4\n, the piston \n18\n of the setting tool \n12\n may include a piston housing \n19\n, and an interior power charge chamber \n22\n according to one or more embodiments of the present disclosure.', 'Further, the piston housing \n19\n of the piston \n18\n may include at least one passage \n24\n in fluid communication with the power charge chamber \n22\n that interfaces with a top face \n26\n of the intermediate section \n16\nc \nof the housing \n16\n of the setting tool \n12\n, in accordance with one or more embodiments of the present disclosure.', 'As further shown in \nFIG. \n4\n, the piston \n18\n may be mounted within the second bore \n17\nb \nof the second section \n16\nb \nof the housing \n16\n via an anti-preset mechanism \n28\n affixed between the second section \n16\nb \nof the housing \n16\n and an outer surface of the piston housing \n19\n.', 'In one or more embodiments of the present disclosure, the anti-preset mechanism \n28\n may be a shear screw or a shear pin, for example.', 'As also shown in \nFIG. \n4\n, at least one seal \n36\n may be disposed between the outer surface of the piston housing \n19\n and the housing \n16\n of the setting tool \n12\n.', 'Still referring to \nFIG.', '4\n, the inner mandrel \n20\n of the setting tool \n12\n may be received in the second bore \n17\nb \nwithin a bottom recess \n30\n of the piston housing \n19\n, and the inner mandrel \n20\n may extend longitudinally through the intermediate bore \n17\nc \nof the intermediate section \n16\nc \nand the first bore \n17\na \nof the first section \n16\na \nof the housing \n16\n.', 'As further shown in \nFIG. \n4\n, at least one seal \n36\n may be disposed between the inner mandrel \n20\n and the intermediate section \n16\nc \nof the housing \n16\n, according to one or more embodiments of the present disclosure.', 'As further shown in \nFIG. \n4\n, a stem \n32\n of the inner mandrel \n20\n may extend beyond the first bore \n17\na \nof the first section \n16\na \nof the housing, in one or more embodiments of the present disclosure, which allows the settable device \n14\n to be mounted on the stem \n32\n of the inner mandrel \n20\n.', 'According to one or more embodiments of the present disclosure, the settable device \n14\n may be mounted on the stem \n32\n of the inner mandrel \n20\n with a fastener \n31\n, such as a nut, for example.', 'In one or more embodiments of the present disclosure, the inner mandrel \n20\n may be a tension mandrel, for example.', 'According to one or more embodiments of the present disclosure, the inner mandrel \n20\n is fixed within the bottom recess \n30\n of the piston housing \n19\n and along its longitudinal length.', 'Still referring to \nFIG.', '4\n, the setting tool \n12\n according to one or more embodiments of the present disclosure may also include a firing head adapter \n38\n connected to the piston \n18\n for receiving a firing head, which may ignite a setting charge disposed in the power charge chamber \n22\n.', 'In one or more embodiments of the present disclosure, burning of the setting charge releases pressurized gas into the power charge chamber \n22\n, and the pressurized gas may flow into the at least one passage \n24\n in the piston housing \n19\n.', 'As the pressurized gas fills the at least one passage \n24\n in the piston housing \n19\n, the force of the pressurized gas presses against the top face \n26\n of the intermediate section \n16\nc \nof the housing \n16\n until the force is strong enough to overcome the anti-preset mechanism \n28\n.', 'Once the anti-preset mechanism \n28\n shears, breaks, or bursts, the setting tool \n12\n moves downward, causing the gauge ring \n44\n of the second piece of the housing \n16\n to push on top of the settable device \n14\n, which sets the settable device \n14\n.', 'As previously described, the unified setting tool and wireline adapter kit according to one or more embodiments of the present disclosure is adjustable, either via the inner mandrel \n20\n, at least one spacer \n40\n, or a gauge ring \n44\n as part of a two piece housing \n16\n, in order to eliminate any gap between the setting tool \n12\n and the settable device \n14\n during assembly and before the system \n10\n is deployed into the borehole.', 'Advantageously, these adjustable configurations of the unified setting tool and wireline adapter kit prevent unwanted debris from entering the system \n10\n between the setting tool \n12\n and the settable device \n14\n while running in hole, ensure consistent contact between the setting tool \n12\n and the settable device \n14\n, and prevent inconsistent setting of the settable device \n14\n by the setting tool \n12\n.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A system to facilitate actuation in a borehole, comprising:\na setting tool comprising: a housing comprising: a first section having a first bore therethrough; an intermediate section having an intermediate bore therethrough; and a second section having a second bore therethrough, wherein the first, intermediate, and second sections of the housing are integrated into a single piece, and wherein the first section is configured as a setting sleeve; a piston comprising: a piston housing; and an interior power charge chamber, wherein the piston housing comprises at least one passage in fluid communication with the power charge chamber that interfaces with a top face of the intermediate section of the housing, and wherein the piston is mounted within the second bore via an anti-preset mechanism affixed between the second section of the housing and an outer surface of the piston housing; and an inner mandrel slidably received in the second bore within a bottom recess of the piston housing, the inner mandrel extending longitudinally through the intermediate bore and the first bore, wherein a stem of the inner mandrel extends beyond the first bore; and\na settable device mounted on the stem of the inner mandrel, wherein at least a portion of the inner mandrel is adjustable via a spring element to eliminate a gap between the setting sleeve and a top of the settable device mounted on the stem of the inner mandrel.', '2.', 'The system of claim 1, wherein the spring element is disposed within the bottom recess of the piston housing such that the spring element contacts a top end of the inner mandrel.', '3.', 'The system of claim 1,\nwherein the inner mandrel comprises a fixed portion and an adjustable portion,\nwherein the stem of the inner mandrel is included in the adjustable portion, and\nwherein the spring element is disposed between the fixed portion and the adjustable portion of the inner mandrel.', '4.', 'The system of claim 1, further comprising a firing head adapter connected to the piston for receiving a firing head.', '5.', 'The system of claim 1, wherein the inner mandrel is a tension mandrel.', '6.', 'The system of claim 1,\nwherein pressurized gas resulting from an ignited setting charge disposed in the power charge chamber enters the at least one passage, and\nwherein force from the pressurized gas presses against the top face of the intermediate section of the housing, overcoming the anti-preset mechanism and moving the setting tool downward, which causes the setting sleeve to push on the top of the settable device, thereby setting the settable device.', '7.', 'The system of claim 6, wherein the anti-preset mechanism is a shear screw.', '8.', 'The system of claim 1, wherein at least one seal is disposed between the outer surface of the piston housing and the housing of the setting tool.', '9.', 'The system of claim 1, wherein at least one seal is disposed between the inner mandrel and the intermediate section of the housing.', '10.', 'A system to facilitate actuation in a borehole, comprising:\na setting tool comprising: a housing comprising: a first piece comprising: a first section having a first bore therethrough; an intermediate section having an intermediate bore therethrough; and a second section having a second bore therethrough; and a second piece comprising a gauge ring positioned over and affixed to the first section of the first piece of the housing, a piston comprising: a piston housing; and an interior power charge chamber, wherein the piston housing comprises at least one passage in fluid communication with the power charge chamber that interfaces with a top face of the intermediate section of the housing, and wherein the piston is mounted within the second bore via an anti-preset mechanism affixed between the second section of the housing and an outer surface of the piston housing; and an inner mandrel received in the second bore within a bottom recess of the piston housing, the inner mandrel extending longitudinally through the intermediate bore and the first bore, wherein a stem of the inner mandrel extends beyond the first bore; and\na settable device mounted on the stem of the inner mandrel, wherein the gauge ring is adjustable to eliminate a gap between the gauge ring and a top of the settable device mounted on the stem of the inner mandrel.', '11.', 'The system of claim 10, wherein the inner mandrel is fixed.', '12.', 'The system of claim 10, wherein the inner mandrel is a tension mandrel.', '13.', 'The system of claim 10, further comprising a firing head adapter connected to the piston for receiving a firing head.', '14.', 'The system of claim 10,\nwherein pressurized gas resulting from an ignited setting charge disposed in the power charge chamber enters the at least one passage, and\nwherein force from the pressurized gas presses against the top face of the intermediate section of the housing, overcoming the anti-preset mechanism and moving the setting tool downward, which causes the gauge ring to push on the top of the settable device, thereby setting the settable device.', '15.', 'The system of claim 14, wherein the anti-preset mechanism is a shear screw.', '16.', 'The system of claim 10, wherein at least one seal is disposed between the outer surface of the piston housing and the housing of the setting tool.', '17.', 'The system of claim 10, wherein at least one seal is disposed between the inner mandrel and the intermediate section of the housing.']

['FIG.', '1 is a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having an adjustable inner mandrel, according to one or more embodiments of the present disclosure;; FIG.', '2 is a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having a two piece inner mandrel, according to one or more embodiments of the present disclosure;; FIG.', '3 is a simplified illustration of a settable device, e.g., a plug, mounted on an inner mandrel, according to one or more embodiments of the present disclosure; and; FIG.', '4 is a cross-sectional view of a settable device, e.g., a plug, coupled with a unified setting tool and wireline adapter kit having a two piece housing, according to one or more embodiments of the present disclosure.']

US11692425

Method and downhole apparatus to accelerate wormhole initiation and propagation during matrix acidizing of a subterranean rock formation

Apr 19, 2021

Ziad Sidaoui, Mustapha Abbad

SCHLUMBERGER TECHNOLOGY CORPORATION

Buijse, M. A.,“Understanding wormholing mechanisms can improve acid treatments in carbonate formations”, SPE-65068-PA, SPE Production Facilities, 2020, 15(3), pp. 168-175.; Chilingar, et al. “Improving Acidizing Operations”, Journal of Sustainable Energy Engineering, 2013, (1(3), pp. 193-197.; Fredd, C. N. et al, “Influence of Transport and Reaction on Wormhole Formation in Carbonate Porous Media”, AlChE Journal, 1998, 44(9), pp. 1933-1949.; Ghommem, M. et al., “Carbonate Acidizing: Modeling, analysis, and characterization of wormhole formation and propagation”, Journal of Petroleum Science and Engineering, 2015, 131, pp. 18-33.; Golfier, F. et al., “Acidizing Carbonate Reservoirs: Numerical Modelling of Wormhole Propagation and Comparison to Experiments”, SPE 68922, presented at the 2001 SPE European Formation Damage Conference, The Hague, The Netherlands, 11 pages.; Gong, M. et al. “Quantitative Model of Wormholing Process in Carbonate Acidizing”, SPE 52165, presented at the 1999 SPE Mid-Continent Operations Symposium, Oklahoma City, Oklahoma, U.S.A., 11 pages.; Liu, M. et al., “Wormhole Propagation Behaviour Under Reservoir Condition in Carbonate Acidizing,” Transport in Porous Media, 2013, 96, pp. 203-220.; Panga, M. K. R. et al., “Two-scale continuum model in simulation of wormholes in carbonate acidization”, AlChE Journal, 2005, pp. 3231-3248.; Ratnaker, R. R. et al., “Modeling, Analysis, and Simulation of Wormhole Formation in Carbonates Rocks with in situ Cross-linked Acids”, Chemical Engineering Science, 2013, 90, pp. 179-199.; Tardy, P. M.J. et al., “An Experimentally Validated Wormhole Model for Self-Diverting and Conventional Acids in Carbonate Rocks Under Radial Flow Conditions”, SPE 107854, presented at the 2007 European Formation Damage Conference, Scheveningen, The Netherlands, 17 pages.; Wong, S.-U. et al., Near Wellbore Stimulation by Acoustic Waves, SPE 82198, presented at the 2003 SPE European Formation Damage Conference, The Hague, The Netherlands, 6 pages.

3050122; August 1962; Huitt; 3211221; October 1965; Huitt; 3393736; July 1968; Goodwin; 4673890; June 16, 1987; Copland; 4974675; December 4, 1990; Austin et al.; 9529112; December 27, 2016; Qiu et al.; 10612355; April 7, 2020; Alruwaili; 20110284232; November 24, 2011; Huang; 20130199789; August 8, 2013; Liang; 20150345267; December 3, 2015; Modavi; 20160024914; January 28, 2016; Ghommem et al.; 20210054735; February 25, 2021; Alruwaili; 20210062073; March 4, 2021; Gomaa; 20210122970; April 29, 2021; Mahmoud

WO-2015089669; June 2015; WO

['The present disclosure relates to downhole tools and related methods that accelerate wormhole initiation and propagation during matrix acidizing of a hydrocarbon-bearing subterranean rock formation.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION(S)\n \nThe subject disclosure claims priority from U.S. Provisional Appl.', 'No. 63/060,688, filed on Aug. 4, 2020,', 'herein incorporated by reference in its entirety.', 'FIELD\n \nThe subject disclosure relates to matrix acidizing operations that enhance recovery of hydrocarbons from subterranean rock formations.', 'BACKGROUND\n \nThe rate of hydrocarbon recovery from hydrocarbon-bearing subterranean rock formations (i.e., subterranean hydrocarbon reservoirs) is governed by the interplay of viscous and capillary forces that determine fluid transport in porous media, and several enhanced recovery techniques have been devised to increase the rate and completeness of fluid transport.', 'One type of enhanced recovery technique is commonly referred to as matrix acidizing, which involves the supply or injection of fluidic chemical agents such as acids and other materials into the near-wellbore area of a hydrocarbon-bearing subterranean rock formation at pressures below formation fracture pressure to restore or enhance the permeability of the rock formation.', 'The matrix acidizing is often carried out following damage to the near-wellbore area following drilling and fracturing operations.', 'As the fluidic chemical agent (referred to herein as a “stimulating fluid”) contacts the rock formation at a treatment site or zone, formation rock (often carbonates) at or near the treatment site or zone can react to the stimulating fluid and undergo dissolution reactions that produce highly permeable channels or “wormholes” that enable fluid transport through the rock formation.', 'Successful matrix acidizing is often characterized by the production of dominant wormholes that may have some degree of branching but extend into the rock formation and consume minimal amounts of stimulating fluid.', 'Although matrix acidizing is relatively common, the evaluation of the matrix acidizing process and recovery enhancement is difficult to characterize.', 'Some common parameters monitored during a matrix acidizing process include injection pressure, injection rate, downhole pressures, and distributed temperature, which can be related to the extent of the reaction of the formation rock with the stimulating fluid.', 'However, techniques such as temperature monitoring are unreliable in many circumstances, and improper stimulation and zonal coverage may not be discovered until the production phase, when remediation is expensive and time consuming.', 'It is important to optimize the efficiency of the matrix acidizing operations.', 'SUMMARY', 'In an embodiment, a method is provided for stimulating recovery of hydrocarbons from a subterranean rock formation traversed by a wellbore, which involves deploying a downhole tool at a treatment zone of the wellbore.', 'The downhole tool is operated to create at least one notch in a wellbore surface at the treatment zone and to inject or supply a stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure.', 'The notch facilitates wormhole formation at a corresponding position of the notch arising from dissolution of rock caused by reaction of the rock with the stimulating fluid.', 'In embodiments, the notch can facilitate wormhole formation by jump-starting wormhole initiation.', 'In embodiments, the notch can reduce an induction time period.', 'In embodiments, the notch can provide for controlled placement of a corresponding wormhole.', 'In embodiments, the notch can provide for reducing volume of the stimulation fluid injected into the wellbore as compared to a volume of the stimulation fluid injected into the wellbore where no notches are present.', 'In embodiments, the notch can be created by a nozzle structure that is configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface.', 'In embodiments, the downhole tool can be operated to create the at least one notch prior to supplying the stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure.', 'In embodiments, the downhole tool can be operated to create the at least one notch simultaneously with supplying the stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure.', 'In embodiments, the downhole tool can be operated to create the at least one notch and supply the stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure after isolating the treatment zone of the wellbore.', 'In embodiments, the operation of the downhole tool can create a plurality of notches in the wellbore surface of the treatment zone, wherein the plurality of notches facilitates wormhole formation at corresponding positions of the plurality of notches.', 'In embodiments, the plurality of notches can be created by a plurality of nozzle structures each configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface.', 'In embodiments, the stimulating fluid can include an acid component.', 'In embodiments, a downhole tool is provided that is deployable in a wellbore that traverses a subterranean rock formation traversed by a wellbore.', 'The downhole tool can be used to stimulate recovery of hydrocarbons from the subterranean rock formation.', 'The downhole tool can be configured to create at least one notch in a wellbore surface at a treatment zone and to supply a stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure in a single run.', 'The notch facilitates wormhole formation at a corresponding position of the notch arising from dissolution of rock caused by reaction of the rock with the stimulating fluid.', 'In embodiments, the downhole tool can include packers spaced apart from one another and configured to isolates the treatment zone.', 'In embodiments, the downhole tool can include a sliding sleeve configured to selectively inject the stimulating fluid into the treatment zone.', 'In embodiments, the downhole tool can include at least one nozzle structure supported by at least one moveable arm, wherein the nozzle structure is configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface to create the notch.', 'In embodiments, the at least one moveable arm can be configured for radial movement to permit the at least one nozzle structure to contact the wellbore surface.', 'In embodiments, the at least one moveable arm can include at least one internal fluid passageway configured to carry stimulating fluid to the at least one nozzle structure.', 'In embodiments, the at least one moveable arm can include at least one nozzle valve in fluid communication with the at least one internal fluid passageway, wherein the at least one nozzle valve is configured to selectively supply stimulating fluid to the at least one nozzle structure via the at least one internal fluid passageway.', 'In embodiments, the nozzle structure can include at least one pad disposed about a nozzle exit.', 'The at least one pad can be configured to contact the wellbore surface and provide a stand-off distance between the wellbore surface and the nozzle exit.', 'In embodiments, the nozzle structure can be configured such that the stand-off distance is fixed.', 'In embodiments, the nozzle structure can be configured such that the stand-off distance is adjustable by hydraulic operation or electromechanical operation.', 'In embodiments, the nozzle structure can be configured to provide a flow path of stimulating fluid leading to the nozzle exit, wherein the flow path has decreasing cross-sectional size over its length such that pressure and velocity of stimulating fluid increases over the flow path and exits from the nozzle exit at sufficient pressure and velocity to create a notch in the wellbore surface.', 'In embodiments, the downhole tool can include a plurality of nozzle structures supported by at least one moveable arm, wherein each nozzle structure is configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface to create a plurality of notches.', 'In embodiments, the plurality of nozzle structures can be supported by a plurality of moveable arms.', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'BRIEF DESCRIPTION OF DRAWINGS', 'The subject disclosure is further described in the detailed description below, in reference to the noted plurality of drawings by way of non-limiting examples of the subject disclosure, in which like reference numerals represent similar parts throughout the several views of the following drawings, and wherein:\n \nFIG.', '1\n is a schematic diagram of a wellsite with equipment provided for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation;\n \nFIGS.', '2\nA and \n2\nB\n are schematic diagrams of an illustrative downhole tool for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation;\n \nFIGS.', '3\nA and \n3\nB\n are schematic diagrams of another illustrative downhole tool for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation;\n \nFIGS.', '4\nA and \n4\nB\n are schematic diagrams of yet another illustrative downhole tool for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation; and\n \nFIG.', '5\n illustrates a schematic view of a computing system according to an embodiment of the present disclosure.', 'DETAILED DESCRIPTION', 'The particulars shown herein are by way of example and for purposes of illustrative discussion of the embodiments of the subject disclosure only and are presented in the cause of providing what is believed to be the most useful and readily understood description of the principles and conceptual aspects of the subject disclosure.', 'In this regard, no attempt is made to show structural details in more detail than is necessary for the fundamental understanding of the subject disclosure, the description taken with the drawings making apparent to those skilled in the art how the several forms of the subject disclosure may be embodied in practice.', 'Furthermore, like reference numbers and designations in the various drawings indicate like elements.', 'Matrix acidizing involves the injection or supply stimulating fluid (e.g. hydrochloric acid) into the near-wellbore area of a hydrocarbon-bearing subterranean rock formation at a pressure below the formation fracturing pressure.', 'As the stimulating fluid contacts the subterranean rock formation at a treatment site or zone, the formation rock (often carbonates) at or near the treatment site or zone can react to the stimulating fluid and undergo dissolution reactions that produce highly permeable channels or “wormholes” that extend radially (i.e., in a direction with a radial component orthogonal to the central axis of the wellbore) through the rock formation and enable fluid transport through the rock formation, which can restore or enhance the permeability of the rock formation.', 'In embodiments, the process that forms such wormholes at a treatment site or zone can be logically partitioned into two time periods: an induction time period and a wormholing time period.', 'The induction time period is the time from the first injection of the stimulation fluid to initiate one or more wormholes at the treatment site or zone.', 'The wormholing time period is the time period that one or more wormholes propagate by further dissolution of the formation rock and extend radially into the rock formation.', 'The volume of stimulation fluid injected during the induction time period can be greater than thirty percent of the total volume required for the matrix acidizing operations.', 'Hence, minimizing the induction time period can significantly reduce the cost and time of matrix acidizing operations.', 'In the subject disclosure, a method and a downhole tool are described.', 'The method and downhole tool create notches in a surface of a wellbore.', 'Each notch can facilitate wormhole formation at a corresponding position of the notch by jump-starting wormhole initiation (i.e., the dissolution of the formation rock) and reducing the induction time period.', 'In embodiments, the notches are created by one or more nozzle structures that are configured to direct a high-pressure flow or jet of stimulating fluid to a localized area of the wellbore surface.', 'The created notches establish a least resistant path to the stimulating fluid that contacts the wellbore surface during the matrix acidizing operation.', 'The created notches act as seeds for wormholes formed by the matrix acidizing operation and thus result in controlled placement of the wormholes and ultimately a reduction of the volume of the stimulating fluid required for the matrix acidizing operation.', 'Notching the formation has been applied to hydraulic fracturing because it creates weak points and reduces the pressure required to fracture the formation.', 'In the subject disclosure, a method and a downhole tool is provided for creating notches to accelerate wormhole initiation.', 'The resultant notches can minimize the required volume of stimulation fluid used for the matrix acidizing operation.', 'This is achieved by creating one or more notches in the wellbore surface prior to or while injecting the stimulation fluid.', 'Furthermore, this method enables more selective placement of the stimulating fluid.', 'The subject disclosure is based on mechanically inducing or creating shallow notches in a wellbore surface by employing a downhole tool prior to or while injecting stimulation fluid to direct the wormhole formation and propagation in the wellbore surface and to minimize the volume of stimulation fluid needed to do the operation.', 'In an embodiment, a downhole tool is provided that creates shallow notches in a wellbore surface and in the same run (of the tool) performs matrix acidizing operations to stimulate the formation.', 'FIG.', '1\n is a schematic diagram that illustrates an example onshore hydrocarbon', 'well location with surface equipment \n101\n above a hydrocarbon-bearing subterranean rock formation \n103\n after a drilling operation has been carried out.', 'At this stage, the wellbore \n105\n is filled with a fluid mixture \n107\n which is typically a mixture of drilling fluid and drilling mud.', 'In subsequent stages, the well is typically completed by running one or more casing strings in the wellbore \n105\n before cementing operations that cement the casting string(s) to the wellbore surface \n106\n.', 'In this example, the surface equipment \n101\n comprises a surface unit \n109\n and rig (or injector) \n111\n for deploying a downhole tool \n113\n in the wellbore \n105\n.', 'The surface unit \n109\n may be a vehicle coupled to the downhole tool \n113\n by coiled tubing or other tubing \n115\n.', 'Furthermore, the surface unit \n109\n can include an appropriate device for determining the depth position of the downhole tool \n113\n relative to the surface level.', 'In one embodiment illustrated in \nFIGS.', '2\nA and \n2\nB\n, the downhole tool \n113\n includes a bottom hole assembly (BHA) \n201\n supported by a connection to the coiled tubing \n115\n.', 'The BHA \n201\n includes one or more packers \n203\nA disposed at or near the connection to the coiled tubing \n115\n.', 'A tool housing \n205\n extends axially away from the connection to the coiled tubing \n115\n to a dummy tail \n207\n that supports one or more packer(s) \n203\nB.', 'In this manner, the packer(s) \n203\nA are spaced axially from the packer(s) \n203\nB.', 'As the BHA \n201\n is run in the wellbore \n105\n, the packers \n203\nA, \n203\nB can be activated to contact the wellbore wall \n106\n to isolate a treatment zone of the wellbore \n105\n, which is the annular space of the wellbore \n105\n between the packer(s) \n203\nA and the packer(s) \n203\nB.\n \nThe tool housing \n205\n has a central channel \n209\n that is in fluid communication with the interior tubular channel of the coiled tubing \n115\n.', 'During operations, stimulating fluid \n211\n is pumped from the surface by the surface equipment \n101\n through the interior tubular channel of the coiled tubing \n115\n and into the central channel \n209\n of the tool housing \n205\n.', 'The tool housing \n205\n supports an actuation system \n213\n and a sliding valve or sleeve \n215\n disposed between the packer(s) \n203\nA and the packer(s) \n203\nB such that the actuation system \n213\n and sliding valve \n215\n are operably disposed in the treatment zone of the wellbore \n105\n as shown.', 'During wormhole formation operations carried out by the tool (which encompass the induction and wormholing time periods as described herein), the movement of the sliding valve or sleeve \n215\n in a direction parallel to the central axis of the tool housing \n205\n can be actuated by the actuation system \n213\n to selectively open one or more ports \n217\n leading from central channel \n209\n of the tool housing \n205\n to the treatment zone to provide for flow of the stimulating fluid \n211\n from the central channel through the port(s) \n217\n and into the treatment zone.', 'Such movement can optionally provide for choking that can selectively vary the flow rate of the stimulating fluid \n211\n from the central channel \n209\n through the port(s) \n217\n and into the treatment zone.', 'The movement of the sliding valve or sleeve \n215\n in an opposite direction parallel to the central axis of the tool housing \n205\n can be actuated by the actuation system \n213\n to close the port(s) \n217\n to block the flow of the stimulating fluid from the central channel \n209\n and through the port(s) \n217\n.', 'The tool housing \n205\n further supports at least one arm (e.g., two arms shown as \n219\nA, \n219\nB) that are disposed about the exterior surface of the tool housing \n205\n between the packer(s) \n203\nA and the packer(s) \n203\nB such that the at least one arm is operably disposed in the treatment zone of the wellbore \n105\n.', 'In embodiments, the at least one arm (e.g., arms \n219\nA, \n219\nB) is disposed adjacent the sliding valve \n215\n as shown.', 'The least one arm (e.g., arms \n219\nA, \n219\nB) is configured such that it is actuated by the actuation system \n213\n to move radially away from the tool housing \n205\n toward the wellbore surface \n106\n (and also for opposite radial movement away from the wellbore surface \n106\n toward the tool housing \n105\n).', 'The at least one arm (e.g., arms \n219\nA, \n219\nB) supports at least one nozzle structure (e.g., two nozzle structures \n221\nA, \n221\nB).', 'The at least one arm (e.g., arm \n219\nA) also includes at least one internal fluid passageway \n223\n that extends between the at least one nozzle structure (e.g., two nozzle structures \n221\nA, \n221\nB) and corresponding nozzle valve(s) \n225\n fluidly coupled to the central channel \n209\n of the tool housing \n205\n.', 'The nozzle valve(s) \n225\n can be actuated by the actuation system \n213\n into an open configuration or closed configuration.', 'In the open configuration of the nozzle valve(s) \n225\n, stimulating fluid \n211\n flows from the central channel \n209\n and into the fluid passageway(s) \n223\n for supply to the at least one nozzle structure (e.g., two nozzle structures \n221\nA, \n221\nB).', 'In the closed configuration of the nozzle valve(s) \n225\n, the flow of stimulating fluid \n211\n from the central channel \n209\n and into the fluid passageway(s) \n223\n is blocked.', 'During a notching operation carried out by the tool, the at least one arm (e.g., arms \n219\nA, \n219\nB) can be moved radially such that the at least one nozzle structure (e.g., two nozzle structures \n221\nA, \n221\nB) contacts the wellbore surface \n106\n in the treatment zone and the nozzle valve(s) \n225\n can be actuated into the open configuration such that stimulating fluid \n211\n flows from the central channel \n209\n to the at least nozzle structure (e.g., two nozzle structures \n221\nA, \n221\nB).', 'The nozzle structure is configured to direct a high-pressure flow or jet of the stimulating fluid \n211\n to a localized area of the wellbore surface \n106\n adjacent the nozzle structure, which creates a shallow notch \n227\n that extends radially into the wellbore surface \n106\n as best shown in \nFIG.', '2\nB\n.', 'After the notching operation is completed, the at least one arm (e.g., arms \n219\nA, \n219\nB) can be configured such that it is actuated by the actuation system \n213\n to retract radial inward away from the wellbore surface \n106\n toward the tool housing \n105\n to permit axial movement of the BHA \n201\n and setting the BHA \n201\n at a desired interval of the wellbore \n105\n.', 'In the embodiment of \nFIGS.', '2\nA and \n2\nB\n, the nozzle structure (e.g., nozzle structure \n221\nA or \n221\nB) defines a fluid channel \n229\n with an inlet end in fluid communication with the passageway \n223\n.', 'The fluid channel \n229\n extends through the nozzle structure (for example, with a ninety-degree turn) to a nozzle exit \n231\n.', 'The fluid channel \n229\n provides a flow path of decreasing cross-sectional size over its length such that the pressure and velocity of the stimulating fluid increases over the flow path and exits from the nozzle exit \n231\n at sufficient pressure and velocity to create the desired notch in the wellbore surface \n106\n.', 'One or more pads \n233\n are disposed about the nozzle exit \n231\n and configured to extend radially and contact the wellbore surface \n106\n as shown.', 'The pad(s) \n233\n provide a predefined or fixed stand-off distance between the nozzle exit \n231\n and the wellbore surface \n106\n during the notching operation as best shown in \nFIG.', '2\nB\n.', 'The actuation system \n213\n can employ one or more electric motors (whether regular or a stepper motor) and solenoids (whether a single solenoid or multiple solenoids), and/or hydraulic systems, etc.', 'Electric power can be provided from a surface-located electrical power source and communicated downhole by conductors, or by a downhole electrical power source such as batteries or capacitors.', 'Hydraulic power can be provided from a surface-located hydraulic power source and communicated downhole by hydraulic lines, or by a downhole hydraulic power source such as a downhole hydraulic motor driven by the flow of stimulating fluid carried downhole to the tool by the coiled tubing.', 'The complexity of the actuation system \n213\n can vary and depend upon whether the sliding valve or sleeve, arm(s) and valves of the tool are actuated individually or in groups, which may require multiple actuator or bridging systems within the tool.', 'Multiple actuators may be staggered relative to one another to permit for integration as part of the tool.', 'In embodiments, the BHA \n201\n can be moved axially within the wellbore \n105\n and then set at a desired interval of the wellbore \n105\n by activating the packers \n203\nA, \n203\nB to contact the wellbore wall \n106\n to isolate a treatment zone of the wellbore \n105\n, which is the annular space of the wellbore \n105\n between the packer(s) \n203\nA and the packer(s) \n203\nB, and the stimulating fluid \n211\n can be supplied to the BHA \n201\n via the coiled tubing \n115\n.', 'The BHA \n201\n can be configured to perform the notching operation prior to wormhole formation operations as described herein.', 'During the notching operation, the sliding valve \n215\n can be positioned such that it closes the port(s) \n217\n to block the flow of the stimulating fluid \n211\n from the central channel \n209\n and through the port(s) \n217\n.', 'Furthermore, the at least one arm (e.g., arms \n219\nA, \n219\nB) can be moved radially such that the at least one nozzle structure (e.g., two nozzle structures \n221\nA, \n221\nB) contacts the wellbore surface \n106\n in the treatment zone and the nozzle valve(s) \n225\n can be actuated into its open configuration such that stimulating fluid \n211\n flows from the central channel \n209\n to the nozzle structure(s).', 'The or each nozzle structure is configured to direct a high-pressure flow of the stimulating fluid \n211\n to a localized area of the wellbore surface \n106\n adjacent the nozzle structure, which creates a shallow notch \n227\n that extends radially into the wellbore surface \n106\n as best shown in \nFIG.', '2\nB\n.', 'Once the notching operation is complete, the nozzle valve(s) \n225\n can be actuated into its closed configuration such that passageway \n223\n and nozzle structure(s) is (are) fluidly isolated from the central channel \n209\n and thus blocking the flow of stimulating fluid \n211\n from the central channel \n209\n to the nozzle structure(s).', 'Furthermore, the at least one arm (e.g., arms \n219\nA, \n219\nB) can optionally be retracted radial inward away from the wellbore surface \n106\n toward the tool housing \n105\n to permit axial movement of the BHA \n201\n.', 'During the wormhole formation operations that follow the notching operation, the nozzle valve(s) \n225\n can be operated in its closed configuration such that passageway \n223\n and the nozzle structure(s) are fluidly isolated from the central channel \n209\n and thus blocking the flow of stimulating fluid \n211\n from the central channel \n209\n to the nozzle structure(s).', 'Furthermore, the sliding valve \n215\n is configured to open one or more ports \n217\n leading from central channel \n209\n of the tool housing \n205\n to the treatment zone to provide for flow of the stimulating fluid \n211\n from the central channel \n209\n through the port(s) \n217\n and into the treatment zone.', 'As the stimulating fluid contacts the rock formation at the treatment zone, the formation rock at the treatment zone can react to the stimulating fluid and undergo dissolution reactions that produce highly permeable channels or “wormholes” that extend radially (i.e., in a direction with a radial component) through the rock formation and enable fluid transport through the rock formation, which can restore or enhance the permeability of the rock formation.', 'The one or more shallow notches \n227\n in the wellbore surface \n106\n that are created by the notching operation can facilitate wormhole formation at a corresponding position of the notch by jump-starting wormhole initiation (i.e., the dissolution of the formation rock) and reducing the induction time period.', 'Specifically, such notch(es) \n227\n establish a least resistant path to the stimulating fluid that contacts the wellbore surface \n106\n during the wormhole formation operations.', 'Such notch(es) \n227\n can act as seed(s) for wormholes formed by the matrix acidizing operation, and thus result in controlled placement of the wormholes and ultimately a reduction of the volume of the stimulating fluid required for the matrix acidizing operation.', 'In one embodiment, the BHA \n201\n can be configured with four nozzle structures that are spaced apart from one another about the circumferential surface of the tool housing \n205\n.', 'The four nozzle structures can be supported by eight movable arms where each one of the four-nozzle structure is mounted on a pair of moveable arms with one arm of the pair proving a respective fluid passageway from a corresponding nozzle valve to the respective nozzle structure.', 'At a resting position, all the four nozzle valves are closed, and all eight arms are positioned near the tool housing \n205\n and flat.', 'The arms are actuated to move away from the tool housing \n205\n toward the wellbore surface \n106\n, which carry the four nozzle structures away from the tool housing \n205\n and cause the four nozzle structures to contact the wellbore surface \n106\n with an initial stand-off distance ensured by the pad(s) \n223\n of the respective nozzle structures.', 'At this point, the four nozzle valves are opened which enable the stimulation fluid to flow through the fluid passageways provided by the four movable arms to reach the respective nozzle structures.', 'The stimulation fluid increases its velocity as the flow path size get smaller ensuring enough velocity to create the desired notch in the wellbore surface \n106\n.', 'After the notching operation is complete, the four nozzle valves can be closed, and the arms retracted or moved radially inward toward the tool housing.', 'Furthermore, the sliding sleeve can be actuated to open the one or more ports \n217\n between the central channel \n209\n and the treatment zone to perform follow-on wormhole formation operations.', 'Once the wormhole formation operations are complete, the sliding sleeve can be actuated to close the one or more ports \n217\n between the central channel \n209\n and the treatment zone, the packer(s) \n203\nA and the packer (s0 \n203\nB can be deactivated, and the tool can be moved axially in the wellbore \n105\n for use in the next target zone or possibly removed from the wellbore \n105\n.', 'In other embodiments, the BHA \n201\n can be configured to perform the notching operation simultaneously with the wormhole formation operations.', 'In this embodiment, the sliding valve \n215\n can be configured to open the one or more ports \n217\n leading from central channel \n209\n of the tool housing \n205\n to the treatment zone to provide for flow of the stimulating fluid \n211\n from the central channel \n209\n through the port(s) \n217\n and into the treatment zone.', 'Concurrent with the sliding valve \n215\n, positioned such that it opens the port(s) \n217\n to provide for the flow of the stimulating fluid \n211\n from the central channel \n209\n and through the port(s) \n217\n, the at least one arm (e.g., arms \n219\nA, \n219\nB) can be positioned such that the at least one nozzle structure (e.g., two nozzle structures \n221\nA, \n221\nB or possibly additional nozzle structures) contacts the wellbore surface \n106\n in the treatment zone and the nozzle valve(s) \n225\n can be actuated into open configuration such that stimulating fluid \n211\n flows from the central channel \n209\n to the nozzle structure(s).', 'The respective nozzle structure is configured to direct a high-pressure flow of the stimulating fluid \n211\n to a localized area of the wellbore surface \n106\n adjacent the nozzle structure, which creates a shallow notch \n227\n that extends radially into the wellbore surface \n106\n as best shown in \nFIG.', '2\nB\n.', 'Concurrent with the notching operation, the stimulating fluid that flows from the central channel \n209\n through the port(s) \n217\n and into the treatment zone contacts the rock formation at the treatment zone.', 'The formation rock at the treatment zone can react to the stimulating fluid and undergo dissolution reactions that produce highly permeable channels or “wormholes” that extend radially (i.e., in a direction with a radial component) through the rock formation and enable fluid transport through the rock formation, which can restore or enhance the permeability of the rock formation.', 'In this embodiment, the notch(es) \n227\n created by the notching operation can facilitate wormhole formation at a corresponding position of the notch by jump-starting wormhole initiation (i.e., the dissolution of the formation rock), aid in jump-starting wormhole initiation and reducing the induction time period.', 'Specifically, such notch(es) \n227\n can establish a least resistant path to the stimulating fluid that contacts the wellbore surface \n106\n during the wormhole formation operations.', 'Such notch(es) \n227\n can act as seed(s) for wormholes formed by the matrix acidizing operation, and thus result in controlled placement of the wormholes and ultimately a reduction of the volume of the stimulating fluid required for the matrix acidizing operation.', 'Once the notching operation is complete, the nozzle valve \n225\n can be actuated into its closed configuration such that passageway \n223\n and nozzle structure(s) is (are) fluidly isolated from the central channel \n209\n and thus blocking the flow of stimulating fluid \n211\n from the central channel \n209\n to the nozzle structure(s).', 'Furthermore, the at least one arm (e.g., arms \n219\nA, \n219\nB) can optionally be configured such that it is actuated by the actuation system \n213\n to retract radial inward away from the wellbore surface \n106\n toward the tool housing \n105\n to permit axial movement of the BHA \n201\n.', 'In another embodiment, the respective nozzle structure(s) of the tool can be adapted such that the stand-off distance between the nozzle exit and the wellbore surface can be adjusted according to operation needs by hydraulic operation.', 'In non-limiting examples, the opening of the nozzle is about 1/32- 1/16 inch.', 'In non-limiting examples, the depth of the notches (depends on the stand-off distance) is expected to be greater than about 1 inch.', 'In this case, the moveable arm(s) (e.g., moveable arms \n219\nB) of the tool can be configured to provide a corresponding internal channel \n251\n to carry hydraulic fluid to the respective nozzle structures as shown in \nFIGS.', '3\nA and \n3\nB\n.', 'The pressure of the hydraulic fluid can be controlled by a piston \n253\n integral to the moveable arm(s) (e.g., moveable arms \n219\nB).', 'Furthermore, the respective nozzle structures can be configured to have a moveable cup \n255\n that houses a nozzle body \n257\n.', 'The cup \n255\n is moveable in the radial direction relative to the nozzle body \n257\n and defines a variable volume interior chamber between the cup \n255\n and the nozzle body \n257\n.', 'The variable volume interior chamber is in fluid communication with the internal passageway \n251\n, such hydraulic fluid pressure controlled by the piston \n253\n controls the volume of the interior chamber and moves the cup \n255\n radially relative to the nozzle body \n257\n.', 'The radial movement of the cup \n255\n is supported by a stopper \n259\n, seal \n261\n and O-ring \n263\n using the pressure of the hydraulic fluid.', 'The cup \n255\n and nozzle body \n257\n further define a fluid channel \n229\n with an inlet end in fluid communication with the passageway \n223\n.', 'The fluid channel \n229\n extends through the nozzle body (for example, with a ninety-degree turn) to a nozzle exit \n231\n.', 'The fluid channel \n229\n provides a flow path of decreasing cross-sectional size over its length such that the pressure and velocity of the stimulating fluid increases over the flow path and exits from the nozzle exit \n231\n at sufficient pressure and velocity to create the desired notch in the wellbore surface \n106\n.', 'One or more pads \n233\n are disposed about the nozzle exit \n231\n and configured to extend radially from the moveable cup \n225\n and contact the wellbore surface \n106\n as shown.', 'The moveable cup \n255\n and pad(s) \n233\n provide an adjustable stand-off distance between the nozzle exit \n231\n and the wellbore surface \n106\n during the notching operation as best shown in \nFIG.', '3\nB\n.', 'In this embodiment, after deploying the nozzle structure(s) near the wellbore surface \n106\n, the stand-off distance can be adjusted by the hydraulic operations, if need be.', 'The nozzle valve(s) can be opened to enable the stimulation fluid to flow to the nozzle structure(s).', 'The respective nozzle structure(s) increase the fluid velocity of the stimulation fluid as the flow path sizes get smaller ensuring enough velocity to form a notch.', 'After the notching operation is complete, the nozzle valve(s) can be closed, and the arm(s) of the tool can be retracted in the radial direction.', 'Furthermore, the sliding sleeve can be actuated to open the one or more ports \n217\n between the central channel \n209\n and the treatment zone to perform follow-on wormhole formation operations.', 'Once the wormhole formation operations are complete, the sliding sleeve can be actuated to close the one or more ports \n217\n between the central channel \n209\n and the treatment zone, the packer(s) \n203\nA and the packer(s) \n203\nB can be deactivated, and the tool can be moved axially in the wellbore \n105\n for use in the next target zone or possibly removed from the wellbore \n105\n.', 'In another embodiment, the respective nozzle structure(s) of the tool can be adapted such that the stand-off distance between the nozzle exit and the wellbore surface can be adjusted according to operation needs by electromechanical operation.', 'In this case, the respective nozzle structure(s) can be configured to have a moveable nozzle cup \n355\n housed by a nozzle body \n357\n as shown in \nFIGS.', '4\nA and \n4\nB\n.', 'The nozzle cup \n355\n is moveable in the radial direction relative to the nozzle body \n357\n by operation of an electric motor \n359\n, drive wire \n361\n, threaded part \n363\n, and pusher \n365\n.', 'The electrical motor \n259\n and drive wire \n361\n drive rotation of the pusher \n363\n, which is threaded to the threaded part \n363\n to impart radial movement of the nozzle cup \n355\n relative to the nozzle body \n357\n.', 'The movement of the pusher \n365\n is restricted by the stopper \n367\n, which houses the pusher \n365\n.', 'The nozzle cup \n355\n interfaces to O-rings \n369\n with seals \n371\n to facilitate its movement.', 'The nozzle cup \n355\n and nozzle body \n357\n define a fluid channel \n229\n with an inlet end in fluid communication with the passageway \n223\n.', 'The fluid channel \n229\n extends through the nozzle cup \n355\n (for example, with a ninety-degree turn) to a nozzle exit \n231\n.', 'The fluid channel \n229\n provides a flow path of decreasing cross-sectional size over its length such that the pressure and velocity of the stimulating fluid increases over the flow path and exits from the nozzle exit \n231\n at sufficient pressure and velocity to create the desired notch in the wellbore surface \n106\n.', 'One or more pads \n233\n are disposed about the nozzle exit \n231\n and extend radially from the nozzle body \n357\n to contact the wellbore surface \n106\n as shown.', 'The moveable cup \n355\n provides an adjustable stand-off distance between the nozzle exit \n231\n and the wellbore surface \n106\n during the notching operation as best shown in \nFIG.', '4\nB\n.', 'In this embodiment, after deploying the nozzle structure(s) near the wellbore surface \n106\n, the stand-off distance can be adjusted by the electromechanical operations, if need be.', 'The nozzle valve(s) can be opened which enable the stimulation fluid to flow to the nozzle structure(s).', 'The respective nozzle structure(s) increase the fluid velocity of the stimulation fluid as the flow path sizes get smaller ensuring enough velocity to form a notch.', 'After the notching operation is complete, the nozzle valve(s) can be closed, and the arm(s) can be retracted in the radial direction.', 'Furthermore, the sliding sleeve can be actuated to open the one or more ports \n217\n between the central channel \n209\n and the treatment zone to perform follow-on wormhole formation operations.', 'Once the wormhole formation operations are complete, the sliding sleeve can be actuated to close the one or more ports \n217\n between the central channel \n209\n and the treatment zone, the packer(s) \n203\nA and the packer(s) \n203\nB can be deactivated, and the tool can be moved axially in the wellbore \n105\n for use in the next target zone or possibly removed from the wellbore \n105\n.', 'FIG.', '5\n illustrates an example device \n2500\n, with a processor \n2502\n and memory \n2504\n that can be configured to implement various embodiments of the methods and processes as discussed in the present application.', 'Memory \n2504\n can also host one or more databases and can include one or more forms of volatile data storage media such as random-access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).', 'Device \n2500\n is one example of a computing device or programmable device and is not intended to suggest any limitation as to scope of use or functionality of device \n2500\n and/or its possible architectures.', 'For example, device \n2500\n can comprise one or more computing devices, programmable logic controllers (PLCs), etc.', 'Further, device \n2500\n should not be interpreted as having any dependency relating to one or a combination of components illustrated in device \n2500\n.', 'For example, device \n2500\n may include one or more of computers, such as a laptop computer, a desktop computer, a mainframe computer, etc., or any combination or accumulation thereof.', 'Device \n2500\n can also include a bus \n2508\n configured to allow various components and devices, such as processors \n2502\n, memory \n2504\n, and local data storage \n2510\n, among other components, to communicate with each other.', 'Bus \n2508\n can include one or more of any of several types of bus structures, including a memory bus or memory controller, a peripheral bus, an accelerated graphics port, and a processor or local bus using any of a variety of bus architectures.', 'Bus \n2508\n can also include wired and/or wireless buses.', 'Local data storage \n2510\n can include fixed media (e.g., RAM, ROM, a fixed hard drive, etc.) as well as removable media (e.g., a flash memory drive, a removable hard drive, optical disks, magnetic disks, and so forth).', 'One or more input/output (I/O) device(s) \n2512\n may also communicate via a user interface (UI) controller \n2514\n, which may connect with I/O device(s) \n2512\n either directly or through bus \n2508\n.', 'In one possible implementation, a network interface \n2516\n may communicate outside of device \n2500\n via a connected network.', 'A media drive/interface \n2518\n can accept removable tangible media \n2520\n, such as flash drives, optical disks, removable hard drives, software products, etc.', 'In one possible implementation, logic, computing instructions, and/or software programs comprising elements of module \n2506\n may reside on removable media \n2520\n readable by media drive/interface \n2518\n.', 'In one possible embodiment, input/output device(s) \n2512\n can allow a user (such as a human annotator) to enter commands and information to device \n2500\n, and also allow information to be presented to the user and/or other components or devices.', 'Examples of input device(s) \n2512\n include, for example, sensors, a keyboard, a cursor control device (e.g., a mouse), a microphone, a scanner, and any other input devices known in the art.', 'Examples of output devices include a display device (e.g., a monitor or projector), speakers, a printer, a network card, and so on.', 'Various systems and processes of present disclosure may be described herein in the general context of software or program modules, or the techniques and modules may be implemented in pure computing hardware.', 'Software generally includes routines, programs, objects, components, data structures, and so forth that perform particular tasks or implement particular abstract data types.', 'An implementation of these modules and techniques may be stored on or transmitted across some form of tangible computer-readable media.', 'Computer-readable media can be any available data storage medium or media that is tangible and can be accessed by a computing device.', 'Computer readable media may thus comprise computer storage media.', '“Computer storage media” designates tangible media, and includes volatile and non-volatile, removable, and non-removable tangible media implemented for storage of information such as computer readable instructions, data structures, program modules, or other data.', 'Computer storage media include, but are not limited to, RAM, ROM, EEPROM, flash memory or other memory technology, CD-ROM, digital versatile disks (DVD) or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other tangible medium which can be used to store the desired information, and which can be accessed by a computer.', 'Some of the methods and processes described above, can be performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any particular device type or system.', 'The processor may include a computer system.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, general-purpose computer, special-purpose machine, virtual machine, software container, or appliance) for executing any of the methods and processes described above.', 'The computer system may further include a memory such as a semiconductor memory device (e.g., a RAM, ROM, PROM, EEPROM, or Flash-Programmable RAM), a magnetic memory device (e.g., a diskette or fixed disk), an optical memory device (e.g., a CD-ROM), a PC card (e.g., PCMCIA card), or other memory device.', 'Alternatively or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.', 'Some of the methods and processes described above, can be implemented as computer program logic for use with the computer processor.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.']

['1.', 'A method for stimulating recovery of hydrocarbons from a subterranean rock formation traversed by a wellbore, comprising:\ndeploying a downhole tool at a treatment zone of the wellbore;\noperating said downhole tool to create at least one notch in a wellbore surface at the treatment zone; and\noperating said downhole tool to supply a stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure, wherein the notch facilitates wormhole formation at a corresponding position of the notch arising from dissolution of rock caused by reaction of the rock with the stimulating fluid, wherein\nthe downhole tool is operated to create the at least one notch simultaneously with supplying the stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure.', '2.', 'The method according to claim 1, wherein:\nthe notch facilitates wormhole formation by jump-starting wormhole initiation.', '3.', 'The method according to claim 1, wherein:\nthe notch reduces an induction time period.', '4.', 'The method according to claim 1, wherein:\nthe notch provides for controlled placement of a corresponding wormhole.', '5.', 'The method according to claim 1, wherein:\nthe notch provides for reducing volume of the stimulation fluid injected into the wellbore as compared to a volume of the stimulation fluid injected into the wellbore where no notches are present.', '6.', 'The method according to claim 1, wherein:\nthe notch is created by a nozzle structure that is configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface.', '7.', 'The method according to claim 1, wherein:\nthe downhole tool is operated to create the at least one notch prior to supplying the stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure.', '8.', 'The method according to claim 1, wherein:\nthe downhole tool is operated to create the at least one notch and supply the stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure after isolating the treatment zone of the wellbore.', '9.', 'The method according to claim 1, wherein:\nthe operation of the downhole tool creates a plurality of notches in the wellbore surface of the treatment zone, wherein the plurality of notches facilitates wormhole formation at corresponding positions of the plurality of notches.', '10.', 'The method according to claim 9, wherein:\nthe plurality of notches are created by a plurality of nozzle structures each configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface.', '11.', 'The method according to claim 1, wherein:\nthe stimulating fluid comprises an acid component.', '12.', 'A downhole tool that is deployable in a wellbore that traverses a subterranean rock formation traversed by a wellbore,\nthe downhole tool for stimulating recovery of hydrocarbons from the subterranean rock formation,\nthe downhole tool configured to create at least one notch in a wellbore surface at a treatment zone simultaneously with supplying a stimulating fluid to the treatment zone at a pressure less than formation breakdown pressure in a single run,\nwherein the notch facilitates wormhole formation at a corresponding position of the notch arising from dissolution of rock caused by reaction of the rock with the stimulating fluid.', '13.', 'The downhole tool according to claim 12, further comprising:\npackers spaced apart from one another and configured to isolates the treatment zone.', '14.', 'The downhole tool according to claim 12, further comprising:\nat least one nozzle structure supported by at least one moveable arm, wherein the nozzle structure is configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface to create the notch.\n\n\n\n\n\n\n15.', 'The downhole tool according to claim 14, wherein:\nthe at least one moveable arm is configured for radial movement to permit the at least one nozzle structure to contact the wellbore surface.', '16.', 'The downhole tool according to claim 14, wherein:\nthe at least one moveable arm comprises at least one internal fluid passageway configured to carry stimulating fluid to the at least one nozzle structure.', '17.', 'The downhole tool according to claim 16, wherein:\nthe at least one moveable arm comprises at least one nozzle valve in fluid communication with the at least one internal fluid passageway, wherein the at least one nozzle valve is configured to selectively supply stimulating fluid to the at least one nozzle structure via the at least one internal fluid passageway.', '18.', 'The downhole tool according to claim 14, wherein:\nthe nozzle structure comprises at least one pad disposed about a nozzle exit, wherein the at least one pad is configured to contact the wellbore surface and provide a stand-off distance between the wellbore surface and the nozzle exit.', '19.', 'The downhole tool according to claim 18, wherein:\nthe nozzle structure is configured such that the stand-off distance is fixed.', '20.', 'The downhole tool according to claim 18, wherein:\nthe nozzle structure is configured such that the stand-off distance is adjustable by hydraulic operation or electromechanical operation.', '21.', 'The downhole tool according to claim 18, wherein:\nthe nozzle structure is configured to provide a flow path of stimulating fluid leading to the nozzle exit, wherein the flow path has decreasing cross-sectional size over its length such that pressure and velocity of stimulating fluid increases over the flow path and exits from the nozzle exit at sufficient pressure and velocity to create a notch in the wellbore surface.', '22.', 'The downhole tool according to claim 12, further comprising:\na plurality of nozzle structures supported by at least one moveable arm, wherein each nozzle structure is configured to direct a high-pressure flow of stimulating fluid to a localized area of the wellbore surface to create a plurality of notches in the wellbore surface.\n\n\n\n\n\n\n23.', 'The downhole tool according to claim 22, wherein:\nthe plurality of nozzle structures are supported by a plurality of moveable arms.', '24.', 'The downhole tool according to claim 12, wherein the downhole tool comprises a sliding sleeve configured to selectively inject the stimulating fluid from the downhole tool into the treatment zone.']

['FIG.', '1 is a schematic diagram of a wellsite with equipment provided for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation;; FIGS.', '2A and 2B are schematic diagrams of an illustrative downhole tool for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation;;', 'FIGS.', '3A and 3B are schematic diagrams of another illustrative downhole tool for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation;; FIGS.', '4A and 4B are schematic diagrams of yet another illustrative downhole tool for creating notches in a wellbore surface and for matrix acidizing a subterranean rock formation; and; FIG.', '5 illustrates a schematic view of a computing system according to an embodiment of the present disclosure.', '; FIG. 1 is a schematic diagram that illustrates an example onshore hydrocarbon', 'well location with surface equipment 101 above a hydrocarbon-bearing subterranean rock formation 103 after a drilling operation has been carried out.', 'At this stage, the wellbore 105 is filled with a fluid mixture 107 which is typically a mixture of drilling fluid and drilling mud.', 'In subsequent stages, the well is typically completed by running one or more casing strings in the wellbore 105 before cementing operations that cement the casting string(s) to the wellbore surface 106.', 'In this example, the surface equipment 101 comprises a surface unit 109 and rig (or injector) 111 for deploying a downhole tool 113 in the wellbore 105.', 'The surface unit 109 may be a vehicle coupled to the downhole tool 113 by coiled tubing or other tubing 115.', 'Furthermore, the surface unit 109 can include an appropriate device for determining the depth position of the downhole tool 113 relative to the surface level.; FIG.', '5 illustrates an example device 2500, with a processor 2502 and memory 2504 that can be configured to implement various embodiments of the methods and processes as discussed in the present application.', 'Memory 2504 can also host one or more databases and can include one or more forms of volatile data storage media such as random-access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).']

US11835673

Methods and systems for determining fast and slow shear directions in an anisotropic formation using a logging while drilling tool

Sep 13, 2021

Pu Wang, Sandip Bose, Bikash Kumar Sinha, Ting Lei

SCHLUMBERGER TECHNOLOGY CORPORATION

Substantive Exam Report issued in Saudi Arabian Patent Application No. 518400238 dated Feb. 28, 2022, 8 pages with English translation.; Alford, J. et al., “Sonic Logging While Drilling-Shear Answers,” Oilfield Review, 2012, 24(1), pp. 4-15.; Alford, R. M., “Shear Data in the Presence of Azimuthal Anisotropy: Dilley, Texas”, SEG Technical Expanded Abstracts, 1986, pp. 476-479.; Arroyo Franco, J. L. et al., “Sonic Investigations in and Around the Borehole,” Oilfield Review, 2006, 18(1), pp. 14-31.; Bose, S. et al., Anisotropy Processing Without Matched Cross-dipole Transmitters, presented at the 75th Annual Meeting, SEG Technical Program Expanded Abstracts, 2007, pp. 114-118.; Ekstrom, M. E., “Dispersion Estimation from Borehole Acoustic Arrays Using a Modified Matrix Pencil Algorithm”, presented at the 29th Asilomar Conference on Signals, Systems, and Computers, Pacific Grove, California, 1995, 1, pp. 449-453.; Esmersoy, C. et al., “Dipole shear anisotropy logging”, presented at the 64th Annual Meeting, SEG Technical Program Expanded Abstracts, 1994, pp. 1139-1142.; Haldorsen, J. B. U. et al., “Borehole Acoustic Waves,” Oilfield Review, 2006, 18(1), pp. 34-43.; Sinha, B. K. et al., “Borehole Dipole and Quadrupole Modes in Anisotropic Formations”, 2003 IEEE Ultrasonics Symposium Proceedings, pp. 284-289.; Sinha, B. K. et al., “Elastic wave propagation in deviated wells in anisotropic formations”, Geophysics, 2006, 71(6), pp. D191-D202.; Sinha, B. K. et al., “Influence of a pipe tool on borehole modes”, Geophysics, 2009, 74(3), pp. E111-E123.; Sinha, B. K. et al., “Sonic logging in deviated wellbores in the presence of a drill collar”, presented at the 2010 SEG Annual Meeting and Exposition, Expanded Abstracts, Denver, Colorado, USA, pp. 553-557.; Tang, X. M. et al., “A curve-fitting method for analyzing dispersion characteristics of guided elastic waves”, presented at the 79th SEG Annual Meeting, Houston, SEG Technical Program Expanded Abstracts, 2009, pp. 461-465.; Wang, P. et al., “Broadband Dispersion Extraction of Borehole Acoustic Modes via Sparse Bayesian Learning”, presented at the 5th IEEE International Workshop on Computational Advances in Multi-Sensor Adaptive Processing, Saint Martine, 2013, pp. 268-271.; Wang, P. et al., Dipole Shear Anisotropy Using Logging-While-Drilling Sonic Tools, presented at the SPWLA 57th Annual Symposium, Reykjavik, Iceland, 2016, 14 pages.; Search Report and Written Opinion of related International Patent Application No. PCT/US2017/027282 dated Jul. 25, 2017, 16 pages.

6718266; April 6, 2004; Sinha et al.; 7120541; October 10, 2006; Wang; 8339897; December 25, 2012; Aeron et al.; 20040158997; August 19, 2004; Tang; 20100034052; February 11, 2010; Pabon; 20110019501; January 27, 2011; Market; 20120026831; February 2, 2012; Mickael; 20150012251; January 8, 2015; Horne et al.; 20170115413; April 27, 2017; Wang et al.; 20170115414; April 27, 2017; Wang et al.; 20190129053; May 2, 2019; Wang et al.

2015021004; February 2015; WO

['Methods are provided for determining properties of an anisotropic formation (including both fast and slow formations) surrounding a borehole.', 'A logging-while-drilling tool is provided that is moveable through the borehole.', 'The logging-while drilling tool has at least one dipole acoustic source spaced from an array of receivers.', 'During movement of the logging-while-drilling tool, the at least one dipole acoustic source is operated to excite a time-varying pressure field in the anisotropic formation surrounding the borehole.', 'The array of receivers is used to measure waveforms arising from the time-varying pressure field in the anisotropic formation surrounding the borehole.', 'The waveforms are processed to determine a parameter value that represents shear directionality of the anisotropic formation surrounding the borehole.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION(S)', 'This application is a continuation of U.S. application Ser.', 'No. 16/093,640, filed on Oct. 14, 2018, which is the U. S. National Phase of International Patent Application No.', 'PCT/US2017/027282, filed Apr. 13, 2017, which claimed priority to U.S. Provisional Application No. 62/322,870, filed on Apr. 15, 2016, all of which are incorporated herein reference in its entirety.', 'TECHNICAL FIELD', 'The subject disclosure relates to the investigation of earth formations.', 'More particularly, the subject disclosure relates to methods of measuring formation characteristics using logging-while-drilling (LWD) acoustic measurement tools.\n \nBACKGROUND\n \nWireline borehole acoustic logging is a major part of subsurface formation evaluation that is important in oil and gas exploration and production.', 'The logging is achieved by lowering a wireline acoustic measurement tool comprising at least one transmitter and an array of receivers into a fluid-filled well, exciting the transmitter(s), recording resulting acoustic waveforms at the receivers, and processing the recorded waveforms to obtain a depth log of slowness measurements (where slowness is the reciprocal of velocity) along the well.', 'The acoustic propagation in the borehole is affected by the properties of rocks surrounding the wellbore.', 'More specifically, the fluid-filled borehole supports propagation of certain number of borehole guided modes that are generated by a transducer placed inside the borehole fluid.', 'These borehole acoustic modes are characterized by their acoustic slowness dispersions which contain valuable information about the rock mechanical properties.', 'Therefore, the acoustic logging can provide answers pertaining to such properties with diverse applications such as geophysical calibration of seismic imaging, geomechanical assessment of wellbore stability, and stress characterization for fracture stimulation.', 'Examples of such acoustic logging are described in i)', 'J. L. A. France, M. A. M. Ortiz, G. S. De, L. Renlie and S. Williams, “Sonic investigations in and around the borehole,” \nOilfield Review\n, vol.', '18, no. 1, pp. 14-31, March 2006; ii) J. B. U. Haldorsen, D. L. Johnson, T. Plona, B. Sinha, H.-P. Valero and K. Winker, “Borehole acoustic waves,” \nOilfield Review\n, vol.', '18, no. 1, pp.', '34-43, March 2006; and iii) J. Alford, M. Blyth, E. Tollefsen, J. Crowe, J. Loreto, S. Mohammed, V. Pistre, and A. Rodriguez-Herrera, “Sonic logging while drilling—shear answers,” \nOilfield Review\n, vol.', '24, no. 1, pp.', '4-15, January 2012.', 'Logging-while-drilling (LWD) acoustic tools such as SonicScope 475 and SonicScope 825 of Schlumberger Technology Corporation have been demonstrated to save a great amount of rig time and to help improve the drilling efficiency and safety.', 'Processing of the sonic data from the LWD acoustic tools provides monopole compressional and shear slownesses in fast formations and quadrupole shear slowness mostly in slow formations.', 'However, both monopole and quadrupole shear slownesses cannot provide a complete anisotropy characterization.', 'To have a complete anisotropy characterization, one of the most important inputs is the fast-shear azimuthal direction and/or slow shear azimuthal direction, which are desirable for subsequent stress and mechanical analyses of the rock properties around the borehole.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Methods are provided for determining properties of an anisotropic formation (including both fast and slow formations) surrounding a borehole.', 'A logging-while-drilling tool is provided that is moveable through the borehole.', 'The logging-while drilling tool has at least one dipole acoustic source spaced from an array of receivers.', 'During movement of the logging-while-drilling tool, the at least one dipole acoustic source is operated to excite a time-varying pressure field in the anisotropic formation surrounding the borehole.', 'The array of receivers are used to measure waveforms arising from the time-varying pressure field in the anisotropic formation surrounding the borehole.', 'The waveforms are processed to determine shear directionality of the anisotropic formation surrounding the borehole.', 'Additional aspects, embodiments, objects and advantages of the disclosed methods may be understood with reference to the following detailed description taken in conjunction with the provided drawings.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nFIG.', '1\n is a schematic diagram of a transversely isotropic formation with a vertical axis of symmetry (TIV).\n \nFIG.', '2\n is a schematic diagram of a transversely isotropic formation with a horizontal axis of symmetry (TIH).\n \nFIG.', '3\n is a schematic diagram illustrating a drill-collar mode (dashed curve labeled “blue”) that propagates in a Logging-While-Drilling (LWD) acoustic measurement tool and that interferes with a formation mode (dashed curve labeled “green”).', 'FIGS.', '4\nA and \n4\nB\n are schematic diagrams illustrating cross-dipole orthogonal firing of a wireline acoustic measurement tool.', 'FIGS.', '5\nA and \n5\nB\n are schematic diagrams illustrating non-orthogonal dipole firings of an LWD acoustic measurement tool.\n \nFIG.', '6\n is a schematic diagram of a wellsite system that can be used in practicing the embodiments of the subject disclosure.\n \nFIG.', '7\n is a schematic diagram of a LWD acoustic measurement tool that can be used in practicing the embodiments of the subject disclosure.\n \nFIG.', '8\n is a flowchart illustrating a time-domain workflow according to an embodiment of the subject disclosure.', 'FIGS.', '9\nA and \n9\nB\n illustrate synthetic time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, of a dipole transmitter in the horizontal section of a fast TIV formation.\n \nFIG.', '9\nC\n illustrates the slowness dispersions of the synthetic time-domain waveforms of \nFIGS.', '9\nA and \n9\nB\n in the horizontal section of a fast TIV formation.', 'FIG.', '10\n illustrates a two-dimensional cost function of the four-component non-orthogonal LWD waveform rotation for the example of \nFIGS.', '9\nA, \n9\nB and \n9\nC\n.', 'FIGS.', '11\nA and \n11\nB\n illustrate rotated time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, for the example of \nFIGS.', '9\nA, \n9\nB and \n9\nC\n.', 'FIG.', '11\nC\n illustrates the slowness dispersions of the rotated time-domain waveforms of \nFIGS.', '11\nA and \n11\nB\n in the horizontal section of the fast TIV formation.', 'FIGS.', '12\nA and \n12\nB\n illustrate synthetic time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, from a dipole source in the horizontal section of a fast TIV formation.', 'The D1 and D2 firings are, respectively, 35 and 67 degrees away from the slow shear azimuth.\n \nFIG.', '12\nC\n illustrates the slowness dispersions of the time-domain waveforms of \nFIGS.', '12\nA and \n12\nB\n in the horizontal section of the fast TIV formation.', 'FIG.', '13\n illustrates a two-dimensional cost function of the four-component non-orthogonal LWD waveform rotation for the example of \nFIGS. \n12\nA, \n12\nB and \n12\nC\n.\n \nFIGS.', '14\nA and \n14\nB\n illustrate rotated time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, for the example of \nFIGS.', '12\nA, \n12\nB and \n12\nC\n.', 'FIG.', '14\nC\n illustrates the slowness dispersions of the rotated time-domain waveforms of \nFIGS.', '14\nA and \n14\nB\n in the horizontal section of the fast TIV formation.', 'FIGS.', '15\nA and \n15\nB\n illustrate rotated time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, from a dipole source in the horizontal section of a slow TIV formation.', 'FIG.', '15\nC\n illustrates the slowness dispersions of the rotated time-domain waveforms of \nFIGS.', '15\nA and \n15\nB\n in the horizontal section of the slow TIV formation.', 'FIG.', '16\n is a flowchart illustrating a frequency-domain workflow according to an embodiment of the subject disclosure.\n \nFIG.', '17\n is a schematic diagram illustrating shear wave splitting arising from a dipole transmitter in anisotropic formations and principal polarization directions.\n \nFIG.', '18\nA\n illustrates an exemplary model slowness dispersion of the fast and slow coupled collar-formation flexural modes arising from a dipole firing which is 45° away from the fast shear direction in a slow formation.', 'The solid dots between 3.5 and 6 kHz represents a bandlimited dispersion used in the frequency-domain workflow.\n \nFIG.', '18\nB\n shows an exemplary one-dimensional LWD-DATC cost function, which is constructed using raw inline and crossline waveforms between 3.5 and 6 kHz.\n \nFIG.', '19\nA\n shows two exemplary slowness dispersions of the fast and slow coupled collar-formation flexural modes arising from a dipole firing which is 45° away from the fast shear direction in a slow formation (same as \nFIG.', '18\nA\n), where the slowness dispersions are extracted from pre-rotated inline and crossline waveforms with a pre-determined angle of 60°.\n \nFIG.', '19\nB\n shows an exemplary one-dimensional LWD-DATC cost function constructed from selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes of \nFIG.', '19\nA\n.\n \nFIG.', '20\nA\n shows two exemplary slowness dispersions of the fast and slow coupled collar-formation flexural modes arising from a dipole firing that is 67° away from the fast shear direction (different from \nFIGS.', '18\nA and \n19\nA\n) in a slow formation, where the slowness dispersions are extracted from pre-rotated inline and crossline waveforms with a pre-determined angle of 60°.\n \nFIG.', '20\nB\n shows an exemplary one-dimensional LWD-DATC cost function constructed from selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes of \nFIG.', '20\nA\n.\n \nFIG.', '20\nC\n shows rotated inline and crossline waveforms for the example of \nFIG.', '20\nA\n when the inline receivers are parallel to the fast shear direction of the slow formation.', 'FIG.', '21\nA\n shows two exemplary slowness dispersions of the fast and slow coupled collar-formation flexural modes arising from a dipole firing that is 85° away from the fast shear direction in a fast formation, where the slowness dispersions are extracted from raw (non-rotated) inline and crossline waveforms\n \nFIG.', '21\nB\n shows an exemplary one-dimensional LWD-DATC cost function constructed from selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes of \nFIG.', '21\nA\n.\n \nFIG.', '21\nC\n shows rotated inline and crossline waveforms for the example of \nFIG.', '21\nA\n when the inline receivers are parallel to the fast shear direction of the fast formation.', 'FIG.', '22\n shows an example computing system that can be used to implement the time-domain and frequency domain workflows as described herein.', 'DETAILED DESCRIPTION', 'The particulars shown herein are by way of example and for purposes of illustrative discussion of the examples of the subject disclosure only and are presented in the cause of providing what is believed to be the most useful and readily understood description of the principles and conceptual aspects of the subject disclosure.', 'In this regard, no attempt is made to show details in more detail than is necessary, the description taken with the drawings making apparent to those skilled in the art how the several forms of the subject disclosure may be embodied in practice.', 'Furthermore, like reference numbers and designations in the various drawings indicate like elements.', 'As used throughout the specification and claims, the term “downhole” refers to a subterranean environment, particularly in a well or wellbore.', '“Downhole tool” is used broadly to mean any tool used in a subterranean environment including, but not limited to, a logging tool, an imaging tool, an acoustic tool, a permanent monitoring tool, and a combination tool.', 'The various techniques disclosed herein may be utilized to facilitate and improve data acquisition and analysis in downhole tools and systems.', 'In this disclosure, downhole tools and systems are provided that utilize arrays of sensing devices that are configured or designed for easy attachment and detachment in downhole sensor tools or modules that are deployed for purposes of sensing data relating to environmental and tool parameters downhole, within a borehole.', 'The tools and sensing systems disclosed herein may effectively sense and store characteristics relating to components of downhole tools as well as formation parameters at elevated temperatures and pressures.', 'Chemicals and chemical properties of interest in oilfield exploration and development may also be measured and stored by the sensing systems contemplated by the present disclosure.', 'The sensing systems herein may be incorporated in tool systems such as wireline logging tools, measurement-while-drilling and logging-while-drilling tools, permanent monitoring systems, drill bits, drill collars, sondes, among others.', 'For purposes of this disclosure, when any one of the terms wireline, cable line, slickline or coiled tubing or conveyance is used it is understood that any of the referenced deployment means, or any other suitable equivalent means, may be used with the present disclosure without departing from the spirit and scope of the present disclosure.', 'Moreover, inventive aspects lie in less than all features of a single disclosed embodiment.', 'Thus, the claims following the Detailed Description are hereby expressly incorporated into this Detailed Description, with each claim standing on its own as a separate embodiment.', 'Borehole acoustic logging is a major part of subsurface formation evaluation that is key to oil and gas exploration and production.', 'The logging may be achieved using an acoustic measurement tool, which includes one or multiple acoustic transducers, or sources, and one or multiple sensors, or receivers.', 'The acoustic measurement tool may be deployed in a fluid-field wellbore for purposes of exciting and recording acoustic waveforms.', 'The receivers thus, may acquire data representing acoustic energy that results from the acoustic energy that is emitted by the acoustic sources of the acoustic measurement tool.', 'The acoustic propagation in the borehole is affected by the properties of rocks surrounding the wellbore.', 'More specifically, the fluid-filled borehole supports propagation of certain number of borehole guided modes that are generated by energy from a source that is placed inside the borehole fluid.', 'These borehole acoustic modes are characterized by their acoustic slowness (i.e., reciprocal of velocity) dispersions, which contain valuable information about the rock mechanical properties.', 'Therefore, the acoustic logging may provide answers pertaining to such diverse applications as geophysical calibration of seismic imaging, geomechanical assessment of wellbore stability, and stress characterization for fracture stimulation.', 'In the context of this application, “acoustic energy” or “sonic energy” refers to energy in the sonic frequency spectrum, and may be, as example, energy between 200 Hertz (Hz) and 30 kiloHertz (kHz).', 'In general, the energy that is emitted by the sources of the acoustic measurement tool may travel through rock formations as either body waves or surface waves (called “flexural waves” herein).', 'The body waves include compressional waves, or P-waves, which are waves in which small particle vibrations occur in the same direction as the direction in which the wave is traveling.', 'The body waves may also include shear waves, or S-waves, which are waves in which particle motion occurs in a direction that is perpendicular to the direction of wave propagation.', 'In addition to the body waves, there are a variety of borehole guided modes whose propagation characteristics can be analyzed to estimate certain rock properties of the surrounding formation.', 'For instance, axis-symmetric Stoneley and borehole flexural waves are of particular interest in determining the formation shear slownesses.', 'As described herein, the flexural waves may also include waves that propagate along the acoustic measurement tool.', 'The acoustic measurement tool may include multiple acoustic sources that are associated with multiple source classifications, or categories.', 'For example, the acoustic measurement tool may include one or multiple monopole sources.', 'In response to energy from a monopole sonic source, the receivers of the acoustic measurement tool may acquire data representing energy attributable to various wave modes, such as data representing P-waves, S-waves and Stoneley waves.', 'The acoustic measurement tool may also include one or multiple directional sources, such as dipole or quadrupole sources, which produce additional borehole guided waves, which travel through the fluid in the borehole and along the acoustic measurement tool itself.', 'Data representing these flexural waves may be processed for such purposes as determining the presence or absence of azimuthal anisotropy.', 'For example, implementations that are described herein, the data representing the flexural waves is processed for purposes of determining a formation shear slowness.', 'The speeds at which the aforementioned waves travel are affected by various properties of the downhole environment, such as the rock mechanical properties, density and elastic dynamic constants, the amount and type of fluid present in the formation, the makeup of rock grains, the degree of inter-grain cementation and so forth.', 'Therefore, by measuring the speed of acoustic wave propagation in the borehole, it is possible to characterize the surrounding formations based on sensed parameters relating to these properties.', 'The speed, or velocity of a given sonic wave, or waveform, may be expressed in terms of the inverse of its velocity, which is referred to herein as the “slowness.”', 'In this context, an “acoustic wave” or “acoustic waveform” may refer to a particular time segment of energy recorded by one or multiple receivers and may correspond to a particular acoustic waveform mode, such as a body wave, flexural or other guided borehole waves.', 'Certain acoustic waves are non-dispersive, or do not significantly vary with respect to frequency.', 'Other acoustic waves, however, are dispersive, meaning that the wave-slownesses vary as a function of frequency.', 'The acoustic measurement tool may be deployed on a number of platforms, such as a wireline tool or a logging while drilling (LWD) platform.', 'In other words, an LWD acoustic measurement tool is disposed on a drilling string, or pipe.', 'Newly introduced logging-while-drilling (LWD) acoustic measurement tools have been demonstrated to save a great amount of rig time and to help drill more efficiently with greater safety margins.', 'Recent progress has enabled LWD acoustic measurement tools to deliver compressional and shear slowness logs in the fast and slow formations using monopole and quadrupole transmitters.', 'In this context, a “fast formation” refers to a formation in which the shear wave velocity is greater than the compressional velocity of the borehole fluid (or “drilling mud”).', 'Otherwise, the formation is a “slow” formation.', 'However, due to their azimuthal characteristics, the LWD acoustic measurement tools can be used to obtain only a single reliable shear slowness estimate which is appropriate for isotropic and TIV (transversely isotropic with a vertical axis of symmetry) formations.', 'An example TIV formation is shown in \nFIG.', '1\n.', 'In the TIV formation, elastic properties are uniform horizontally, but vary vertically.', 'Currently, there are no reliable techniques for obtaining the fast and slow shear slownesses in anisotropic formations (such as transversely isotropic with a horizontal axis of symmetry or TIH formations) or orthorhombic formations, because they require the use of directional dipole firings.', 'For example, see i) J. Alford, M. Blyth, E. Tollefsen, J. Crowe, J. Loreto, S. Mohammed, V. Pistre, and A. Rodriguez-Herrera, “Sonic logging while drilling—shear answers,” \nOilfield Review\n, vol.', '24, no. 1, pp.', '4-15, January 2012; ii) B. K. Sinha and E. Simsek, “Sonic logging in deviated wellbores in the presence of a drill collar”, 2010 \nSEG Annual Meeting and Exposition\n, Expanded Abstracts, Denver, Colo.; iii) B. K. Sinha, E. Simsek, and Q-H. Liu, “Elastic wave propagation in deviated wells in anisotropic formations”, \nGeophysics, \n71(6), D191-D202, 2006; iv) B. K. Sinha, J. Pabon and C-J. Hsu, “Borehole dipole and quadrupole modes I anisotropic formations”, 2003 IEEE Ultrasonics Symposium Proc., 284-289; and v) B. K. Sinha, E. Simsek, and S. Asvadurov, “Influence of a pipe tool on borehole modes”, \nGeophysics\n, vol.', '74(3), May-June, 2009.', 'An example TIH formation is shown in \nFIG.', '2\n.', 'In the TIH formation, elastic properties are uniform in vertical planes parallel to fractures, but vary in the perpendicular horizontal direction.', 'In an anisotropic formation, firing of the dipole transmitters generally excites both the fast and slow flexural waves, behaving like the shear-wave splitting, with different polarizations and different velocities.', 'The shear waves polarized parallel to layering in the TIV formation (e.g., a shale) or vertical fractures in the TIH formation (e.g., a formation with aligned vertical fractures) travel faster than the shear waves polarized orthogonal to the layering or fracture.', 'Therefore, the azimuth direction of the fast shear, slow shear and flexural waves can be detected by using firing from cross-dipole transmitters (e.g., cross-dipole orthogonal firings) in a wireline acoustic measurement tool.', 'Once the azimuth direction of the fast shear and slow shear is determined, the raw dipole waveforms can be rotated to yield waveforms propagating with the fast and slow shear polarizations.', 'Then the fast and slow shear slownesses can be extracted from these rotated waveforms corresponding to the fast and slow shear azimuth directions.', 'In summary, both the fast and slow shear slownesses together with the fast shear azimuth direction are inputs to a complete formation anisotropy characterization.', "Wireline acoustic measurement tools, such as Schlumberger's Sonic Scanner™, has been commercialized to provide such complete formation anisotropy characterization.", 'However, the same anisotropy characterization has not been available in LWD acoustic measurement tools, due to a number of fundamental challenges in LWD acoustic measurement tools.', 'These challenges include the following: \n \n \n \nstrong interference and coupling from collar modes in LWD acoustic measurement tools;\n \ncross-dipole orthogonal firing cannot be maintained in LWD acoustic measurement tools;\n \ntool eccentering in LWD acoustic measurement tools; and\n \nsignal-to-noise ratio (SNR) in LWD acoustic measurement tools.', 'With regard to the first challenge regarding strong interference and coupling from collar modes in the LWD acoustic measurement tool, the LWD acoustic measurement tool has to be mechanically competent for drilling and the drill-collar mode interferes with the formation mode of interest.', 'This is unlike the wireline Sonic Scanner™.', 'In fact, the drill-collar mode dominates the acoustic response especially for the dipole flexural modes in fast formations and strongly couples with the formation mode of interest.', 'Note that a LWD acoustic measurement tool consists of a stiff drill collar to survive the harsh drilling environment.', 'As shown in \nFIG.', '3\n, the stiff drill-collar supports propagation of a drill-collar mode (dashed blue curve) that interferes with a formation flexural mode (dashed green curve).', 'The drill-collar mode intersects the formation flexural mode in a fast formation.', 'As these two modes interact in a composite structure, they cannot simply overlay on top of each other.', 'Instead, they repel one from the other to form the coupled collar-formation mode (top blue solid curve, also referred to as the tool flexural mode) and the formation-collar mode (bottom green solid curve, also referred to as the formation flexural mode).', 'Moreover, the drill-collar flexural mode is usually the dominant one.', 'Therefore, a conventional wireline dipole workflow developed for handling a single formation mode cannot be applied to this complex scenario.', 'The second challenge stems from the fact that the cross-dipole orthogonal firing is unavailable in the LWD acoustic measurement tool due to tool pipe rotation and therefore cannot be assumed.', 'The cross-dipole orthogonal firing in a wireline acoustic measurement tool is shown in \nFIGS.', '4\nA and \n4\nB\n.', 'The wireline acoustic measurement tool includes an array of receivers or receiver stations (labeled 1, 2, 3, 4) that are offset at 90 degrees relative to one another about the circumference of the wireline acoustic measurement tool. \nFIG.', '4\nA\n shows the cross-sectional coordinate system of the X-Dipole firing.', 'The X-Dipole direction, which is denoted by the solid line with arrow, is offset θ-degrees from the fast shear direction.', 'This fast shear direction aligns with the inline receivers (e.g., the azimuthal receiver stations 1 and 3) and perpendicular to the crossline receivers (e.g., the azimuthal receiver stations 2 and 4) of the receiver array for the X-Dipole firing.', 'The fast and slow shear directions are denoted as dashed black lines with arrows in \nFIG.', '4\nA\n.', 'FIG.', '4\nB\n shows the cross-sectional coordinate system of the Y-Dipole firing.', 'The Y-Dipole direction, which is denoted by the solid line with arrow, is (θ+90°)-degree away from the fast shear direction.', 'This fast shear direction aligns with the inline receivers (e.g., the azimuthal receiver stations 2 and 4) and perpendicular to the crossline receivers (e.g., the azimuthal receiver stations 1 and 3) for the Y-dipole firing.', 'The fast and slow shear directions are denoted as dashed black lines with arrows in \nFIG.', '4\nB\n.', 'The cross-dipole orthogonal firing (X-dipole firing/Y-dipole firing) of the wireline acoustic measurement tool enables acquisition of four-component waveforms for the receiver array.', 'The four-component waveforms include an X-Inline waveform, an X-Crossline waveform, a Y-Inline waveform, and a Y-Crossline waveform.', 'The four-component waveforms can be synthetically rotated towards the fast and slow shear polarization directions by minimizing the total crossline energy, for example via the Alford rotation algorithm as described in i) R. M. Alford, “Shear data in the presence of azimuthal anisotropy,” 56th Ann.', 'Internat.', 'Mtg., Sot. Explor.', 'Geophys., Expanded Abstracts, 476-479, 1986; and ii) C. Esmersoy, K. Koster, M. Williams, A. Boyd and M. Kane, “Dipole shear anisotropy logging”, 64th Ann.', 'Internat.', 'Mtg., Soc.', 'Expl.', 'Geophys., Expanded Abstracts, 1139-1142, 1994.', 'In contrast to the wireline acoustic measurement tool, the orthogonality of the two LWD dipole firings for each depth is no longer maintained due to the fast tool rotation with variable speeds during the drilling process.', 'An example of the two LWD dipole firings is shown in \nFIGS.', '5\nA and \n5\nB\n.', 'Note that the LWD acoustic measurement tool also includes an array of receivers or receiver stations (labeled 1, 2, 3, 4) that are offset at 90 degrees relative to one another about the circumference of the LWD acoustic measurement tool. \nFIG.', '5\nA\n shows the cross-sectional coordinate system of the D1 (Dipole-1) firing.', 'The D1 direction, which is denoted by the solid line with arrow, is offset θ-degrees from the fast shear direction.', 'This fast shear direction aligns with the inline receivers (e.g., the azimuthal receiver stations 1 and 3) and perpendicular to the crossline receivers (e.g., the azimuthal receiver stations 2 and 4) of the receiver array for the D1 firing.', 'The fast and slow shear directions are denoted as dashed black lines with arrows in \nFIG.', '5\nA\n.', 'FIG.', '5\nB\n shows the cross-sectional coordinate system of the D2 firing.', 'The D2 direction, which is denoted by the solid line with arrow, is offset (θ+ϕ)-degrees from the fast shear direction.', 'The fast shear direction aligns with the inline receivers (e.g., the azimuthal receiver stations 2 and 4) and perpendicular to the crossline receivers (e.g., the azimuthal receiver stations 1 and 3) of the array for the D2 firing.', 'The D1 and D2 dipole firings of the LWD acoustic measurement tool enables acquisition of four-component waveforms for the receiver array.', 'The four-component waveforms include an X-Inline waveform, an X-Crossline waveform, a Y-Inline waveform, and a Y-Crossline waveform.', 'Due to the non-orthogonal nature of the D1 and D2 firings, the four-component Alford waveform rotation used for the wireline acoustic measurement tool cannot be applied to the four-components waveforms of the LWD acoustic measurement tool.', 'The third challenge stems from eccentering of the LWD acoustic measurement tool during the LWD operations.', 'Since the fast rotation of drill string precludes the use of centralizers with the LWD acoustic measurement tools, stabilizers are used to limit the amount of eccentering.', 'However, the use of these stabilizers cannot provide a complete centralization of the LWD acoustic measurement tool.', 'The amount of tool eccentering is further aggravated in deviated wells.', 'Large amount of eccentering poses additional challenges for the anisotropic processing of LWD dipole sonic data.', 'The fourth challenge stems from the SNR of the LWD acoustic measurement tool.', 'Compared with the wireline logging environment, the acquired data in the LWD environment is usually corrupted by the drilling noise, shocks, and vibration.', 'Furthermore, the directional nature of the dipole transmitters precludes the use of waveform stacking as used for the monopole and quadrupole logging with a rotating drill string.', 'To overcome the aforementioned challenges, the present disclosure introduces two independent workflows that can be used to calculate a parameter value that characterizes the fast shear azimuth direction of the formation from the processing of dipole waveforms acquired by an LWD-acoustic measurement tool.', 'The first workflow consists of a time-domain, non-orthogonal waveform rotation algorithm using the four-component waveforms from the two non-orthogonal LWD dipole firings.', 'The second workflow is based on a frequency-domain processing of the dipole sonic data.', 'This processing is a multi-component rotation algorithm that accounts for the presence of the drill collar and its associated drill-collar flexural mode in the recorded dipole waveforms.', 'The output from either of the two workflows is a parameter value that represents the fast shear azimuth direction of the formation, which can be used as an input to the formation stress and fracture analyses.', 'For example, the parameter value that represents the fast shear azimuth direction of the formation can be used to synthetically rotate the LWD dipole waveforms acquired by a LWD acoustic measurement tool to point toward the fast and slow shear directions.', 'Then the fast and slow formation shear slownesses can be estimated from the rotated waveforms using a data-driven or model-based and/or workflow.', 'Thus, by cascading the LWD dipole waveform rotation and the dipole shear slowness estimation, complete characterization of the anisotropy of the formation can be provided by the LWD tool.', 'An example of a workflow that estimates fast and slow formation shear slownesses from acoustic waveforms is described in U.S. patent application Ser.', 'No. 15/331,946, filed on Oct. 24, 2016, entitled “Determining Shear Slowness from Dipole Source-based Measurements Acquired by a Logging-While-Drilling Acoustic Measurement Tool.”', 'In this workflow, for the case where the acoustic measurements are acquired in a fast formation and are associated with a relatively high SNR (an SNR at, near or above 20 dB, for example), the fast and slow formation shear slownesses can be determined from a low frequency formation flexural asymptote engine, which bases the shear slowness determination on a low-frequency asymptote of extracted flexural dispersions.', 'For the other cases (slow formations or fast formation coupled with a lower SNR), the fast and slow formation shear slownesses can be determined from a model-based inversion engine, which employs a model that explicitly accounts for the presence of the acoustic measurement tool in the borehole.', 'As such, the model-based inversion engine may consider such model inputs as compressional slowness, formation density, mud density, hole diameter, and so forth.', 'Therefore, for the slow formation, when the tool flexural acoustic mode significantly interferes with the formation flexural acoustic mode at the low frequency region, the model-based inversion is used, as the low-frequency asymptote of the extracted flexural dispersion no longer converges to the shear slowness.', 'In accordance with example implementations, the model-based inversion engine can use a boundary condition determinant associated with a concentrically placed cylindrical structure to construct the cost function and estimate multiple physical parameters of interest from numerical optimization techniques.', 'Another example of a workflow that estimates fast and slow formation shear slownesses from acoustic waveforms is described in U.S. patent application Ser.', 'No. 15/331,958, filed on Oct. 24, 2016, entitled “Determining Shear Slowness Based on a High Order Formation Flexural Acoustic Mode.”', 'In this workflow, acoustic modes (including the first and third order formation flexural acoustic modes) are extracted from the acoustic waveforms.', 'The extracted acoustic modes are processed by a high frequency slowness frequency analysis (HF-SFA) engine based on input parameters (such as a slowness range and a frequency range).', 'These ranges may be user selected, in accordance with example implementations.', 'The HF-SFA engine non-coherently integrates the dispersion energy along the frequency axis to provide an output.', 'A peak finding engine identifies at least one peak in the integrated energy, and this peak corresponds to an estimated or determined shear slowness.', 'FIG.', '6\n illustrates a wellsite system in which the workflows of the present disclosure can be employed.', 'The wellsite can be onshore or offshore.', 'In this exemplary system, a borehole \n11\n is formed in subsurface formations by rotary drilling in a manner that is well known.', 'Embodiments of the present disclosure can also use directional drilling, as will be described hereinafter.', 'A drill string \n12\n is suspended within the borehole \n11\n and has a bottom hole assembly \n100\n which includes a drill bit \n105\n at its lower end.', 'The surface system includes platform and derrick assembly \n10\n positioned over the borehole \n11\n.', 'The assembly \n10\n includes a rotary table \n16\n, kelly \n17\n, hook \n18\n and rotary swivel \n19\n.', 'The drill string \n12\n is rotated by the rotary table \n16\n, energized by means not shown, which engages the kelly \n17\n at the upper end of the drill string.', 'The drill string \n12\n is suspended from a hook \n18\n, attached to a traveling block (also not shown), through the kelly \n17\n and a rotary swivel \n19\n which permits rotation of the drill string relative to the hook.', 'As is well known, a top drive system could alternatively be used.', 'In the example of this embodiment, the surface system further includes drilling fluid or mud \n26\n stored in a pit \n27\n formed at the well site.', 'A pump \n29\n delivers the drilling fluid \n26\n to the interior of the drill string \n12\n via a port in the swivel \n19\n, causing the drilling fluid to flow downwardly through the drill string \n12\n as indicated by the directional arrow \n8\n.', 'The drilling fluid exits the drill string \n12\n via ports in the drill bit \n105\n, and then circulates upwardly through the annulus region between the outside of the drill string and the wall of the borehole, as indicated by the directional arrows \n9\n.', 'In this well known manner, the drilling fluid lubricates the drill bit \n105\n and carries formation cuttings up to the surface as it is returned to the pit \n27\n for recirculation.', 'The bottom hole assembly \n100\n of the illustrated embodiment has a logging-while-drilling (LWD) tool \n120\n, a measuring-while-drilling (MWD) tool \n130\n, a roto-steerable system \n150\n, and drill bit \n105\n.', 'In other embodiments, the bottom hole assembly \n100\n can include a mud motor that is powered by the flow of the drilling fluid and drives the rotation of the drill bit \n105\n.', 'The LWD tool \n120\n is housed in a special type of drill collar, as is known in the art, and can contain one or a plurality of known types of logging tools.', 'It will also be understood that more than one LWD and/or MWD tools can be employed, e.g. as represented at \n120\nA. The LWD tool includes capabilities for measuring, processing, and storing information, as well as for communicating with the surface equipment.', 'In the present embodiment, the LWD tool includes at least a dipole transmitter that transmits directional D1 and D2 dipole firings and an array of receivers for receiving the four-component waveforms of the acoustic energy that results from the directional D1 and D2 dipole firings as described herein.', 'The MWD module \n130\n is also housed in a special type of drill collar, as is known in the art, and can contain one or more devices for measuring characteristics of the drill string and drill bit.', 'In the present embodiment, the MWD module includes one or more of the following types of measuring devices: a weight-on-bit measuring device, a torque measuring device, a vibration measuring device, a shock measuring device, a stick slip measuring device, a direction measuring device, and an inclination measuring device.', 'The LWD tool further includes an apparatus (not shown) for generating electrical power to the downhole system.', 'This may typically include a mud turbine generator powered by the flow of the drilling fluid, it being understood that other power and/or battery systems may be employed.', 'FIG.', '7\n schematically illustrates selected components of the acoustic measurement LWD module \n120\n of \nFIG.', '6\n according to embodiments of the subject disclosure.', 'A pipe portion \n203\n defines a mud channel \n205\n.', 'Distributed on the pipe portion \n203\n is a number of acoustic transmitters including a pair of dipole transmitters \n201\n that transmit directional D1 and D2 dipole firings.', 'An array of receivers \n207\n and receiver electronics \n211\n are distributed on the pipe portion \n203\n.', 'The array of receivers receive the four-component waveforms of the acoustic energy that results from the directional D1 and D2 dipole firings as described herein.', 'A surface-located processing facility \n151\n (\nFIG.', '6\n) controls the D1 and D2 firings of the dipole transmitters \n201\n and the receiver electronics \n211\n.', 'The processing facility \n151\n can be located in one or more locations at the wellsite.', 'According to some embodiments, the processing facility \n151\n can process and interpret the data from the acoustic measurement LWD module \n120\n at one or more locations remote from the wellsite.', 'The processing facility \n151\n may include one or more central processing units, storage systems, communications and input/output modules, a user display, and a user input system.', 'Time-Domain Workflow\n \nAn embodiment of the first workflow that employs a time-domain LWD four-component waveform rotation scheme is summarized in the flow chart of \nFIG.', '8\n.', 'The embodiment follows the geometry of the D1 and D2 dipole firing and the inline and crossline waveforms received by the receiver array described above with respect to \nFIGS.', '5\nA and \n5\nB\n.', 'In optional block \n801\n, the time domain inline and crossline array waveforms of the acoustic energy arising from the D1 LWD dipole firing as received by the receivers of the receiver array can be filtered to remove unwanted noise components.', 'Such filtering can be carried out in one or more domains, such as in the time domain (e.g., time window processing), frequency domain (e.g., bandpass filtering), the slowness domain (e.g., semblance, Nth-root stacking processing), and in the time-frequency domain (using wavelets or other time-frequency representations).', 'In optional block \n803\n, the time domain inline and crossline array waveforms of the acoustic energy arising from the D2 LWD dipole firing as received by the receivers of the receiver array can be filtered to remove unwanted noise components.', 'Such filtering can be carried out in one or more domains, such as in the time domain (e.g., time window processing), frequency domain (e.g., bandpass filtering), the slowness domain (e.g., semblance, Nth-root stacking processing), and in the time-frequency domain (using wavelets or other time-frequency representations).', 'In block \n805\n, the time-domain inline and crossline array waveforms corresponding to the D1 LWD dipole firing as provided by the waveform filtering of block \n801\n (or as received by the receivers of the receiver array if the waveform filtering of block \n801\n is omitted) can be represented as a D1 data vector/matrix u\nD1 \nas follows:\n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n\u2062\n \n \n{\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n \n \n)\n \n \n=\n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nO\n \n\u2062\n \nF\n \n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n]\n \n \n \n \n \n \nEqn\n \n.', '(\n \n1\n \n)\n \n \n \n \n \n \n \n \n where u\nD1IN\n(t,z\nm\n) and u\nD1OF\n(t,z\nm\n) are, respectively, the time-domain inline and crossline array waveforms at the m-th receiver at a given time t, and z\nm \ndenotes the axial location of the m-th receiver.', 'In total there are M receivers.', 'For example, \nFIGS.', '5\nA and \n5\nB\n illustrate an example where there are 4 azimuthal receivers at a given axial location.', 'Other embodiments can use more than four azimuthal receivers at a given axial location.', 'The azimuthal receiver configuration can be stacked/replicated over a number of axial locations offset from the dipole source for increased sensitivity.', 'In this case, the number of azimuthal receivers at each axial location can be summed together with a sinusoidal function as weights to give the M total receivers.', 'In an anisotropic formation, the time-domain inline array waveforms u\nD1IN \nand crossline array waveforms u\nD1OF \narising from the D1 dipole firing consist of contributions from both the fast and slow shear propagations of the D1 dipole firing.', 'As a result, the D1 data vector/matrix u\nD1 \ncan be represented as follows:\n \n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n=\n \n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nI\n \n\u2062\n \nN\n \n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nO\n \n\u2062\n \nF\n \n \n \n\u2062\n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n=\n \n \n \n \n[\n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \nsin\n \n\u2062\n \nθ\n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n]\n \n \n[\n \n \n \n \n \n \ns\n \n\u2061\n \n(\n \nt\n \n)\n \n \n*\n \n \n \ng\n \nf\n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n0\n \n \n \n \n \n0\n \n \n \n \n \ns\n \n\u2061\n \n(\n \nt\n \n)\n \n \n*\n \n \n \ng\n \ns\n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n]', '[\n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \nsin\n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nθ\n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n]\n \n \n[\n \n \n \n \n1\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n=\n \nΔ\n \n \n \n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n\u2062\n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)\n \n \n\u2062\n \nS\n \n \n \n \n \n \n \n \n \nEqn\n \n.', '(\n \n2\n \n)\n \n \n \n \n \n \n \n \n Note that the rotation matrix R(θ) is used to project the waveforms twice, one from the D1 dipole source to the fast/slow shear directions and another (the transpose of the rotation matrix R(θ)) from the fast/slow shear directions to the receiver z\nm\n.', 'The matrix D(t, z\nm\n) denotes the propagating waveforms directly in the fast and slow shear directions (e.g., the diagonal elements).', 'The vector S is a selection vector for the two-component waveforms for the D1 dipole firing.', 'In block \n807\n, the time-domain inline and crossline array waveforms corresponding to the D2 LWD dipole firing as provided by the waveform filtering of block \n803\n (or as received by the receivers of the receiver array if the waveform filtering of block \n803\n is omitted) can be represented in a D2 data/vector matrix form.', 'Assuming the source signatures from the D1 and D2 dipole firings are the same, the time-domain inline and crossline array waveforms corresponding to the D2 LWD dipole firing can be represented as a D2 data/vector matrix u\nD2 \nas follows:\n \n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n2\n \n \n \n=\n \n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n2\n \n\u2062\n \nIN\n \n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n2\n \n\u2062\n \nOF\n \n \n \n\u2062\n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n=\n \n \n \n[\n \n \n \n \n \ncos\n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n \n \n \n \n \n \nsin\n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)', 'cos\n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n \n[\n \n \n \n \n \n \ns\n \n\u2061\n \n(\n \nt\n \n)\n \n \n*\n \n \n \ng\n \nf\n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n0\n \n \n \n \n \n0\n \n \n \n \n \ns\n \n\u2061\n \n(\n \nt\n \n)\n \n \n*\n \n \n \ng\n \ns\n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n]', '[\n \n \n \n \n \ncos\n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n \n \n \n \nsin\n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n \n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n \n \n \n \ncos\n \n\u2062\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n \n \n \n \n]', '[\n \n \n \n \n1\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n=\n \nΔ\n \n \n \n \n \nR\n \n\u2061\n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n\u2062\n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n\u2062\n \n \n \nR\n \nT\n \n \n(\n \n \nθ\n \n+\n \nϕ\n \n \n)\n \n \n\u2062\n \nS\n \n \n \n \n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n3\n \n)\n \n \n \n \n \n \n \n \n Note that the rotation matrix R(θ+ϕ) for the D2 dipole firing employs a rotation angle of θ+ϕ. Note that the rotation matrix R(θ+ϕ) is used to project the waveforms twice, one from the D2 dipole source to the fast/slow shear directions and another (the transpose of the rotation matrix R(θ+ϕ)) from the fast/slow shear directions to the receiver z\nm\n.', 'The matrix D(t, z\nm\n) denotes the propagating waveforms directly in the fast and slow shear directions (e.g., the diagonal elements).', 'The vector S is a selection vector for the two-component waveforms for the D2 dipole firing.', 'It is worth noting that the rotation matrix R(θ+ϕ) has the following property: \n \nR\n(θ+ϕ)=\nR\n(ϕ)\nR\n(θ), \n \nR\n(θ)\nR\nT\n(θ)=\nI\n2\n\u2003\u2003Eqn.', '(4) \n \nwhere I\n2 \nis the identity matrix of dimension 2.\n \nTherefore, the Eqn.', '(3) arising from the D2 dipole firing is equivalent to:', 'u\nD2\n=R\n(ϕ)\nR\n(θ)\nD\n(\nt,z\nm\n)\nR\nT\n(θ)\nR\nr\n(ϕ)\nS\n\u2003\u2003Eqn.', '(5)', 'In block \n809\n, a rotation matrix R(ϕ) is defined for the D2 data/vector u\nD2 \nas:\n \n \n \n \n \n \n \n \n \nR\n \n\u2061\n \n(\n \nϕ\n \n)', '=\n \n \n \n[\n \n \n \n \n \ncos\n \n\u2062\n \nϕ\n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nϕ\n \n \n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nϕ\n \n \n \n \n \ncos\n \n\u2062\n \nϕ\n \n \n \n \n \n]\n \n \n.', 'Eqn\n \n.', '(\n \n6\n \n)\n \n \n \n \n \n \n \n \n Note that the angle ϕ represents the angle difference between the D1 and D2 firings as follows: \n \n \n \n \n \n \n \n \n \n \n \n \nR\n \nT\n \n \n(\n \nϕ\n \n)', '\u2062\n \n \nu\n \n \nD\n \n\u2062\n \n2\n \n \n \n \n=\n \n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n\u2062\n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nS\n \n˜\n \n \n \n \n\u2062\n \n \n \n \nwhere\n \n\u2062\n \n \n \n \n \n \nS\n \n˜\n \n \n \n=\n \n \n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)\n \n \n\u2062\n \nS\n \n \n=\n \n \n \n[\n \n \n \n \n \ncos\n \n\u2062\n \nϕ\n \n \n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nϕ\n \n \n \n \n \n]\n \n \n.', 'Eqn\n \n.', '(\n \n7\n \n)\n \n \n \n \n \n \n \n \n Note that the rotation matrix R\nT\n(ϕ) is the transpose of the rotation matrix R(ϕ).', 'In block \n811\n, rotation matrix R(θ) and rotation matrix P(ϕ) are defined as follows:\n \n \n \n \n \n \n \n \n \n \n \n \n \nR\n \n\u2062\n \n \n(\n \nθ\n \n)\n \n \n \n=\n \n \n[\n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n \n]\n \n \n \n,\n \n \n \nand\n \n \n \n \n \n \n \n \nP\n \n\u2062\n \n \n(\n \nϕ\n \n)', '=\n \n \n \n[\n \n \n \n \n1\n \n \n \n \ncos\n \n\u2062\n \nϕ\n \n \n \n \n \n \n1\n \n \n \n \n \n-\n \ns\n \n \n\u2062\n \nin\n \n\u2062\n \nϕ\n \n \n \n \n \n]\n \n \n.', 'Eqn\n \n.\n \n \n \n \n(\n \n8\n \n)', 'In block \n813\n, a four-component data vector u can be defined by combining the D1 data vector/matrix u\nD1 \nfrom the D1 dipole firing (block \n805\n) and the rotated data vectors R\nT\n(ϕ)u\nD2 \nfrom the D2 dipole firing (block \n807\n and Eqn.', '(6)) as follows:\n \n \n \n \n \n \n \n \n \n \n \nu\n \n=\n \n \n \n[\n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n \n \n \n \n \n \n \nR\n \nT\n \n \n(\n \nϕ\n \n)', '\u2062\n \n \nu\n \n \nD\n \n\u2062\n \n2\n \n \n \n \n]\n \n \n=\n \n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n\u2062\n \n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)', '[\n \n \nS\n \n,\n \n \nS\n \n~\n \n \n \n]\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n=\n \n \n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nD\n \n(\n \n \n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n\u2062\n \n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)', '[\n \n \n \n \n1\n \n \n \n \ncos\n \n\u2062\n \nϕ\n \n \n \n \n \n \n0\n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nϕ\n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n \n \n=\n \n \n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n\u2062\n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nP\n \n\u2061\n \n(\n \nϕ\n \n)', 'Eqn\n \n.\n \n \n \n \n(\n \n9\n \n)\n \n \n \n \n \n \n \n \n Furthermore, the four-component data vector u can be rotated based on the rotation matrices R(θ) and P(ϕ) (Eqn. (8)) to define a matrix D(t,z\nm\n) as follows: \n \nD\n(\nt,z\nm\n)=\nR\nT\n(θ)[\nu\nD1\nR\nT\n(ϕ)\nu\nD2\n]P\n−1\n(ϕ)\nR\n(θ)\u2003\u2003Eqn.', '(10) \n \nThen, in block \n815\n, a cost function that involves the total crossline energy of the matrix D(t,z\nm\n) across all of the M receivers and all time samples can be evaluated and minimized by computer-implemented methods as follows:\n \n \n \n \n \n \n \n \n \n \nmin\n \n \nθ\n \n,\n \nϕ\n \n \n \n \n \n \n∑\n \n \n \nt\n \n0\n \n \n+\n \nT\n \n \n \n \nt\n \n=\n \n \nt\n \n0\n \n \n \n \n \n \n∑\n \n \nm\n \n=\n \n1\n \n \nM\n \n \n \n \n \noff\n \n\u2062\n \n \n \n \n{\n \n \nD\n \n\u2061\n \n(\n \n \nt\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n}\n \n \n \n \n \n \n=\n \n \n \nmin\n \n \nθ\n \n,\n \nϕ\n \n \n \n \n \n \n∑\n \n \nt\n \n=\n \n \nt\n \n0\n \n \n \n \n \n \nt\n \n0\n \n \n+\n \nT\n \n \n \n \n \n∑\n \n \nm\n \n=\n \n1\n \n \n \nM\n \n \n \n \noff\n \n\u2062\n \n \n \n \n{\n \n \n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)', '[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n \n \n \n \nR\n \nT\n \n \n(\n \nϕ\n \n)', '\u2062\n \n \nu\n \n \nD\n \n\u2062\n \n2\n \n \n \n \n]\n \n \n\u2062\n \n \n \nP\n \n \n-\n \n1\n \n \n \n(\n \nϕ\n \n)\n \n \n\u2062\n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n}\n \n \n \n \n \n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n11\n \n)\n \n \n \n \n \n \n \n \n where off{D} computes the sum of all off-diagonal elements of D, t\n0 \nis the time index of the first sample, and T is the total sample duration.', 'In certain scenarios, a magnetometer of the LWD acoustic measurement tool can measure both D1 and D2 firing azimuth directions up to a certain precision with respect to a reference (e.g., the direction of gravity).', 'Such output can provide an a priori range of θ: θ∈[θ\n1l\n,θ\n1h\n] and (θ+ϕ): (θ+ϕ)∈[θ\n2l\n,θ\n2h\n] with respect to the same reference direction.', 'This provides a feasible range of the angle ϕ as follows: \n ϕ∈[θ\n2l\n−θ\n1h\n,θ\n2h\n−θ\n1l\n]\u2003\u2003Eqn.', '(12) \n \nTherefore, the two rotation angles θ, ϕ can be determined by computer-implemented methods that solve the following constrained minimization problem:\n \n \n \n \n \n \n \n \n \n \nmin\n \n \nθ\n \n,\n \nϕ\n \n \n \n \n \n∑\n \n \nt\n \n=\n \n \nt\n \n0\n \n \n \n \n \nt\n \n0\n \n \n+\n \nT\n \n \n \n \n \n∑\n \n \nm\n \n=\n \n1\n \n \nM\n \n \n \n \n \noff\n \n\u2062\n \n \n \n \n{\n \n \n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)', '[\n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n \n \n \n \nR\n \nT\n \n \n\u2062\n \n \n(\n \nϕ\n \n)\n \n \n\u2062\n \n \nu\n \n \nD\n \n\u2062\n \n2\n \n \n \n \n \n \n \n]\n \n \n\u2062\n \n \n \nP\n \n \n-\n \n1\n \n \n \n(\n \nϕ\n \n)\n \n \n\u2062\n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n}\n \n \n \n \n \n \n,\n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n13\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \ns\n \n.', 't\n \n.\n \n \n,\n \n \nϕ\n \n∈\n \n \n[\n \n \n \n \nθ\n \n \n2\n \n\u2062\n \nl\n \n \n \n-\n \n \nθ\n \n \n1\n \n\u2062\n \nh\n \n \n \n \n,\n \n \n \nθ\n \n \n3\n \n\u2062\n \nh\n \n \n \n-\n \n \nθ\n \n \n1\n \n\u2062\n \nl\n \n \n \n \n \n]\n \n \n \n \n \n \n \nOnce θ and ϕ have been determined, the fast shear direction of the formation can be calculated as θ\n1\n=θ degrees away from the D1 dipole firing direction.', 'In other words, the value of the parameter θ\n1 \nrepresents the fast shear direction of the formation.', 'The fast shear direction of the formation can also be calculated as θ\n2\n=(θ+ϕ)', 'degrees away from the D2 dipole firing direction.', 'In other words, the value of the parameter θ\n2 \nrepresents the fast shear direction of the formation.', 'The slow shear direction of the formation can be calculated by an offset of 90° relative to the fast shear direction of the formation as is evident from \nFIGS.', '5\nA and \n5\nB\n.', 'Note that if the angle difference between the D1 and D2 firing is known (e.g., the D1 and D2 firing directions can be determined precisely), the rotation angle ϕ is known and the two-dimensional minimization of Eqn.', '(13) reduces to a one-dimensional minimization over θ.', 'In order to validate the first workflow, consider an example of the horizontal section of a fast TIV formation (e.g., the Bakken shale formation).', 'The synthetic data, generated by forward modeling code, simulates a fast formation with an LWD acoustic measurement tool centered in the borehole.', 'The formation, mud and tool parameters of the forward modeling code are listed in Table 1 below:\n \n \n \n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \n \nParameters\n \nValues\n \nUnits\n \n \n \n \n \n \n \n \n \nDTs(slow)\n \n2170', 'm/s (us/ft)\n \n \n \n \n \n(141)\n \n \n \n \n \nDTs(fast)\n \n2619 \n \nm/s (us/ft)\n \n \n \n \n \n(116)\n \n \n \n \n \nDTc\n \n3473 \n \nm/s (us/ft)\n \n \n \n \n \n(88)\n \n \n \n \n \nρ\nF\n \n2230\n \nkg/m\n3\n \n \n \n \nDTm\n \n1500 \n \nm/s (us/ft)\n \n \n \n \n \n(203)\n \n \n \n \n \nρ\nM\n \n1000\n \nkg/m\n3\n \n \n \n \nDT\nstool\n \n3110 \n \nm/s (us/ft)\n \n \n \n \n \n(98)\n \n \n \n \n \nDTc\ntool\n \n5751 \n \nm/s (us/ft)\n \n \n \n \n \n(53)\n \n \n \n \n \nρ\nT\n \n7630\n \nkg/m\n3\n \n \n \n \nD\n \n\u2003\u20020.1600 \n \nm (in)\n \n \n \n \n \n(6.3)', 'The LWD acoustic measurement tool contains 12 axial receivers placed at a distance from 7 ft to 10.6 ft away from a dipole transmitter with an inter-element spacing of 0.2 ft. \n \nFIGS.', '9\nA and \n9\nB\n show the synthetic received time-domain array waveforms generated from the dipole transmitter in the horizontal section of the fast TIV formation.', 'The D1 and D2 firings are, respectively, 15 and 85 degrees away from the slow shear azimuth.', 'In this case, the D1 inline array waveforms are mostly dominated by the propagation from the slow shear direction, while the D2 inline array waveforms are mostly dominated by the propagation from the fast shear direction.', 'FIG.', '9\nC\n shows the slowness dispersions generated from the dipole transmitter in the horizontal section of the fast TIV formation.', 'The slowness dispersions represent the dipole flexural dispersion extracted by the matrix pencil method, referred to as the TKO algorithm and described in M. P. Ekstrom, “Dispersion estimation from borehole acoustic arrays using a modified matrix pencil algorithm,”', 'Proc. 29th Asilomar Conf.', 'Signals, Syst., Comput., vol.', '2, Pacific Grove, Calif., November 1995, pp. 449-453. \nFIG.', '9\nC\n shows that two flexural modes are present in the fast TIV formation.', 'The upper branch (above 200 us/ft) is the dominant drill-collar flexural dispersion, while the lower branch is the formation flexural dispersion.', 'The low frequency asymptotes of the formation flexural dispersions (D1 shown with dots labeled with “∘” and D2 shown with dots labeled with “+”) approach to the fast and slow shear slownesses in Table 1.', 'Specifically, the formation flexural dispersion of D1 is similar to the slow flexural dispersion as D1 is close to the slow shear azimuth.', 'FIG.', '10\n shows a two-dimensional cost function of the four-component non-orthogonal LWD waveform rotation in the (θ\n1\n=θ, θ\n2\n=θ+ϕ) plane (Block \n815\n of \nFIG. \n8\n) for the synthetic example of \nFIGS.', '9\nA and \n9\nB\n.', 'The two dashed lines are constraints for the upper and lower limit of the angle difference between the D1 and D2 firing directions.', 'Such constraints can be derived from the tolerance of D1 and D2 firing directions as measured during rotation of the LWD acoustic measurement tool, for example by a magnometer.', 'It is easy to observe that the global minima are located at (14.2°, 84.9°) and (104.2°, 174.9°) for [θ, θ+ϕ)].', 'Note that there is a 90° ambiguity in the [θ, θ+ϕ)] plane as one can rotate D1 to the fast shear direction and D2 to the slow shear direction or vice versa.', 'Since the workflow values the cost function to find the minimization of the total crossline energy, the coordinates of the global minima give the estimated rotation angles.', 'From \nFIG. \n10\n, the workflow searches for the minima within a bounded region (in between the two dashed lines) and the local minima are seen at (θ\n1\n=14.2°, θ\n2\n=84.9°) and (θ\n1\n=104.2°, θ\n2\n=174.9°), where the former one gives the slow shear polarization direction (i.e., 14.2° away from the D1 firing or 84.9° away from the D2 firing) and the latter one yields the fast shear direction due to a 90° ambiguity.', 'Nevertheless, the 90° ambiguity can be removed by rotating the four-component waveforms and identifying which rotated waveforms correspond to the fast and slow flexural waveforms as described in C. Esmersoy, K. Koster, M. Williams, A. Boyd and M. Kane, “Dipole shear anisotropy logging”, 64th Ann.', 'Internat.', 'Mtg., Soc.', 'Expl.', 'Geophys., Expanded Abstracts, 1139-1142, 1994.', 'FIGS.', '11\nA and \n11\nB\n show the rotated inline and crossline array waveforms for the D1 and D2 dipole firings of \nFIGS.', '9\nA and \n9\nB\n.', 'Particularly, the D1 firing is rotated to the slow shear direction while D2 is rotated towards the fast shear direction using the estimated rotation angles from \nFIG.', '10\n.', 'Note that the crossline energy of the rotated waveforms is significantly minimized and the inline waveform energy is enhanced.', 'The modified matrix pencil algorithm (TKO method) can be used to extract the dispersion curves from the rotated inline array waveforms of D1 and D2.', 'FIG.', '11\nC\n shows the corresponding slowness dispersions.', 'Note that formation flexural dispersion (dots labeled with “∘”) of the rotated D1 captures the slow flexural wave, while the formation flexural dispersion (dots labeled with “+”) of the rotated D2 converges to the fast flexural shear around 110 us/ft.\n \nFIGS. \n12\nA and \n12\nB\n show synthetic time-domain array waveforms arising from the D1 and D2 firings of the dipole transmitter in the horizontal section of a fast Try formation.', 'The D1 and D2 firings are, respectively, 35° and 67° away from the slow shear azimuth.', 'In this case, the D1 and D2 inline array waveforms contain a mixture of both the fast and slow flexural waves.', 'Note that the inline and crossline array waveforms for the D1 and D2 dipole firings are closer to an azimuth direction in between the fast and slow shear direction.', 'Specifically, the the D1 and D2 dipole firings are 35° and 67° away from the slow shear direction, respectively.', 'Compared with the case of \nFIGS.', '9\nA and \n9\nB\n, more waveform energy is split into the crossline channel, as both dipole firings move away from either the fast or slow shear directions. \nFIG.', '12\nC\n shows the corresponding slowness dispersions.', 'In \nFIG. \n12\nC\n, one can no longer see the formation flexural splitting at low frequencies from the inline receivers.\n \nFIG.', '13\n shows the two-dimensional cost function (Block \n815\n of \nFIG. \n8\n) for the synthetic example of \nFIGS.', '12\nA and \n12\nB\n.', 'The two dashed lines represent the constraints for the upper and lower limit of the angle difference between the D1 and D2 firing directions.', 'The estimated rotation angles are (θ\n1\n=34.4°, θ\n2\n=66.7°) within the two dashed lines (the constraints).', 'FIGS.', '14\nA and \n14\nB\n show the rotated inline and crossline array waveforms for the D1 and D2 dipole firings of \nFIGS.', '12\nA and \n12\nB\n.', 'Note that the crossline energy of the rotated array waveforms is significantly minimized and the inline array waveforms display the fast and slow flexural modes.', 'FIG.', '14\nC\n shows the corresponding slowness dispersions.', 'Note that the TKO results on the rotated inline array waveforms recover the formation flexural dispersions splitting at frequencies below 4 kHz.\n \nFIGS.', '15\nA and \n15\nB\n shows the rotated synthesized inline and crossline array waveforms for D1 and D2 dipole firings in the horizontal section of a slow TIV formation.', 'FIG.', '15\nC\n shows the corresponding slowness dispersions.', 'The TKO results in \nFIG.', '15\nC\n show the coupled collar-flexural dispersions corresponding to the inline waveforms from the rotated D1 and D2.', 'The flexural splitting at high frequencies is clearly observed.', 'In this case, the fast and slow shear slownesses can be inverted from the fast and slow flexural dispersions using a model-based workflow as described in U.S. patent application Ser.', 'No. 15/331,946, filed on Oct. 24, 2016, entitled “Determining Shear Slowness from Dipole Source-based Measurements Acquired by a Logging-While-Drilling Acoustic Measurement Tool.”', 'Note that the time-domain workflow as discussed above is computationally efficient.', 'However, its performance may be affected by the strong noise level and the tool eccentering effect in the LWD operation.', 'Moreover, its performance can be affected by mismatch in the source-signatures of the D1 and D2 dipole firings.', 'Thus, a complementary frequency-domain workflow is described below that is intended to relax the limitations of the time-domain workflow.\n \nFrequency-Domain Workflow\n \nAn embodiment of the second workflow that employs a frequency domain LWD multiple-component waveform rotation scheme is summarized in the flow chart of \nFIG.', '16\n.', 'The embodiment follows the geometry of the D1 and D2 dipole firing and the inline and crossline waveforms received by the receiver array described above with respect to \nFIGS.', '5\nA and \n5\nB\n.', 'The frequency-domain workflow, referred to herein as the LWD-DATC workflow, takes into account the presence of drill collar and its associated collar-flexural mode in the waveforms, and outputs a parameter value that represents the Fast Shear Azimuth (FSA) direction of the formation.', 'Compared with the time-domain workflow discussed above, the LWD-DATC workflow is more robust to the presence of noise and any tool eccentering that might be there (insofar as the dispersion is less affected).', 'Furthermore, it is based on processing inline and crossline waveforms generated by a single directional dipole firing.', 'This alleviates the requirement of dipole source matching.', 'The frequency-domain workflow begins in block \n1601\n where a fast Fourier transform is applied to the time domain inline and crossline array waveforms of the acoustic energy arising from the either the D1 or D2 LWD dipole firing as received by the receivers of the receiver array.', 'As an optional part of block \n1601\n, the inline and crossline array waveforms can be filtered to remove unwanted noise components.', 'Such filtering can be carried out in one or more domains, such as in the time domain (e.g., time window processing), frequency domain (e.g., bandpass filtering), the slowness domain (e.g., semblance, Nth-root stacking processing), and in the time-frequency domain (using wavelets or other time-frequency representations).', 'The frequency-domain inline and crossline array waveforms output from block \n1601\n can be represented in a data vector/matrix form.', 'For example, the frequency-domain inline and crossline array waveforms corresponding to the one dipole firing (D1, for instance) can be represented by a two-component data vector/matrix u\nD1 \nas follows:', 'u\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n=\n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOF\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n]\n \n \n \n,\n \n\u205f\n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n14\n \n)\n \n \n \n \n \n \n \n \n \nwhere ω is angular frequency.', 'The two-component data vector/matrix u\nD1 \ncan be expressed as follows:', 'u\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \n \nω\n \n,\n \n \nz\n \nn\n \n \n \n)\n \n \n=\n \n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nn\n \n \n \n)', 'u\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOF\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nn\n \n \n \n)\n \n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n=\n \n \n \n \n \n \n[\n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \nsin\n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n \n]\n \n \n[\n \n \n \n \n \n \ns\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \n \n \ng\n \nf\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n0\n \n \n \n \n \n0\n \n \n \n \n \ns\n \n\u2061\n \n(\n \nω\n \n)', '\u2062\n \n \n \ng\n \ns\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n]', '[\n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \nsin\n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \n-\n \nsin\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \ncos\n \n\u2062\n \nθ\n \n \n \n \n \n \n]\n \n \n[\n \n \n \n \n1\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n=\n \nΔ\n \n \n \n \n \nR\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n\u2062\n \n \nD\n \n\u2061\n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n\u2062\n \n \n \nR\n \nT\n \n \n(\n \nθ\n \n)\n \n \n\u2062\n \nS\n \n \n \n \n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n15\n \n)\n \n \n \n \n \n \n \n \n This two-component data vector/matrix u\nD1 \nis a simple transformation of the time-domain data vector of Eqn.', '(2) into the frequency domain.', 'In order to model the propagation of the pressure field associated with the fast and slow flexural waves, consider a dipole transmitter oriented at an angle θ with respect to the fast shear direction as shown in \nFIG. \n17\n.', 'The dispose transmitter waveform can be decomposed into two virtual sources directed along the fast and slow shear directions.', 'The fast and slow flexural waves with corresponding polarization directions propagate along the borehole in accordance with the fast and slow dispersions.', 'The inline array waveforms U\nXX \nand the crossline array waveforms U\nXY \ncontain contributions from both the fast and slow flexural waves.', 'The model representation of the inline and crossline array waveforms are denoted by U\nXX \nand U\nXY\n, respectively.', 'The model representation of the inline and crossline array waveforms U\nXX \nand U\nXY \ntake the following form: \n \nU\nXX\n=S\nX \ncos\n2\nθg\nf\n+S\nX \nsin\n2\nθg\ns\n, \n \nU\nXY\n=S\nX \nsin θ cos θ\ng\nf\n+S\nX \nsin θ cos θ\ng\ns\n,\u2003\u2003Eqn.', '(16) \n where S\nX \nis the source signature for the dipole transmitter aligned along the X-direction that makes the angle θ with respect to the fast shear direction.', 'The eigenfunctions for the pressure field associated with the fast and slow flexural waves are given as: \n \ng\nf\n(ω,\nz\nm\n)=−ρ\nm\nω\n2 \ncos φζ(\nk\nr\nf\n,k\nz\nf\n,r\n) \n \ng\ns\n(ω,\nz\nm\n)', '=−ρ\nm\nω\n2 \ncos φζ(\nk\nr\ns\n,k\nz\ns\n,r\n)\u2003\u2003Eqn.', '(17) \n where ρ\nm \nis the mud density, r and φ are the radial and azimuthal coordinates, respectively of a given receiver, k\nr \nand k\nz \nare the radial and axial wavenumbers, respectively, for the fast and slow flexural waves (denoted by super-script f and s) with the following association \n \n \n \n \n \n \n \n \n \n \n(\n \n \nk\n \nr\n \ns\n \n \n)', '2\n \n \n=\n \n \n \n \nω\n \n2\n \n \n \nv\n \nm\n \n2\n \n \n \n-\n \n \n \n(\n \n \nk\n \nz\n \ns\n \n \n)\n \n \n2\n \n \n \n \n \n \n \nEqn\n \n.', '(\n \n18\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n(\n \n \nk\n \nr\n \nf\n \n \n)', '2\n \n \n=\n \n \n \n \nω\n \n3\n \n \n \nv\n \nm\n \n2\n \n \n \n-\n \n \n \n(\n \n \nk\n \nz\n \nf\n \n \n)\n \n \n2\n \n \n \n \n \n \n with v\nm \ndenoting the mud compressional velocity.', 'Note that a function ζ can be used to represent the difference between the LWD acoustic measurement tool and wireline acoustic measurement tool.', 'In the wireline acoustic measurement tool, the tool flexural mode is designed to be significantly slower than the formation flexural modes encountered in logging conditions and is moreover attenuated due to the presence of an isolation section between the dipole transmitter and the receivers.', 'Therefore, the formation flexural mode is the dominant one with no interference from the tool flexural mode.', 'In this case, the function ζ is given as: \n ζ(\nk\nr\nf\n,k\nz\nf\n,r\n)', '=\nJ\n1\n(\nk\nr\nf\nr\n)\nAe\njk\ns\nf\nz\nm\n, \n ζ(\nk\nr\ns\n,k\nz\ns\n,r\n)=\nJ\n1\n(\nk\nr\nf\nr\n)\nAe\njk\nz\ns\nz\nm\n\u2003\u2003Eqn.', '(19) \n \nwhere J\n1 \nis the Bessel function of first kind, and \n \n \n \nA is an amplitude coefficient of the Bessel function common to both fast and slow flexural eigenfunctions and obtained from the continuity condition at the borehole surface for the wireline propagation mode.', 'The Bessel function J\n1 \naccounts for the formation flexural mode and is described in the following references: i) B. K Sinha and X. Huang, “Dipole Anisotropy from Two-Component Acquisition: Validation against synthetic data,” Schlumberger-Doll Research Note, 1999; ii) B. K. Sinha, S. Bose and X. Huang, “Determination of dipole shear anisotropy of earth formations”, U.S. Pat.', 'No. 6,718,266 B1, 2002; and iii) S. Bose, B. K. Sinha, S. Sunaga, T. Endo and H. P. Valero, “Anisotropy processing without matched cross-dipole transmitters”, 75th Ann.', 'Internat.', 'Mtg., Soc.', 'Expl.', 'Geophys., Expanded Abstracts, 2007.', 'In the LWD acoustic measurement tool there is direct propagation of the strong drill-collar flexural wave.', 'To account for the existence of the rotating tool pipe and the fact that the receivers are located in the annulus just outside of the rotating tool pipe and inside the formation, the function ζ is modified for either a slow formation or a fast formation to include Bessel functions of the second kind in addition to those of the first kind.', 'In a slow formation, the function ζ is modified as follows: \n ζ(\nk\nr\nf\n,k\nz\nf\n,r\n)=[\nJ\n1\n(\nk\nr\nf\nr\n)\nA+Y\n1\n(\nk\nr\nf\nr\n)\nB]e\njk\nz\nf\nz\nm\n, \n ζ(\nk\nr\ns\n,k\nz\ns\n,r\n)=[\nJ\n1\n(\nk\nr\ns\nr\n)\nA+Y\n1\n(\nk\nr\ns\nr\n)', 'B]e\njk\nz\ns\nz\nm\n,\u2003\u2003Eqn.', '(20) \n \nwhere J\n1 \nis the Bessel function of the first kind, \n \n \n \nY\n1 \nis the Bessel function of the second kind,\n \nk\nr\nf \nand k\nr\ns \nare the radial wavenumbers for the fast and slow coupled tool-formation flexural waves, and\n \nA and B are amplitude coefficients for Bessel functions of the first and second kind respectively obtained from the continuity conditions at the borehole and tool pipe surface for the LWD propagation mode in the slow formation.', 'Note that the Y\n1 \nBessel function of Eqn.', '(20) is needed to properly account for propagation of the drill-collar flexural wave in the annulus between the rotating tool and the formation in this slow formation case.', 'In the case of a slow formation, Eqn.', '(15) can be rewritten with the following expression for the two-component data vector/matrix u\nD1\n:\n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \n \nω\n \n,\n \n \nz\n \nn\n \n \n \n)\n \n \n=\n \n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOP\n \n \n \n(\n \n \nω\n \n,\n \n \nz\n \nm\n \n \n \n)\n \n \n \n \n \n]\n \n \n=\n \n \n \n-\n \n \nρ\n \nm\n \n \n \n\u2062\n \n \nω\n \n2\n \n \n\u2062\n \n \ns\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \ncos\n \n\u2062\n \n \n \nφ\n \n\u2061\n \n(\n \n \n \nA\n \n[\n \n \n \n \n \n \nJ\n \nf\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n \n0\n \n \n \n \n \nJ\n \ns\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n \n \n \n0\n \n \n \n \n \n \nJ\n \ns\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n-\n \n \n \nJ\n \nf\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n+\n \n \nB\n \n[\n \n \n \n \n \n \nY\n \nf\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n \n0\n \n \n \n \n \nY\n \ns\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n \n \n \n0\n \n \n \n \n \n \nY\n \ns\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n-\n \n \n \nY\n \nf\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n)', '[\n \n \n \n \n \n \ncos\n \nz\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \nsin\n \n\u2062\n \nθcos\n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \nsin\n \n2\n \n \n\u2062\n \nθ\n \n \n \n \n \n]\n \n \n \n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n21\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \nwhere\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nJ\n \nf\n \n \n\u2062\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n=\n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \nm\n \n \n \n \n \n \n,\n \n \n \n \n \n \n \n \n \n \nJ\n \ns\n \n \n\u2062\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n \n=\n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \nj\n \n\u2062\n \n \nk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \nm\n \n \n \n \n \n \n,\n \n \n \n \n \n \n \n \n \n \nY\n \nf\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n=\n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \nm\n \n \n \n \n \n \n,\n \n \n \nand\n \n \n \n \n \n \n \n \n \nY\n \ns\n \n \n(\n \n \nz\n \nm\n \n \n)\n \n \n=\n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \n \ne\n \n \nj\n \n\u2062\n \n \nk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \nm\n \n \n \n \n.', 'Eqn\n \n.\n \n \n \n \n(\n \n22\n \n)', 'The array waveforms for all of the receivers can be combined into two long vectors as follows:\n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n(\n \nω\n \n)', '=\n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n(\n \n \nω\n \n,\n \n \nz\n \n1\n \n \n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \n2\n \n \n \n)\n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nM\n \n \n \n)\n \n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n23\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOF\n \n \n \n(\n \nω\n \n)\n \n \n=\n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOF\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \n1\n \n \n \n)\n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOF\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \n2\n \n \n \n)\n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOF\n \n \n \n\u2062\n \n \n(\n \n \nω\n \n,\n \n \nz\n \nM\n \n \n \n)\n \n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \nThe vectors of Eqn.', '(23) can be rewritten into a matrix form as follows:\n \n \n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)\n \n \n=\n \n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nI\n \n\u2062\n \nN\n \n \n \n(\n \nω\n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nO\n \n\u2062\n \nF\n \n \n \n(\n \nω\n \n)\n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n=\n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \n \n(\n \n \n \nA\n \n[\n \n \n \n \n \nJ\n \nf\n \n \n \n \n0\n \n \n \n \nJ\n \ns\n \n \n \n \n \n \n0\n \n \n \n \n \nJ\n \ns\n \n \n-\n \n \nJ\n \nf\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n+\n \n \nB\n \n[\n \n \n \n \n \nY\n \nf\n \n \n \n \n0\n \n \n \n \nY\n \ns\n \n \n \n \n \n \n0\n \n \n \n \n \nY\n \ns\n \n \n-\n \n \nY\n \nf\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n)\n \n \n\u2062\n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n \n \n \n \n \n \n=\n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)', '\u2062\n \n \n(\n \n \n \nAJ\n \n\u2061\n \n(\n \nω\n \n)\n \n \n+\n \n \nBY\n \n\u2061\n \n(\n \nω\n \n)\n \n \n \n)\n \n \n\u2062\n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n \n \n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n24\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \nwhere\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n=\n \n \n \n-\n \n \nρ\n \nm\n \n \n \n\u2062\n \n \nω\n \n2\n \n \n\u2062\n \n \ns\n \n\u2061\n \n(\n \nω\n \n)', '\u2062\n \ncos\n \n\u2062\n \nφ\n \n \n \n,\n \n \n \n \n \n \nEqn\n \n.', '(\n \n25\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n=\n \n \n[\n \n \n \n \n \n \ncos\n \n2\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \nsin\n \n\u2062\n \nθcos\n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \nsin\n \n2\n \n \n\u2062\n \nθ\n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \n \n \n \n \n \n \n \n \nJ\n \nf\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nJ\n \n1\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)', '\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \n \n \n \n \n \n \n \n \nJ\n \ns\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nJ\n \n1\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \n \n \n \n \n \n \n \n \nY\n \nf\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \nf\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \nf\n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n,\n \nand\n \n \n \n \n \n \n \n \n \n \n \n \nY\n \ns\n \n \n=\n \n \n \n[\n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \nY\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nY\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \ns\n \n \n\u2062\n \nr\n \n \n)', '\u2062\n \n \ne\n \n \n \njk\n \nz\n \ns\n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n.', 'The matrices of Eqns.', '(24) and (25) can be rewritten into a simplified form as follows:\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)\n \n \n=\n \n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n(\n \nω\n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nOF\n \n \n \n(\n \nω\n \n)\n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n=\n \n \n \n \n[\n \n \n \n \n \nJ\n \n\u2062\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \nv\n \n\u2062\n \n \n(\n \nθ\n \n)\n \n \n \n \n \n \nY\n \n\u2062\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \nv\n \n\u2062\n \n \n(\n \nθ\n \n)\n \n \n \n \n \n \n]', '[\n \n \n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \nA\n \n \n \n \n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \nB\n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n=\n \n \n \n \nD\n \n\u2061\n \n(\n \n \nω\n \n,\n \nθ\n \n \n)\n \n \n\u2062\n \n \nb\n \n\u2061\n \n(\n \nω\n \n)\n \n \n \n \n \n \n \n.', 'Eqn\n \n.\n \n \n \n \n(\n \n26\n \n)\n \n \n \n \n \n \n \n \n \nIn practice, the data vector/matrix u\nC1 \nof Eqn.', '(26) is usually contaminated by noise as follows: \n \nu\nD1\n(ω)=\nD\n(ω,θ)\nb\n(ω)+\nn\n(ω).', 'Eqn.', '(27) \n \nTo find a solution of the rotation angle θ in a slow formation, an LWD-DATC cost function can be constructed from the data vector/matrix u\nD1 \nof Eqn.', '(26).', 'Note that the data vector/matrix u\nD1 \nof Eqn.', '(26) is produced from the model of propagation of the pressure field associated with the fast and slow flexural waves of Eqns.', '(16)-(26).', 'The LWD-DATC cost function involves the frequency-domain waveforms across the receivers of the array and multiple frequency points as follows:\n \n \n \n \n \n \n \n \n \nθ\n \nˆ\n \n \n=\n \n \narg\n \n \n \n \nmax\n \nθ\n \n \n \n \n∑\n \n \nω\n \n \n \n∈\n \nΩ\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \nθ\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nP\n \n \nD\n \n\u2061\n \n(\n \n \nω\n \n,\n \nθ\n \n \n)', '\u2062\n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)', 'Eqn\n \n.\n \n \n \n \n(\n \n28\n \n)\n \n \n \n \n \n \n \n \n \nwhere Ω is the set of selected frequency points, \n \n \n \nP\nD(ω,θ) \nis the projection matrix onto the subspace of the signal matrix D(ω,θ) of the form P\nD(ω,θ)\n=D(ω,θ)(D\nH\n(ω,θ)D(ω,θ))\n−1\nD\nH\n(ω,θ), and \n \nD\n(ω,θ) is a rank-two matrix of the form \nD\n(ω,θ)=[\nJ\n(ω)\nv\n(θ) \nY\n(ω)\nv\n(θ)] for the slow formation.', 'Eqn.', '(29) \n \n \n \n \n \nWith this cost function, the rotation angle θ is estimated as the parameter that maximizes the total energy projected onto the signal subspace defined by the two Bessel functions J(ω) and Y(ω) along the fast and slow flexural dispersions.', 'The set of the selected frequency points Ω of the cost function is based on estimated dispersion of the fast and slow (tool/formation) flexural modes.', 'In a fast formation, the function ζ is modified to describe the coupled tool and formation flexural modes as follows: \n ζ(\nk\nr\nf\n,k\nz\nf\n,r\n)=[\nJ\n1\n(\nk\nr\nf,F\nr\n)', 'A\nF\n+Y\n1\n(\nk\nr\nf,F\nr\n)\nB\nF\n]e\njk\nz\nf,F\nz\nm', '+', '[J\n1\n(\nk\nr\nf', ',T\nr\n)\nA\nT\n+Y\n1\n(\nk\nr\nf,T\nr\n)\nB\nT\n]e\njk\ns\nf,T\nz\nm\n, \n ζ(\nk\nr\ns\n,k\nz\ns\n,r\n)=[\nJ\n1\n(\nk\nr\ns,F\nr\n)\nA\nF\n+Y\n1\n(\nk\nr\ns,F\nr\n)\nB\nF\n]e\njk\nz\nf,F\nz\nm', '+', '[J\n1\n(\nk\nr\ns,T\nr\n)\nA\nT\n+Y\n1\n(\nk\nr\ns,T\nr\n)\nB\nT\n]e\njk\ns\ns,T\nz\nm\n,\u2003\u2003Eqn.', '(30) \n where J\n1 \nis the Bessel function of the first kind, Y\n1 \nis the Bessel function of the second kind, k\nr\nf,F \nand k\nr\ns,F \nare the radial wavenumbers for the fast and slow formation flexural waves, k\nr\nf,T \nand k\nr\ns,T \nare the radial wavenumbers for the fast and slow tool flexural waves; A\nF \nand B\nF \nare the amplitude coefficients for the Bessel function of the first and second kind respectively, representing the LWD formation flexural propagation mode in the fast formation and obtained from the continuity conditions at the borehole and tool pipe interfaces; and AT and BT are similarly the amplitude coefficients for the Bessel function of the first and second kind respectively, representing the LWD tool flexural propagation mode in the fast formation and obtained from the continuity conditions at the borehole and tool pipe interfaces.', 'Note that in Eqn.', '(30) the Y\n1 \nBessel function of Eqn.', '(21) is used in a similar manner as described above with respect to Eqn.', '(20) to properly account for the propagation of the drill-collar flexural wave in the annulus between the rotating tool and the formation.', 'It also accounts for the coupling between the rotating tool and the formation.', 'In the case of a fast formation, Eqn.', '(15) can be rewritten with the following expression of the two-component data vector/matrix u\nD1\n:\n \n \n \n \n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n31\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)\n \n \n=\n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \n \n(\n \n \n \n \n \n \n \nA\n \nT\n \n \n[\n \n \n \n \n \nJ\n \nf\n \nT\n \n \n \n \n0\n \n \n \n \nJ\n \ns\n \nT\n \n \n \n \n \n \n0\n \n \n \n \n \nJ\n \ns\n \nT\n \n \n-\n \n \nJ\n \nf\n \nT\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n+\n \n \n \nB\n \nT\n \n \n[\n \n \n \n \n \nY\n \nf\n \nT\n \n \n \n \n0\n \n \n \n \nY\n \ns\n \nT\n \n \n \n \n \n \n0\n \n \n \n \n \nY\n \ns\n \nT\n \n \n-\n \n \nY\n \nf\n \nT\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n+\n \n \n \nA\n \nF\n \n \n[\n \n \n \n \n \nJ\n \nf\n \nF\n \n \n \n \n0\n \n \n \n \nJ\n \ns\n \nF\n \n \n \n \n \n \n0\n \n \n \n \n \nJ\n \ns\n \nF\n \n \n-\n \n \nJ\n \nf\n \nF\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n+\n \n \n \nB\n \nF\n \n \n[\n \n \n \n \n \nY\n \nf\n \nF\n \n \n \n \n0\n \n \n \n \nY\n \ns\n \nF\n \n \n \n \n \n \n0\n \n \n \n \n \nY\n \ns\n \nF\n \n \n-\n \n \nY\n \nf\n \nF\n \n \n \n \n \n0\n \n \n \n \n]\n \n \n \n \n \n \n)\n \n \n\u2062\n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n \n \n \n \n \n \n=\n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \n \n(\n \n \n \n \nA\n \nT\n \n \n\u2062\n \n \n \nJ\n \nT\n \n \n(\n \nω\n \n)\n \n \n \n+\n \n \n \nB\n \nT\n \n \n\u2062\n \n \n \nY\n \nT\n \n \n(\n \nω\n \n)\n \n \n \n+\n \n \n \nB\n \nF\n \n \n\u2062\n \n \n \nY\n \nF\n \n \n(\n \nω\n \n)\n \n \n \n \n)\n \n \n\u2062\n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nwhere\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n=\n \n \n \n-\n \n \nρ\n \nm\n \n \n \n\u2062\n \n \nω\n \n2\n \n \n\u2062\n \n \ns\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \ncos\n \n\u2062\n \nφ\n \n \n \n \n \n \n \nEqn\n \n.\n \n \n \n \n(\n \n32\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n=\n \n \n[\n \n \n \n \n \n \ncos\n \n2\n \n \n\u2062\n \nθ\n \n \n \n \n \n \n \nsin\n \n\u2062\n \nθcos\n \n\u2062\n \nθ\n \n \n \n \n \n \n \n \nsin\n \n2\n \n \n\u2062\n \nθ\n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \n \n \n \n \n \n \n \n \nJ\n \nf\n \nT\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nJ\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \n \n \n \n \n \n \n \n \nJ\n \ns\n \nT\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nJ\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n,\n \n \n \n \n \n \n \n \n \n \n \n \nJ\n \nf\n \nF\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nJ\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nJ\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n \n \n \n \nY\n \ns\n \nT\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nT\n \n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nY\n \nf\n \nF\n \n \n=\n \n \n[\n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \nf\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n \n,\n \nand\n \n \n \n \n \n \n \n \n \n \n \n \nY\n \ns\n \nF\n \n \n=\n \n \n \n[\n \n \n \n \n \n \n \nY\n \n1\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \n1\n \n \n \n \n \n \n \n \n \n \n \nY\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \n2\n \n \n \n \n \n \n \n \n \n⋮\n \n \n \n \n \n \n \nY\n \n1\n \n \n\u2062\n \n \n(\n \n \n \nk\n \nr\n \n \ns\n \n,\n \nF\n \n \n \n\u2062\n \nr\n \n \n)\n \n \n\u2062\n \n \ne\n \n \n \njk\n \nz\n \n \ns\n \n,\n \nF\n \n \n \n\u2062\n \n \nz\n \nM\n \n \n \n \n \n \n \n \n]\n \n \n.', 'The matrices of Eqns.', '(31) and (32) can be rewritten into a simplified form as follows:\n \n \n \n \n \n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)\n \n \n=\n \n \n \n[\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nIN\n \n \n \n(\n \nω\n \n)\n \n \n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n\u2062\n \nO\n \n\u2062\n \nF\n \n \n \n(\n \nω\n \n)\n \n \n \n \n \n]\n \n \n \n \n \n \n \n \n=\n \n \n \n \n \n[\n \n \n \n \n \n \nJ\n \nT\n \n \n\u2062\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \nv\n \n\u2062\n \n \n(\n \nθ\n \n)\n \n \n\u205f\n \n \n \n \n \n \n \nY\n \nT\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n \n \n \n \nJ\n \nF\n \n \n\u2062\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \nv\n \n\u2062\n \n \n(\n \nθ\n \n)\n \n \n \n \n \n \n \n \nY\n \nF\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nv\n \n\u2061\n \n(\n \nθ\n \n)\n \n \n \n \n \n \n]', '[\n \n \n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nA\n \nT\n \n \n \n \n \n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nB\n \nT\n \n \n \n \n \n \n \n \nα\n \n\u2062\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nA\n \nF\n \n \n \n \n \n \n \n \n \nα\n \n\u2061\n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nB\n \nF\n \n \n \n \n \n \n]\n \n \n.\n \n \n \n \n \n \n \n \n=\n \n \n \n \nD\n \n\u2061\n \n(\n \n \nω\n \n,\n \nθ\n \n \n)\n \n \n\u2062\n \n \nb\n \n\u2061\n \n(\n \nω\n \n)\n \n \n \n \n \n \n \n \n \n \nEqn\n \n.', '(\n \n33\n \n)', 'This form consists of the same expression as in the case of the slow formation (Eqn. (26)), except that the rank of the matrix D(ω,θ) increases from 2 to 4 due to the separation of the drill-collar and formation flexural modes.', 'In practice, the data vector/matrix u\nD1 \nof Eqn.', '(33) is usually contaminated by noise as follows: \n \nu\nD1\n(ω)=\nD\n(ω,θ)\nb\n(ω)+\nn\n(ω)\u2003\u2003Eqn.', '(34) \n \nTo find a solution of the rotation angle θ in a fast formation, an LWD-DATC cost function can be constructed from the data vector/matrix u\nD1 \nof Eqn.', '(33).', 'Note that the data vector/matrix u\nD1 \nof Eqn.', '(33) is produced from the model of propagation of the pressure field associated with the fast and slow flexural waves of Eqns.', '(29)-(33).', 'The LWD-DATC cost function involves the frequency-domain waveforms across all of the receivers of the array and multiple frequency points as follows:\n \n \n \n \n \n \n \n \n \nθ\n \nˆ\n \n \n=\n \n \narg\n \n \n \n \nmax\n \nθ\n \n \n \n \n∑\n \n \nω\n \n∈\n \nΩ\n \n \n \n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \ns\n \n \n(\n \nω\n \n)\n \n \n\u2062\n \n \nP\n \n \nD\n \n\u2061\n \n(\n \n \nω\n \n,\n \nθ\n \n \n)', '\u2062\n \n \n \nu\n \n \nD\n \n\u2062\n \n1\n \n \n \n(\n \nω\n \n)', 'Eqn\n \n.\n \n \n \n \n(\n \n35\n \n)\n \n \n \n \n \n \n \n \n \n \n \nwhere, again, P\nD(ω,θ) \nis the projection matrix onto the subspace of the matrix \n \nD\n(ω,θ),\nP\nD(ω,θ)\n=D\n(ω,θ)(\nD\nH\n(ω,θ)\nD\n(ω,θ))\n−1\nD\nH\n(ω,θ), and \n \nD\n(ω,θ) is a rank-four matrix given as \n \nD\n(ω,θ)=[\nJ\nT\n(ω)\nv\n(θ)\nY\nT\n(ω)\nv\n(θ)\nJ\nF\n(ω)\nv\n(θ)\nY\nF\n(ω)\nv\n(θ)]\u2003\u2003Eqn.', '(36)', 'In order to construct the LWD-DATC cost function for a slow formation or a fast formation, the frequency-domain workflow rotates the data vectors output from block \n1601\n (e.g., the two-component data vectors of Eqn.', '(15)) with a set of one or more predetermined rotation angles in block \n1603\n.', 'If the data vectors are rotated by a set of two or more predetermined rotation angles, the rotated data vectors (which are rotated by the predetermined rotation angle) that shows the largest flexural dispersion splitting are selected for output to block \n1605\n.', 'Note that the set of one or more predetermined rotation angles can be configured to cover the fast shear direction based on the fast shear directions acquired from other depths in the formation.', 'In block \n1605\n, the rotated data vectors output from block \n1603\n are used to estimate the dispersion of fast and slow (tool/formation) flexural modes arising from the D1 or D2 LWD dipole firing.', 'Such operations can employ a variety of methods known in the art for such estimation.', 'A number of methods are described in i) U.S. patent application Ser.', 'No. 15/331,946, filed on Oct. 24, 2016, entitled “Determining Shear Slowness from Dipole Source-based Measurements Acquired by a Logging-While-Drilling Acoustic Measurement Tool;” ii) Ekstrom, M. P., “Dispersion estimation from borehole acoustic arrays using a modified matrix pencil algorithm,” 29th Asilomar Conf.', 'Signals, Syst., Comput., Pacific Grove, Calif., pp. 449-453, Oct. 31, 1995; iii) Tang, X. M., Li, C., and Patterson, D., “A curve-fitting method for analyzing dispersion characteristics of guided elastic waves,” The 79th SEG Annual Meeting, Houston, Tex., 25-30 Oct. 25-30, 2009, pp.', '461-465; iv) Wang, C., “Sonic well logging methods and apparatus utilizing parametric inversion dispersive wave processing,” U.S. Pat.', 'No. 7,120,541; v) Aeron, S., Bose, S. and Valero, H.-P., “Automatic Dispersion Extraction of Multiple Time-Overlapped Acoustic Signals,” U.S. Pat.', 'No. 8,339,897; vi) Wang, P. and Bose, S., “Broadband dispersion extraction of borehole acoustic modes via sparse Bayesian learning: 5th IEEE International Workshop on Computational Advances in Multi-Sensor Adaptive Processing, Saint Martine, Dec. 15-18, 2013, pp.', '268-271; and vii) Wang, P. and Bose, S., “Apparatus for Mode Extraction Using Multiple Frequencies,” PCT Publication No. PCT/US14/049703;', 'herein incorporated by reference in their entireties.', 'The estimated dispersions for each of the modes can be represented in terms of the phase slowness, or equivalently, the axial wavenumbers, as a function of frequency, which are then used as described below.', 'In block \n1607\n, the rotated data vectors output from block \n1603\n are used to define a propagation model of the pressure field associated with the fast and slow flexural waves arising from the D1 or D2 LWD dipole firing for the appropriate fast or slow formation.', 'In one embodiment, for a slow formation, the rotated data vectors output from block \n1603\n are used to define the frequency domain waveforms u\nD1IN\n(ω) and u\nD1OF\n(ω) for the receivers of the receiver array with respect to the propagation model of Eqns.', '(15)-(26) as described above.', 'The estimated dispersion of the fast and slow (tool/formation) flexural modes as computed in block \n1605\n can be used to define the propagation model for the slow formation.', 'For example, the wavenumbers of the fast and slow (tool/formation) flexural modes as computed in block \n1605\n can be used to compute the matrix D(ω,θ) of Eqn.', '(29) via the matrices J\nf\n, J\ns\n,', 'Y\nf\n, Y\ns \nof Eqn. (25).', 'In another embodiment, for a fast formation, the rotated data vectors output from block \n1603\n are used to define the frequency domain waveforms u\nD1IN\n(ω) and u\nD1OF\n(ω) for all of the receivers of the receiver array with respect to the propagation model of Eqns.', '(29)-(32) as described above.', 'The estimated dispersion of the fast and slow (tool/formation) flexural modes as computed in block \n1605\n can be used to define the propagation model for the fast formation.', 'For example, the wavenumbers of the fast and slow (tool/formation) flexural modes as computed in block \n1605\n can be used to compute the matrix D(ω,θ) of Eqn.', '(36) via the matrices J\nf\nT\n, J\ns\nT\n, J\nf\nF\n, Y\ns\nT\n, Y\nf\nF\n, and Y\ns\nF \nof Eqn.', '(32).', 'In block \n1609\n, the LWD-DATC cost function (e.g., Eqn. (28) for the slow formation or Eqn.', '(34) for the fast formation) is constructed based on the propagation model defined in block \n1607\n.', 'The set of the selected frequency points Ω of the LWD-DATC cost function is based on estimated dispersion of the fast and slow (tool/formation) flexural modes computed in block \n1605\n.', 'In particular, the frequency points are selected to lie in a frequency band where we have sufficiently large separation between the fast and slow flexural (formation/tool) dispersions.', 'In the fast formation case, the selected frequency points can lie in the low frequency range where the formation flexural dispersions normally show large separation.', 'In the slow formation case, the selected frequency points can lie in the relatively high frequency range where the dispersion separation is larger.', 'The LWD-DATC cost function is then evaluated by computer-implemented methods to determine the angle θ where the total energy projected onto the signal subspace defined by the two Bessel functions J(w) and Y(w) along the fast and slow flexural dispersions is maximized.', 'In block \n1611\n, the angle θ obtained by the maximized cost function in block \n1609\n can be used to estimate the fast shear direction of the formation as θ degrees away from the respective D1 or D2 dipole firing direction.', 'In other words, the parameter value for the angle θ as obtained by the maximized cost function in block \n1609\n represents the fast shear direction of the formation.', 'The slow shear direction of the formation can be calculated by an offset of 90° relative to the fast shear direction of the formation as is evident from \nFIGS.', '5\nA and \n5\nB\n.', 'In block \n1613\n, the workflow evaluates a stopping criterion to determine if the stopping criterion is satisfied.', 'There are a number of possible options for the choice of stopping criterion.', 'One choice is to re-iterate the process once and see if the estimated fast shear azimuth is close enough to its estimate in the previous iteration.', 'If the two estimates are close (subject to a threshold), then the workflow ends and outputs the estimated fast shear azimuth direction in the last iteration or the average value as the final estimate of the fast shear azimuth direction.', 'If so (yes), the fast shear direction as determined in block \n1611\n is stored and output as the fast shear azimuth direction of the slow formation.', 'If not (no), the data vectors output from block \n1601\n (e.g., the two-component data vectors of Eqn.', '(15)) can be rotated at one or more predetermined rotation angles in block \n1615\n in a manner similar to block \n1603\n and the operations of blocks \n1605\n to \n1613\n can be repeated for one or more additional iterations until the stopping criterion is satisfied.', 'To evaluate the effectiveness of the LWD-DATC cost function, first consider a slow formation, which is the same case as shown in \nFIGS.', '15\nA, \n15\nB and \n15\nC\n.', 'To construct the LWD-DATC cost function for the slow formation, the wavenumbers of the fast and slow collar-formation flexural modes are used as inputs to compute the matrix D(ω,θ) of Eqn.', '(29) via the matrices J\nf\n, J\ns\n,', 'Y\nf\n, Y\ns \nof Eqn. (25).', 'To validate the proposed frequency-domain workflow, true model wavenumbers can be used to construct the LWD-DATC cost function.', 'In this case, the inline and crossline array waveforms arising from only the D1 firing are used.', 'Specifically, the D1 firing direction is 45° away from the fast shear direction.', 'FIG.', '18\nA\n shows the model slowness dispersion of the fast and slow coupled collar-formation flexural modes.', 'The solid dots between 3.5 and 6 kHz represents a bandlimited dispersion used in the frequency-domain workflow. \nFIG.', '18\nB\n shows the one-dimensional LWD-DATC cost function, which is constructed by using the inline and crossline waveforms between 3.5 and 6 kHz from a dipole firing which is 45° away from the fast shear direction.', 'The maximum of the LWD-DATC cost function corresponds to the fast shear direction, whereas the minimum of the LWD-DATC cost function represents the slow shear direction.', 'The difference between the maximum and minimum reflects the calculated difference between the fast and slow shear polarization directions.', 'Note that the true model slowness dispersion of the fast and slow coupled collar-formation flexural modes between 3.5 and 6 kHz is used to construct the LWD-DATC cost function, which computes the projected total signal energy between 3.5 and 6 kHz.', 'It is further seen in \nFIG.', '18\nB\n that the maximum of the LWD-DATC cost function provides the fast shear direction at 46.68°, whereas the minimum yields the slow shear direction.', 'The difference between the maximum and minimum reflects the difference between the fast and slow shear polarization directions.', 'In practice, the measured dispersion for the fast and slow flexural waves may not be known in advance.', 'To address this issue, the inline and crossline array waveforms can be rotated by a set of pre-determined angles in block \n1603\n.', 'For instance, the inline and crossline array waveforms can be rotated by a set of three pre-determined angles [20°, 40°, 60°], and the pre-rotated waveforms showing the largest flexural dispersion splitting can be selected.', 'Then, in block \n1609\n, estimated flexural dispersions from the pre-rotated waveforms (block \n1605\n) are used to construct the LWD-DATC cost function (block \n1607\n).', 'In an example shown in \nFIGS.', '19\nA and \n19\nB\n, two slowness dispersions of the fast and slow coupled collar-formation flexural modes are selected from the pre-rotated waveforms with a pre-determined angle of 60° to construct the LWD-DATC cost function.', 'The selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes are used to construct and evaluate the LWD-DATC cost function shown in \nFIG.', '19\nB\n.', 'Note that the maximum of the LWD-DATC cost function is shifted to the left to 42.5° and this effect may be attributed to the pre-rotation.', 'One may mitigate this effect by using multiple pre-determined angles with a finer step size.', 'Consider another case with a D2 firing direction that is 67° away from the fast-shear direction in a slow formation.', 'Again, the inline and crossline array waveforms can be rotated by a set of pre-determined angles in block \n1603\n.', 'For instance, the inline and crossline array waveforms can be rotated by a set of three pre-determined angles [20°, 40°, 60°], and the pre-rotated waveforms showing the largest flexural dispersion splitting can be selected.', 'Then, in block \n1609\n, estimated flexural dispersions from the pre-rotated waveforms (block \n1605\n) are used to construct the LWD-DATC cost function (block \n1607\n).', 'In an example shown in \nFIGS. \n20\nA, \n20\nB and \n20\nC\n, two slowness dispersions of the fast and slow coupled collar-formation flexural modes are selected from the pre-rotated waveforms with a pre-determined angle of 60° to construct the LWD-DATC cost function.', 'The selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes are used to construct and evaluate the LWD-DATC cost function shown in \nFIG.', '20\nB\n, which attains its maximum at 67.18°.', 'The rotated inline and crossline waveforms are shown in \nFIG.', '20\nC\n.', 'Note that, the crossline energy is not minimized to zero as the LWD-DATC cost function does not minimize the crossline energy directly.', 'Nevertheless, the crossline energy is relatively small when it is compared with the inline waveform energy.', 'Finally, consider the frequency-domain workflow in a fast formation with the physical parameters given in Table 1 where a single dipole D2 firing direction is 85° from the fast shear direction.', 'Again, the inline and crossline array waveforms can be rotated by a set of pre-determined angles in block \n1603\n.', 'For instance, the inline and crossline array waveforms can be rotated by a set of three pre-determined angles [0°, 20°, 40°, 60°], and the pre-rotated waveforms showing the largest flexural dispersion splitting can be selected.', 'Then, in block \n1609\n, estimated flexural dispersions from the pre-rotated waveforms (block \n1605\n) are used to construct the LWD-DATC cost function (block \n1607\n).', 'In an example shown in \nFIGS.', '21\nA, \n21\nB and \n21\nC\n, by applying the multiple pre-rotation angles in block \n1603\n, it is found that the raw inline and crossline array waveforms (rotated by 0°) yield the best flexural dispersion splitting, especially for the formation flexural dispersion at low frequencies.', 'Then, in block \n1609\n, the tool fast and slow flexural dispersion mode estimates between 3.5 and 6 kHz (the upper branch of \nFIG.', '21\nA\n shows the tool slow flexural mode and the tool fast flexural mode with dots labelled “slow” and “fast”, respectively) as well as the formation fast and slow flexural dispersion mode estimates between 3.5 and 6 kHz (the lower branch of \nFIG.', '21\nA\n shows the formation slow flexural mode and the formation fast flexural mode with dots labelled “slow” and “fast”, respectively) are extracted from the raw inline and crossline array waveforms and used to compute the LWD-DATC cost function shown in \nFIG.', '20\nB\n.', 'The estimated rotation angle is 84.61°.', 'Note that for the assumed fast formation, the difference between the maximum and minimum of the LWD-DATC cost function is significantly smaller than that of the slow formation previously considered.', 'In addition, \nFIG.', '21\nC\n displays the rotated inline and crossline array waveforms, where the inline array waveforms clearly exhibit significantly larger amplitudes while the crossline array waveforms are significantly reduced.', 'In one aspect, some of the methods and processes described above for the time-domain and/or the frequency-domain workflows are performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any particular device type or system.', 'The processor may include a computer system which can be part of the Logging and Control System \n151\n of \nFIG. \n6\n.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, or general purpose computer) for executing any of the methods and processes described above.', 'The computer system may further include a memory such as a semiconductor memory device (e.g., a RAM, ROM, PROM, EEPROM, or Flash-Programmable RAM), a magnetic memory device (e.g., a diskette or fixed disk), an optical memory device (e.g., a CD-ROM), a PC card (e.g., PCMCIA card), or other memory device.', 'Some of the methods and processes described above, can be implemented as computer program logic for use with the computer processor.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Alternatively or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.\n \nFIG.', '22\n shows an example computing system \n300\n that can be used to implement the methods and processes described above for the time-domain and/or the frequency-domain workflows or parts thereof.', 'The computing system \n300\n can be an individual computer system \n301\nA or an arrangement of distributed computer systems.', 'The computer system \n301\nA includes one or more analysis modules \n303\n (a program of computer-executable instructions and associated data) that can be configured to perform various tasks according to some embodiments, such as the tasks described above.', 'To perform these various tasks, an analysis module \n303\n executes on one or more processors \n305\n, which is (or are) connected to one or more storage media \n307\n.', 'The processor(s) \n305\n is (or are) also connected to a network interface \n309\n to allow the computer system \n301\nA to communicate over a data network \n311\n with one or more additional computer systems and/or computing systems, such as \n301\nB, \n301\nC, and/or \n301\nD. Note that computer systems \n301\nB, \n301\nC and/or \n301\nD may or may not share the same architecture as computer system \n301\nA, and may be located in different physical locations.', 'The processor \n305\n can include at least a microprocessor, microcontroller, processor module or subsystem, programmable integrated circuit, programmable gate array, digital signal processor (DSP), or another control or computing device.', 'The storage media \n307\n can be implemented as one or more non-transitory computer-readable or machine-readable storage media.', 'Note that while in the embodiment of \nFIG.', '22\n, the storage media \n307\n is depicted as within computer system \n301\nA, in some embodiments, storage media \n307\n may be distributed within and/or across multiple internal and/or external enclosures of computing system \n301\nA and/or additional computing systems.', 'Storage media \n307\n may include one or more different forms of memory including semiconductor memory devices such as dynamic or static random access memories (DRAMs or SRAMs), erasable and programmable read-only memories (EPROMs), electrically erasable and programmable read-only memories (EEPROMs) and flash memories; magnetic disks such as fixed, floppy and removable disks; other magnetic media including tape; optical media such as compact disks (CDs) or digital video disks (DVDs); or other types of storage devices.', 'Note that the computer-executable instructions and associated data of the analysis module(s) \n303\n can be provided on one computer-readable or machine-readable storage medium of the storage media \n307\n, or alternatively, can be provided on multiple computer-readable or machine-readable storage media distributed in a large system having possibly plural nodes.', 'Such computer-readable or machine-readable storage medium or media is (are) considered to be part of an article (or article of manufacture).', 'An article or article of manufacture can refer to any manufactured single component or multiple components.', 'The storage medium or media can be located either in the machine running the machine-readable instructions, or located at a remote site from which machine-readable instructions can be downloaded over a network for execution.', 'It should be appreciated that computing system \n300\n is only one example of a computing system, and that computing system \n300\n may have more or fewer components than shown, may combine additional components not depicted in the embodiment of \nFIG.', '22\n, and/or computing system \n300\n may have a different configuration or arrangement of the components depicted in \nFIG. \n22\n.', 'The various components shown in \nFIG.', '22\n may be implemented in hardware, software, or a combination of both hardware and software, including one or more signal processing and/or application specific integrated circuits.', 'There have been described and illustrated herein several embodiments of methods and systems for determining fast and slow shear directions in an anisotropic formation using a logging while drilling tool.', 'While particular embodiments of the invention have been described, those skilled in the art will readily appreciate that many modifications are possible in the examples without materially departing from this subject disclosure.', 'For example, the workflows described herein can be adapted to account for both rotation and sliding motion of the logging while drilling tool during excitation of the time-varying pressure field in the formation surround the borehole and the acquisition of waveforms resulting therefrom.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.']

['1.', 'A method of determining properties of an anisotropic formation surrounding a borehole, comprising:\nproviding a logging-while-drilling tool that is moveable through the borehole, the logging-while drilling tool having at least one dipole acoustic source spaced from an array of receivers, wherein the at least one dipole acoustic source produces a predefined excitation of an oriented dipole transmitter wavefield in the borehole at a particular azimuthal direction;\nduring movement of the logging-while-drilling tool, operating the at least one dipole acoustic source to excite a time-varying pressure field in the anisotropic formation surrounding the borehole;\nduring the movement of the logging-while-drilling tool, using the array of receivers to measure waveforms arising from the time-varying pressure field in the anisotropic formation surrounding the borehole; and\nprocessing the waveforms measured by the array of receivers to determine a parameter value that represents shear directionality of the anisotropic formation surrounding the borehole, wherein processing involves processing waveforms measured by the array of receivers in the frequency domain for the predefined excitation to evaluate a cost function which is based on a propagation model of dispersion extracted from the waveforms, and\nwherein the cost function is evaluated to maximize energy projected onto a signal subspace defined by two Bessel functions J(ω) and Y(ω) along fast and slow flexural dispersions of the waveforms.', '2.', 'A method according to claim 1, wherein the movement of the logging-while-drilling tool involves at least one of rotation and sliding motion of the logging-while-drilling tool.', '3.', 'A method according to claim 1, wherein the parameter value represents a fast shear direction of the anisotropic formation.', '4.', 'A method according to claim 1, wherein the parameter value represents a slow shear direction of the anisotropic formation.', '5.', 'A method according to claim 1, wherein the parameter that represents shear directionality of the anisotropic formation is used to generate synthetically-rotated waveforms, and the synthetically-rotated waveforms are used to estimate dipole shear slowness of the formation.', '6.', 'A method according to claim 1, wherein:\nthe at least one dipole acoustic source produces first and second excitations of an oriented dipole transmitter wavefield in the borehole at different azimuthal directions; and\nthe processing involves processing waveforms measured by the array of receivers in the time domain for the first and second excitations to evaluate the cost function involving rotation of four-component data vectors.', '7.', 'A method according to claim 6, wherein:\nthe four-component data vectors are defined by combining a data vector arising from the first excitation and a rotated data vector arising from the second excitation.', '8.', 'A method according to claim 7, wherein:\nthe data vector arising from the first excitation is defined by inline and crossline waveforms received by the array of receivers and corresponding to the first excitation; and\nthe rotated data vector arising from the second excitation is defined by inline and crossline waveforms received by the array of receivers and corresponding to the second excitation.', '9.', 'A method according to claim 6, wherein:\nthe cost function is evaluated to minimize a sum of off-diagonal elements over a number of time samples and receivers of the receiver array.', '10.', 'A method according to claim 6, wherein:\nthe cost function involves total crossline energy of a data matrix of rotated four-component data vectors over a number of time samples and receivers of the receiver array.', '11.', 'A method according to claim 6, wherein:\nthe cost function is constrained by lower and upper bounds for a difference in azimuthal direction between the first and second excitations.', '12.', 'A method according to claim 11, wherein:\nthe lower and upper bounds for the difference in azimuthal direction are determined from output of a sensor of the logging-while-drilling tool that measures azimuthal direction of the first and second excitations.', '13.', 'A method according to claim 1, wherein:\nthe cost function involves frequency-domain waveforms for a plurality of receivers and multiple frequency points.', '14.', 'A method according to claim 1, wherein:\nthe Bessel function J(ω) is configured to account for flexural mode of the formation; and\nthe Bessel function Y(ω) is configured to account for propagation of a drill-collar flexural wave in an annulus between the rotating logging while drilling tool and the formation as well as coupling between the moving logging-while drilling tool and the formation.', '15.', 'A method according to claim 1, wherein:\nthe cost function involves a set of frequency points that are selected based on estimated dispersion of fast and slow flexural modes.', '16.', 'A method according to claim 13, wherein:\nthe propagation model is determined by rotating two-component data vectors over a set of one or more predetermined rotation angles.', '17.', 'A method according to claim 16, wherein:\nthe two-component data vectors are defined by inline and crossline waveforms received by the array of receivers that correspond to the predefined excitation.', '18.', 'A method according to claim 16, wherein:\nthe propagation model is determined by rotating two-component data vectors over a plurality of predetermined rotation angles, and selecting rotated two-component data vectors that show largest flexural dispersion splitting.\n\n\n\n\n\n\n19.', 'A method according to claim 18, wherein:\nthe set of one or more predetermined rotation angles is configured to cover fast shear direction of the formation based on fast shear directions acquired from other depths in the formation.', '20.', 'A method according to claim 16, wherein:\nthe rotated two-component data vectors are used to estimate dispersion of fast and slow flexural modes arising from the predefined excitation of the sonic dipole transmitter; and\nthe estimated dispersion of fast and slow flexural modes is used to define the propagation model.']

['FIG.', '1 is a schematic diagram of a transversely isotropic formation with a vertical axis of symmetry (TIV).; FIG.', '2 is a schematic diagram of a transversely isotropic formation with a horizontal axis of symmetry (TIH).; FIG.', '3 is a schematic diagram illustrating a drill-collar mode (dashed curve labeled “blue”) that propagates in a Logging-While-Drilling (LWD) acoustic measurement tool and that interferes with a formation mode (dashed curve labeled “green”).;', 'FIGS.', '4A and 4B are schematic diagrams illustrating cross-dipole orthogonal firing of a wireline acoustic measurement tool.;', 'FIGS.', '5A and 5B are schematic diagrams illustrating non-orthogonal dipole firings of an LWD acoustic measurement tool.; FIG.', '6 is a schematic diagram of a wellsite system that can be used in practicing the embodiments of the subject disclosure.', '; FIG. 7 is a schematic diagram of a LWD acoustic measurement tool that can be used in practicing the embodiments of the subject disclosure.', '; FIG. 8 is a flowchart illustrating a time-domain workflow according to an embodiment of the subject disclosure.;', 'FIGS.', '9A and 9B illustrate synthetic time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, of a dipole transmitter in the horizontal section of a fast TIV formation.', '; FIG.', '9C illustrates the slowness dispersions of the synthetic time-domain waveforms of FIGS.', '9A and 9B in the horizontal section of a fast TIV formation.', '; FIG.', '10 illustrates a two-dimensional cost function of the four-component non-orthogonal LWD waveform rotation for the example of FIGS.', '9A, 9B and 9C.; FIGS.', '11A and 11B illustrate rotated time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, for the example of FIGS.', '9A, 9B and 9C.; FIG.', '11C illustrates the slowness dispersions of the rotated time-domain waveforms of FIGS.', '11A and 11B', 'in the horizontal section of the fast TIV formation.', '; FIGS.', '12A and 12B illustrate synthetic time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, from a dipole source in the horizontal section of a fast TIV formation.', 'The D1 and D2 firings are, respectively, 35 and 67 degrees away from the slow shear azimuth.', '; FIG.', '12C illustrates the slowness dispersions of the time-domain waveforms of FIGS.', '12A and 12B in the horizontal section of the fast TIV formation.', '; FIG. 13 illustrates a two-dimensional cost function of the four-component non-orthogonal LWD waveform rotation for the example of FIGS.', '12A, 12B and 12C.; FIGS.', '14A and 14B illustrate rotated time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, for the example of FIGS.', '12A, 12B and 12C.; FIG.', '14C illustrates the slowness dispersions of the rotated time-domain waveforms of FIGS.', '14A and 14B in the horizontal section of the fast TIV formation.', '; FIGS.', '15A and 15B illustrate rotated time-domain waveforms arising from non-orthogonal D1 and D2 firings, respectively, from a dipole source in the horizontal section of a slow TIV formation.', '; FIG.', '15C illustrates the slowness dispersions of the rotated time-domain waveforms of FIGS.', '15A and 15B in the horizontal section of the slow TIV formation.', '; FIG.', '16 is a flowchart illustrating a frequency-domain workflow according to an embodiment of the subject disclosure.', '; FIG.', '17 is a schematic diagram illustrating shear wave splitting arising from a dipole transmitter in anisotropic formations and principal polarization directions.; FIG.', '18A illustrates an exemplary model slowness dispersion of the fast and slow coupled collar-formation flexural modes arising from a dipole firing which is 45° away from the fast shear direction in a slow formation.', 'The solid dots between 3.5 and 6 kHz represents a bandlimited dispersion used in the frequency-domain workflow.;', 'FIG.', '18B shows an exemplary one-dimensional LWD-DATC cost function, which is constructed using raw inline and crossline waveforms between 3.5 and 6 kHz.; FIG.', '19A shows two exemplary slowness dispersions of the fast and slow coupled collar-formation flexural modes arising from a dipole firing which is 45° away from the fast shear direction in a slow formation (same as FIG.', '18A), where the slowness dispersions are extracted from pre-rotated inline and crossline waveforms with a pre-determined angle of 60°.; FIG.', '19B shows an exemplary one-dimensional LWD-DATC cost function constructed from selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes of FIG.', '19A.; FIG.', '20A shows two exemplary slowness dispersions of the fast and slow coupled collar-formation flexural modes arising from a dipole firing that is 67° away from the fast shear direction (different from FIGS.', '18A and 19A) in a slow formation, where the slowness dispersions are extracted from pre-rotated inline and crossline waveforms with a pre-determined angle of 60°.; FIG.', '20B shows an exemplary one-dimensional LWD-DATC cost function constructed from selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes of FIG.', '20A.; FIG.', '20C shows rotated inline and crossline waveforms for the example of FIG.', '20A when the inline receivers are parallel to the fast shear direction of the slow formation.', '; FIG.', '21A shows two exemplary slowness dispersions of the fast and slow coupled collar-formation flexural modes arising from a dipole firing that is 85° away from the fast shear direction in a fast formation, where the slowness dispersions are extracted from raw (non-rotated) inline and crossline waveforms; FIG.', '21B shows an exemplary one-dimensional LWD-DATC cost function constructed from selected slowness dispersions (denoted as solid dots) for the fast and slow flexural modes of FIG.', '21A.; FIG.', '21C shows rotated inline and crossline waveforms for the example of FIG.', '21A when the inline receivers are parallel to the fast shear direction of the fast formation.', '; FIG.', '22 shows an example computing system that can be used to implement the time-domain and frequency domain workflows as described herein.; FIG.', '6 illustrates a wellsite system in which the workflows of the present disclosure can be employed.', 'The wellsite can be onshore or offshore.', 'In this exemplary system, a borehole 11 is formed in subsurface formations by rotary drilling in a manner that is well known.', 'Embodiments of the present disclosure can also use directional drilling, as will be described hereinafter.; FIG.', '7 schematically illustrates selected components of the acoustic measurement LWD module 120 of FIG.', '6 according to embodiments of the subject disclosure.', 'A pipe portion 203 defines a mud channel 205.', 'Distributed on the pipe portion 203 is a number of acoustic transmitters including a pair of dipole transmitters 201 that transmit directional D1 and D2 dipole firings.', 'An array of receivers 207 and receiver electronics 211 are distributed on the pipe portion 203.', 'The array of receivers receive the four-component waveforms of the acoustic energy that results from the directional D1 and D2 dipole firings as described herein.', 'A surface-located processing facility 151 (FIG. 6) controls the D1 and D2 firings of the dipole transmitters 201 and the receiver electronics 211.', 'The processing facility 151 can be located in one or more locations at the wellsite.', 'According to some embodiments, the processing facility 151 can process and interpret the data from the acoustic measurement LWD module 120 at one or more locations remote from the wellsite.', 'The processing facility 151 may include one or more central processing units, storage systems, communications and input/output modules, a user display, and a user input system.;', 'FIGS.', '9A and 9B show the synthetic received time-domain array waveforms generated from the dipole transmitter in the horizontal section of the fast TIV formation.', 'The D1 and D2 firings are, respectively, 15 and 85 degrees away from the slow shear azimuth.', 'In this case, the D1 inline array waveforms are mostly dominated by the propagation from the slow shear direction, while the D2 inline array waveforms are mostly dominated by the propagation from the fast shear direction.', 'FIG.', '9C shows the slowness dispersions generated from the dipole transmitter in the horizontal section of the fast TIV formation.', 'The slowness dispersions represent the dipole flexural dispersion extracted by the matrix pencil method, referred to as the TKO algorithm and described in M. P. Ekstrom, “Dispersion estimation from borehole acoustic arrays using a modified matrix pencil algorithm,”', 'Proc. 29th Asilomar Conf.', 'Signals, Syst., Comput., vol.', '2, Pacific Grove, Calif., November 1995, pp. 449-453. FIG.', '9C shows that two flexural modes are present in the fast TIV formation.', 'The upper branch (above 200 us/ft) is the dominant drill-collar flexural dispersion, while the lower branch is the formation flexural dispersion.', 'The low frequency asymptotes of the formation flexural dispersions (D1 shown with dots labeled with “∘” and D2 shown with dots labeled with “+”) approach to the fast and slow shear slownesses in Table 1.', 'Specifically, the formation flexural dispersion of D1 is similar to the slow flexural dispersion as D1 is close to the slow shear azimuth.', '; FIG.', '10 shows a two-dimensional cost function of the four-component non-orthogonal LWD waveform rotation in the (θ1=θ, θ2=θ+ϕ) plane (Block 815 of FIG.', '8) for the synthetic example of FIGS.', '9A and 9B. The two dashed lines are constraints for the upper and lower limit of the angle difference between the D1 and D2 firing directions.', 'Such constraints can be derived from the tolerance of D1 and D2 firing directions as measured during rotation of the LWD acoustic measurement tool, for example by a magnometer.', 'It is easy to observe that the global minima are located at (14.2°, 84.9°) and (104.2°, 174.9°) for [θ, θ+ϕ)].', 'Note that there is a 90° ambiguity in the [θ, θ+ϕ)] plane as one can rotate D1 to the fast shear direction and D2 to the slow shear direction or vice versa.', 'Since the workflow values the cost function to find the minimization of the total crossline energy, the coordinates of the global minima give the estimated rotation angles.', 'From FIG.', '10, the workflow searches for the minima within a bounded region (in between the two dashed lines) and the local minima are seen at (θ1=14.2°, θ2=84.9°) and (θ1=104.2°, θ2=174.9°), where the former one gives the slow shear polarization direction (i.e., 14.2° away from the D1 firing or 84.9° away from the D2 firing) and the latter one yields the fast shear direction due to a 90° ambiguity.', 'Nevertheless, the 90° ambiguity can be removed by rotating the four-component waveforms and identifying which rotated waveforms correspond to the fast and slow flexural waveforms as described in C. Esmersoy, K. Koster, M. Williams, A. Boyd and M. Kane, “Dipole shear anisotropy logging”, 64th Ann.', 'Internat.', 'Mtg., Soc.', 'Expl.', 'Geophys., Expanded Abstracts, 1139-1142, 1994.; FIGS.', '11A and 11B show the rotated inline and crossline array waveforms for the D1 and D2 dipole firings of FIGS.', '9A and 9B. Particularly, the D1 firing is rotated to the slow shear direction while D2 is rotated towards the fast shear direction using the estimated rotation angles from FIG.', '10.', 'Note that the crossline energy of the rotated waveforms is significantly minimized and the inline waveform energy is enhanced.', 'The modified matrix pencil algorithm (TKO method) can be used to extract the dispersion curves from the rotated inline array waveforms of D1 and D2.', 'FIG.', '11C shows the corresponding slowness dispersions.', 'Note that formation flexural dispersion (dots labeled with “∘”) of the rotated D1 captures the slow flexural wave, while the formation flexural dispersion (dots labeled with “+”) of the rotated D2 converges to the fast flexural shear around 110 us/ft.; FIGS.', '12A and 12B show synthetic time-domain array waveforms arising from the D1 and D2 firings of the dipole transmitter in the horizontal section of a fast Try formation.', 'The D1 and D2 firings are, respectively, 35° and 67° away from the slow shear azimuth.', 'In this case, the D1 and D2 inline array waveforms contain a mixture of both the fast and slow flexural waves.', 'Note that the inline and crossline array waveforms for the D1 and D2 dipole firings are closer to an azimuth direction in between the fast and slow shear direction.', 'Specifically, the the D1 and D2 dipole firings are 35° and 67° away from the slow shear direction, respectively.', 'Compared with the case of FIGS.', '9A and 9B, more waveform energy is split into the crossline channel, as both dipole firings move away from either the fast or slow shear directions.', 'FIG.', '12C shows the corresponding slowness dispersions.', 'In FIG.', '12C, one can no longer see the formation flexural splitting at low frequencies from the inline receivers.; FIG.', '13 shows the two-dimensional cost function (Block 815 of FIG.', '8) for the synthetic example of FIGS.', '12A and 12B. The two dashed lines represent the constraints for the upper and lower limit of the angle difference between the D1 and D2 firing directions.', 'The estimated rotation angles are (θ1=34.4°, θ2=66.7°) within the two dashed lines (the constraints).', '; FIGS.', '14A and 14B show the rotated inline and crossline array waveforms for the D1 and D2 dipole firings of FIGS.', '12A and 12B. Note that the crossline energy of the rotated array waveforms is significantly minimized and the inline array waveforms display the fast and slow flexural modes.', 'FIG.', '14C shows the corresponding slowness dispersions.', 'Note that the TKO results on the rotated inline array waveforms recover the formation flexural dispersions splitting at frequencies below 4 kHz.; FIGS.', '15A and 15B shows the rotated synthesized inline and crossline array waveforms for D1 and D2 dipole firings in the horizontal section of a slow TIV formation.', 'FIG.', '15C shows the corresponding slowness dispersions.', 'The TKO results in FIG.', '15C show the coupled collar-flexural dispersions corresponding to the inline waveforms from the rotated D1 and D2.', 'The flexural splitting at high frequencies is clearly observed.', 'In this case, the fast and slow shear slownesses can be inverted from the fast and slow flexural dispersions using a model-based workflow as described in U.S. patent application Ser.', 'No. 15/331,946, filed on Oct. 24, 2016, entitled “Determining Shear Slowness from Dipole Source-based Measurements Acquired by a Logging-While-Drilling Acoustic Measurement Tool.”', '; FIG.', '18A shows the model slowness dispersion of the fast and slow coupled collar-formation flexural modes.', 'The solid dots between 3.5 and 6 kHz represents a bandlimited dispersion used in the frequency-domain workflow.', 'FIG.', '18B shows the one-dimensional LWD-DATC cost function, which is constructed by using the inline and crossline waveforms between 3.5 and 6 kHz from a dipole firing which is 45° away from the fast shear direction.', 'The maximum of the LWD-DATC cost function corresponds to the fast shear direction, whereas the minimum of the LWD-DATC cost function represents the slow shear direction.', 'The difference between the maximum and minimum reflects the calculated difference between the fast and slow shear polarization directions.', 'Note that the true model slowness dispersion of the fast and slow coupled collar-formation flexural modes between 3.5 and 6 kHz is used to construct the LWD-DATC cost function, which computes the projected total signal energy between 3.5 and 6 kHz.', 'It is further seen in FIG.', '18B that the maximum of the LWD-DATC cost function provides the fast shear direction at 46.68°, whereas the minimum yields the slow shear direction.', 'The difference between the maximum and minimum reflects the difference between the fast and slow shear polarization directions.; FIG.', '22 shows an example computing system 300 that can be used to implement the methods and processes described above for the time-domain and/or the frequency-domain workflows or parts thereof.', 'The computing system 300 can be an individual computer system 301A or an arrangement of distributed computer systems.', 'The computer system 301A includes one or more analysis modules 303 (a program of computer-executable instructions and associated data) that can be configured to perform various tasks according to some embodiments, such as the tasks described above.', 'To perform these various tasks, an analysis module 303 executes on one or more processors 305, which is (or are) connected to one or more storage media 307.', 'The processor(s) 305 is (or are) also connected to a network interface 309 to allow the computer system 301A to communicate over a data network 311 with one or more additional computer systems and/or computing systems, such as 301B, 301C, and/or 301D. Note that computer systems 301B, 301C and/or 301D may or may not share the same architecture as computer system 301A, and may be located in different physical locations.']

US11913331

Systems and methods for recovering and protecting sidewall core samples in unconsolidated formations

Aug 25, 2022

Mark Milkovisch, Amol Bhome, Joseph Casassa, Anish Kumar, Daniel De La Garza

Schlumberger Technology Corporation

PCT International Search Report and Written Opinion; Application No. PCT/US2023/031114; dated Dec. 6, 2023; 10 pages.

4518051; May 21, 1985; Sollie; 5445228; August 29, 1995; Rathmell; 20030078610; April 24, 2003; Yedlowski; 20080066534; March 20, 2008; Reid; 20080078582; April 3, 2008; Phan et al.; 20090133932; May 28, 2009; Church; 20130066605; March 14, 2013; Li; 20130081879; April 4, 2013; Ward; 20140208826; July 31, 2014; Larter et al.; 20150354352; December 10, 2015; Ezzat; 20160053564; February 25, 2016; Haley et al.; 20190234204; August 1, 2019; Moronkeji; 20210246731; August 12, 2021; West et al.; 20210389294; December 16, 2021; Krueger

2020096874; May 2020; WO

['Systems and methods presented herein include sidewall coring tools used to return core samples of rock from a sidewall of a wellbore as part of a data collection exercise for exploration and production of hydrocarbons.', 'In particular, the systems and methods presented herein perform sidewall coring of a subterranean formation using a combination of rotary and percussive coring.', 'More specifically, the systems and methods presented herein rotate a coring cylinder of a sidewall coring tool back and forth less than a full rotation while pushing the coring cylinder of the sidewall coring tool against a bore wall of a wellbore, and push the coring cylinder of the sidewall coring tool into the subterranean formation to enable extraction of a core sample of the subterranean formation.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThe present disclosure relates generally to systems and methods for performing sidewall coring within a wellbore.', 'More specifically, the present disclosure relates to using muleshoes or other coring cylinders (e.g., cylinders with cutting knife edge(s)) actuated by actuators to perform sidewall coring within a wellbore extending through an unconsolidated (or poorly consolidated or poorly cemented) formation.', 'This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present techniques, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as an admission of any kind.', 'The oil and gas industry includes a number of sub-industries, such as exploration, drilling, logging, extraction, transportation, refinement, retail, and so forth.', 'During exploration and drilling, wellbores may be drilled into the ground for reasons that may include discovery, observation, and/or extraction of resources.', 'These resources may include oil, gas, water, or any other combination of elements within the ground.', 'Wellbores or boreholes may be drilled to, for example, locate and produce hydrocarbons.', 'During a well development operation, it may be desirable to evaluate and/or measure properties of encountered formations, formation fluids and/or formation gasses.', 'Some formation evaluations may include extracting a core sample (e.g., a rock sample) from the sidewall of a wellbore.', 'Core samples may be extracted using a coring tool coupled to a downhole tool that is lowered into the wellbore and positioned adjacent a formation.', 'A hollow coring shaft or bit of the coring tool may be extended from the downhole tool and urged against the formation to penetrate the formation.', 'A formation or core sample fills the hollow portion or cavity of the coring shaft and the coring shaft is removed from the formation retaining the sample within the cavity.', 'The sample obtained using the hollow coring bit (or bullet) is generally referred to as a “core sample” or “core plug.”', 'Once the core sample has been transported to the surface, it may be analyzed to assess, among other things, the reservoir storage capacity (e.g., porosity) and the flow potential (e.g., permeability) of the material that makes up the formation; the chemical and mineral composition of the fluids and mineral composition of the rock, including deposits contained in the pores of the formation; and the irreducible water content of the formation material.', 'The information obtained from analysis of a sample is used to design and implement well completion and production facilities.', 'SUMMARY\n \nA summary of certain embodiments described herein is set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'The systems and methods presented herein include a method that includes deploying a sidewall coring tool into a wellbore extending through a subterranean (e.g., including offshore) formation.', 'The method also includes rotating a coring cylinder of the sidewall coring tool back and forth less than a full rotation while pushing the coring cylinder of the sidewall coring tool against a bore wall of the wellbore.', 'The method further includes pushing the coring cylinder of the sidewall coring tool into the subterranean formation to enable extraction of a core sample of the subterranean formation.', 'In addition, the method includes retracting the coring cylinder to retrieve the core sample of the subterranean formation.', 'The systems and methods presented herein also include a sidewall coring tool includes a coring cylinder and one or more actuators.', 'The one or more actuators are configured to rotate the coring cylinder back and forth less than a full rotation while pushing the coring cylinder against a bore wall of a wellbore.', 'The one or more actuators are also configured to push the coring cylinder into the subterranean formation to enable extraction of a core sample of a subterranean (e.g., including offshore) formation.', 'The systems and methods presented herein further include a coring system includes a sidewall coring tool having a coring cylinder and one or more actuators configured to perform sidewall coring of a subterranean (e.g., including offshore) formation using a combination of rotary and percussive coring.', 'The coring system also includes a surface unit configured to send control signals to the sidewall coring tool to control the sidewall coring of the subterranean formation.', 'Various refinements of the features noted above may be undertaken in relation to various aspects of the present disclosure.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'The brief summary presented above is intended to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein.\n \nFIG.', '1\n is a schematic view of an embodiment of a coring system, according to one or more embodiments of the present disclosure;\n \nFIG.', '2\n is a schematic diagram of a surface unit of the coring system of \nFIG.', '1\n, according to one or more embodiments of the present disclosure;\n \nFIG.', '3\n illustrates a coring actuator of a sidewall coring tool that includes a hydraulic piston, according to one or more embodiments of the present disclosure;\n \nFIG.', '4\n illustrates a coring actuator of a sidewall coring tool that includes a set of opposing hydraulic pistons, according to one or more embodiments of the present disclosure;\n \nFIG.', '5\n is a cutaway side view of a full muleshoe of a sidewall coring tool of the coring system of \nFIG.', '1\n, according to one or more embodiments of the present disclosure;\n \nFIG.', '6\n is a cutaway side view of a half muleshoe of a sidewall coring tool of the coring system of \nFIG.', '1\n, according to one or more embodiments of the present disclosure;\n \nFIG.', '7\n is a cutaway side view of another coring cylinder (e.g., having a “knife edge”) of the sidewall coring tool of the coring system of \nFIG.', '1', ', according to one or more embodiments of the present disclosure;\n \nFIGS.', '8\nA through \n8\nC\n illustrate various embodiments of coring cylinders having a “knife edge”, according to one or more embodiments of the present disclosure; and\n \nFIG.', '9\n is a flow diagram of a method of operating sidewall coring tools, according to one or more embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'One or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are only examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements; in other words, these terms are used in an open-ended fashion, and thus should be interpreted to mean “including, but not limited to . . . .”', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'Furthermore, the phrase “A based on B” is intended to mean that A is at least partially based on B. Moreover, unless expressly stated otherwise, the term “or” is intended to be inclusive (e.g., logical OR) and not exclusive (e.g., logical XOR).', 'In other words, the phrase “A or B” is intended to mean A, B, or both A and B.', 'As used herein, the terms “connect,” “connection,” “connected,” “in connection with,” and “connecting” are used to mean “in direct connection with” or “in connection with via one or more elements”; and the term “set” is used to mean “one element” or “more than one element.”', 'Further, the terms “couple,” “coupling,” “coupled,” “coupled together,” and “coupled with” are used to mean “directly coupled together” or “coupled together via one or more elements.”', 'As used herein, the terms “up” and “down,” “upper” and “lower,” “upwardly” and “downwardly,” “upstream” and “downstream,” “uphole” and “downhole,” “above” and “below,” “top” and “bottom,” and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure.', 'Commonly, these terms relate to a reference point as the surface from which drilling operations are initiated as being the top (e.g., uphole or upper) point and the total depth along the drilling axis being the lowest (e.g., downhole or lower) point, whether the well (e.g., wellbore, borehole) is vertical, horizontal or slanted relative to the surface.', 'As described above, mechanical sidewall coring tools use a coring bit or cylinder to cut into an annular space in the wellbore to create a cylindrical core sample or plug that can be extracted to the surface.', 'A plurality of core samples or plugs can be cut and stored (usually sequentially) and returned to the surface for analysis.', 'The embodiments described herein relate to sidewall coring tools having coring bits or coring shafts that may be used to collect samples (e.g., rock samples, tar sand samples, etc.)', 'from subterranean formations adjacent a borehole or a wellbore.', 'The example coring shafts generally include a cylindrical body coupled to a coring bit having a leading edge (e.g., bit face) to contact and penetrate a subterranean formation to be sampled.', 'The cylindrical body has an internal cavity defined at least in part by an inner surface of the cylindrical body to collect the samples.', 'Referring now to the drawings, \nFIG.', '1\n is a schematic view of an embodiment of a coring system \n10\n utilizing a sidewall coring tool \n12\n as described in greater detail herein.', 'As illustrated, the sidewall coring tool \n12\n may be used in a drilled well to obtain core samples from a downhole or subterranean (e.g., including offshore) formation \n14\n.', 'In operation, the sidewall coring tool \n12\n may be lowered into a wellbore \n16\n with an internal wall, commonly referred to as the bore wall \n18\n.', 'As illustrated, in certain embodiments, the sidewall coring tool \n12\n may be connected by one or more electrically conducting cables \n20\n (e.g., wireline cables) to a surface unit \n22\n, which may include (or otherwise be operatively coupled to) a control panel \n24\n and a monitor \n26\n.', 'In general, the surface unit \n22\n is configured to provide electrical power to the sidewall coring tool \n12\n, to monitor the status of downhole coring and activities of other downhole equipment, and to control the activities of the sidewall coring tool \n12\n and other downhole equipment.', 'While \nFIG. \n1\n illustrates the sidewall coring tool \n12\n deployed at the end of a wireline cable \n20\n, in other embodiments, a sidewall coring tool \n12\n may be deployed in a well using any known or future-developed conveyance means, including drill pipe, coiled tubing, etc.', 'In certain embodiments, the sidewall coring tool \n12\n may be contained within an elongated housing suitable for being lowered into and retrieved from the wellbore \n16\n.', 'In certain embodiments, the sidewall coring tool \n12\n may include an electronic sonde \n28\n, a mechanical sonde \n30\n, and a core storage chamber \n32\n.', 'In general, the electronic sonde \n28\n includes electronics that enable the sidewall coring tool \n12\n to communicate with the surface unit \n22\n (e.g., though the cables \n20\n) and to control coring operations of the sidewall coring tool \n12\n in accordance with such communication.', 'In addition, the mechanical sonde \n30\n includes mechanical components that enable the sidewall coring tool \n12\n to retrieve core samples through the bore wall \n18\n of the wellbore \n16\n, as described in greater detail, and to store the retrieved core samples (e.g., as sequentially retrieved) in the core storage chamber \n32\n.', 'In particular, as described in greater detail herein, the mechanical sonde \n30\n may contain a coring assembly including at least one coring actuator \n34\n powered through the cables \n20\n, a (generally cylindrical) coring cylinder \n36\n having a distal, open axial end \n38\n for cutting and receiving a core sample from a formation \n14\n into an internal cavity formed radially within the coring cylinder \n36\n, and a mechanical linkage (not shown) for deploying and retracting the coring cylinder \n36\n relative to the sidewall coring tool \n12\n, as described in greater detail herein. \nFIG.', '1\n illustrates the sidewall coring tool \n12\n in an active, cutting configuration.', 'As described in greater detail herein, the distal, open axial end \n38\n of the coring cylinder \n36\n may be moved via the coring actuator \n34\n against the formation \n14\n to cut a core sample from the formation \n14\n.', 'The embodiments described herein provide systems and methods for improving the recovery and quality of subterranean sidewall core samples in unconsolidated formations \n14\n with relatively low Unconfined Compressive Strength (UCS) (e.g., less than 800 psi UCS).', 'This is even more challenging in subterranean environments with relatively high pressure (e.g., greater than 25 ksi).', 'For example, coring and recovery become even more challenging with increasing formation pore pressure and increasing mud weight and associated hydrostatic pressure.', 'As used herein, the term “unconsolidated” is intended to refer to formations \n14\n having uncemented to poorly cemented grains (regardless of the actual grain size, though it would be a fraction of the bit inner diameter).', 'For coring planning purposes, the term “unconsolidated” may be used based on the measured or computed values of UCS in the following manner: \n \n \n \nUCS ˜2,000 psi: consolidated formation\n \n \n \n \n \nTraditionally, sidewall core samples are predominately extracted by one of two means—percussive sidewall coring or rotary sidewall coring.', 'Rotary sidewall coring mainly uses a coring bit to drill out the core sample (e.g., like a hole saw).', 'This method works very well for relatively hard rocks, but poorly for unconsolidated formations \n14\n.', 'In general, the drilling rotation causes vortexes with the cuttings and downhole fluids that destroy samples with relatively low UCS (e.g., 100-300 psi) or unconsolidated formations \n14\n (e.g., including sand, sandstone, shale, shaly sand, sandy shale, other low UCS rock types, and so forth).', 'Additionally, with the downhole pressure, while drilling the differential pressure between the wellbore \n16\n and the formation \n14\n tries to pull back cuttings, causing the bit to stall.', 'As such, the coring bit often needs to be pulled back several times to clear the cuttings to recover a single core.', 'The rotation of the coring bit and these additional actions cause damage to the core sample, leading to poor quality that are often not recoverable.', 'Percussive coring, on the other hand, uses shape charges that shoot cups (e.g., hollow bullets) into the rock that are tethered to the sidewall coring tool.', 'Percussive coring is often better at capturing softer cores, but it generally tends to destroy the integrity of the core due to the relatively high shock.', 'The embodiments described herein combine both methods in a single sidewall coring tool \n12\n.', 'In particular, instead of using a rotating bit to drill into the formation \n14\n like as done on a rotary sidewall coring tool, the sidewall coring tool \n12\n described herein uses a coring cylinder \n36\n to cut and penetrate into the formation \n14\n.', 'Similarly to rotary sidewall coring, after being axially pushed against a surface of the formation \n14\n, the sidewall coring tool \n12\n described herein is configured to rotate the coring cylinder \n36\n back and forth, but only less than a full rotation (e.g., 360 degrees), for example, less than ¾ turn (e.g., 270 degrees), less than ½ turn (e.g., 180 degrees), or approximately 90 degrees (e.g., within a range of between 85-95 degrees, between 86-94 degrees, between 87-93 degrees, between 88-92 degrees, between 89-91 degrees, and so forth) relative to a longitudinal axis of the coring cylinder \n36\n, while applying axial force such that the rotation of the coring cylinder \n36\n begins forming the core sample, at each coring station.', 'After initially forming a small portion of the core sample, similar to percussive sidewall coring, using hydraulics and a coring actuator \n34\n, the rotating coring cylinder \n36\n is then pushed axially into the formation \n14\n, thereby further forming the core sample.\n \nFIG.', '2\n is a schematic diagram of the surface unit \n22\n of the coring system \n10\n of \nFIG.', '1\n.', 'As illustrated, in certain embodiments, the surface unit \n22\n may include one or more processor(s) \n40\n, memory media \n42\n, storage media \n44\n, and/or a display \n46\n.', 'In certain embodiments, the surface unit \n22\n may send control signals to, among other things, the coring actuators \n34\n of the sidewall coring tools \n12\n to enable the coring actuators \n34\n to cause the rotation and axial movement of the respective coring cylinders \n36\n, as described in greater detail herein.', 'In particular, the processor(s) \n40\n, using instructions stored in the memory media \n42\n and/or storage media \n44\n, may determine when and how to control operational parameters of the sidewall coring tools \n12\n.', 'As such, the memory media \n42\n and/or the storage media \n44\n of the surface unit \n22\n may be any suitable article of manufacture that can store the instructions.', 'The memory media \n42\n and/or the storage media \n44\n may be read-only memory (ROM), random-access memory (RAM), flash memory, an optical storage medium, or a hard disk drive, to name a few examples.', 'The display \n46\n may be any suitable electronic display that can display logs, indices, and/or indicators that enable monitoring of operation of the sidewall coring tools \n12\n, as described in greater detail herein.', 'In certain embodiments, the sidewall coring tool \n12\n may include processing circuitry similar to the surface unit \n22\n to enable the sidewall coring tool \n12\n to at least partially control the rotation and axial movement of its respective coring cylinder \n36\n, as described in greater detail herein.', 'The sidewall coring tool \n12\n may utilize various different types of coring actuators \n34\n to cause the rotation and the axial movement of the coring cylinder \n36\n, as described in greater detail herein.', 'FIGS.', '3\n and \n4\n illustrate two non-limiting examples of such coring actuators \n34\n of the sidewall coring tool \n12\n.', 'In particular, \nFIG.', '3\n illustrates a coring actuator \n34\nA of the sidewall coring tool \n12\n that includes a hydraulic piston \n52\nA that may directly cause axial movement \n54\n of the coring cylinder \n36\n into the formation \n14\n, and \nFIG.', '4\n illustrates a coring actuator \n34\nB of the sidewall coring tool \n12\n that includes a set of opposing hydraulic pistons \n52\nB, \n52\nC that may indirectly cause the axial movement \n54\n of the coring cylinder \n36\n into the formation \n14\n via connections to linkages \n56\nB, \n56\nC that are coupled to both the respective hydraulic piston \n52\nB, \n52\nC and the axial end \n48\n of the coring cylinder \n36\n.', 'Although illustrated in \nFIGS. \n3\n and \n4\n as being hydraulic actuators \n34\nA, \n34\nB that include hydraulic pistons \n52\nA, \n52\nB, \n52\nC, in other embodiments, the actuators \n34\n described herein may utilize other actuation means including, but not limited to, electric actuation, electromagnetic actuation, magnetic actuation, mechanical actuation, or some combination thereof.', 'As illustrated in \nFIG.', '3\n, injection of hydraulic fluid into a piston chamber \n58\nA of the hydraulic piston \n52\nA causes a piston head \n60\nA of the hydraulic piston \n52\nA to move away from a transverse axis \n62\n of the sidewall coring tool \n12\n (and toward the formation \n14\n), which in turn causes a piston rod \n64\nA of the hydraulic piston \n52\nA, which is coupled to the axial end \n48\n of the coring cylinder \n36\n, to push the coring cylinder \n36\n into the formation \n14\n, as illustrated by arrow \n54\n, to enable extraction of a core sample \n66\n.', 'It will be appreciated that the hydraulic piston \n52\nA of the coring actuator \n34\nA illustrated in \nFIG.', '3\n may be a linear hydraulic piston \n52\nA whereby the piston rod \n64\nA is configured to move linearly relative to a cylinder \n68\nA of the hydraulic piston \n52\nA.', 'In addition, in certain embodiments, the piston head \n60\nA and the piston rod \n64\nA of the hydraulic piston \n52\nA may be configured to be rotated about a longitudinal axis \n50\n of the hydraulic piston \n52\nA (and the coring cylinder \n36\n), as illustrated by arrow \n70\n, while applying force against the formation \n14\n via the coring cylinder \n36\n, prior to the axial movement \n54\n of the coring cylinder \n36\n.', 'In contrast, as opposed to having a single hydraulic piston \n52\nA that is configured to directly actuate the coring cylinder \n36\n, in other embodiments, the coring actuator \n34\nB illustrated in \nFIG.', '4\n includes two opposing hydraulic pistons \n52\nB, \n52\nC that are longitudinally aligned with the transverse axis \n62\n of the sidewall coring tool \n12\n.', 'As illustrated in \nFIG.', '4\n, injection of hydraulic fluid into piston chambers \n58\nB, \n58\nC of the hydraulic pistons \n52\nB, \n52\nC causes piston heads \n60\nB, \n60\nC of the hydraulic pistons \n52\nB, \n52\nC to move toward each other along the transverse axis \n62\n of the sidewall coring tool \n12\n, as illustrated by arrows \n72\n, which in turn causes piston rods \n64\nB, \n64\nC of the hydraulic piston \n52\nB, \n52\nC, which are coupled to respective linkages \n56\nB, \n56\nC that are coupled to the axial end \n48\n of the coring cylinder \n36\n, to push the coring cylinder \n36\n into the formation \n14\n, as illustrated by arrow \n54\n, to enable extraction of a core sample \n66\n.', 'It will be appreciated that the hydraulic pistons \n52\nB, \n52\nC of the coring actuator \n34\nB illustrated in \nFIG.', '4\n may have piston rods \n64\nB, \n64\nC that are coupled to their respective piston heads \n60\nB, \n60\nC at rod connection joints \n74\nB, \n74\nC that enable the piston rods \n64\nB, \n64\nC to rotate about the rod connection joints \n74\nB, \n74\nC (e.g., as opposed to the rigidly-coupled linear piston head \n60\nA and piston rod \n64\nA of the hydraulic piston \n52\nA of the coring actuator \n34\nA illustrated in \nFIG. \n3\n).', 'In addition, as also illustrated in \nFIG.', '4\n, the piston rods \n64\nB, \n64\nC are each rotationally coupled to respective linkages \n56\nB, \n56\nC (e.g., at linkage connection joints \n76\nB, \n76\nC) such that the axial movement \n72\n of the piston heads \n60\nB, \n60\nC of the hydraulic pistons \n52\nB, \n52\nC indirectly causes the linkages \n56\nB, \n56\nC to cause the axial movement of the coring cylinder \n36\n into the formation \n14\n (e.g., via a coring cylinder connection joint \n78\n that rotationally couples the linkages \n56\nB, \n56\nC to the coring cylinder \n36\n).', 'In addition, in certain embodiments, the piston rods \n64\nB, \n64\nC of the hydraulic pistons \n52\nB, \n52\nC may also be configured to rotate along a plane of the transverse axis \n62\n of the sidewall coring tool \n12\n (e.g., into or out of \nFIG.', '4\n) to indirectly cause (e.g., via the respective linkages \n56\nB, \n56\nC) the coring cylinder \n36\n to rotate about the longitudinal axis \n50\n of the coring cylinder \n36\n, as illustrated by arrow \n70\n, while applying force against the formation \n14\n via the coring cylinder \n36\n, prior to the axial movement \n54\n of the coring cylinder \n36\n.', 'In certain embodiments, after the core sample \n66\n has been formed, the process for rotating the coring cylinder \n36\n back and forth less than a full rotation (e.g., 360 degrees), for example, less than ¾ turn (e.g., 270 degrees), less than ½ turn (e.g., 180 degrees), or approximately 90 degrees (e.g., within a range of between 85-95 degrees, between 86-94 degrees, between 87-93 degrees, between 88-92 degrees, between 89-91 degrees, and so forth) relative to a longitudinal axis of the coring cylinder \n36\n, may be performed by the coring actuator \n34\n to break any mud-seal formed between the coring cylinder \n36\n and the formation \n14\n.', 'In other embodiments, the mud-seal may be broken using relatively rapid axial movement of the coring cylinder \n36\n at a relatively small amplitude.', 'Then, reverse axial motion of the coring cylinder \n36\n may be performed by the coring actuator \n34\n, for example, by reversing the axial movement steps discussed with reference to \nFIGS. \n3\n and \n4\n to extract the core sample \n66\n.', 'In addition, in certain embodiments, the core sample \n66\n may be extracted at least partially using suction created by the sidewall coring tool \n12\n within the internal cavity formed radially within the coring cylinder \n36\n.', 'In certain embodiments, the coring cylinder \n36\n may take the form of a muleshoe, half muleshoe, or other muleshoe.', 'As used herein, the term “muleshoe” is used to mean a relatively short length of cylindrical tubing having an axial end of the tubing angled (e.g., 45 degrees, between 40-50 degrees, between 35-55 degrees, between 30-60 degrees, and so forth) relative to its longitudinal axis.', 'For example, \nFIGS.', '5\n and \n6\n are cutaway side views of a full muleshoe \n36\nA and a half muleshoe \n36\nB of the sidewall coring tool \n12\n of the coring system \n10\n of \nFIG.', '1\n, respectively.', 'As illustrated, each muleshoe \n36\n includes a cylindrical tubular body \n80\n that includes an angled axial end \n38\n (e.g., an axial end farthest away from the sidewall coring tool \n12\n.', 'Specifically, the opposite axial end \n48\n is closest to the sidewall coring tool \n12\n and is the axial end that is actuated by the sidewall coring tool \n12\n to move the muleshoe \n36\n into a formation \n14\n to extract a sidewall core sample, as described in greater detail herein.', 'The main difference between the full muleshoe \n36\nA illustrated in \nFIG.', '5\n and the half muleshoe \n36\nB illustrated in \nFIG.', '6\n is that only approximately half of the axial end \n38\n of the half muleshoe \n36\nB illustrated in \nFIG.', '6\n is angled, wherein the entirety of the axial end \n38\n of the full muleshoe \n36\nA illustrated in \nFIG.', '5\n is angled.', 'It will be appreciated that other types of partial muleshoes \n36\n (e.g., having only a portion of the axial end \n38\n of the muleshoe \n36\n angled).', 'In addition, in other embodiments, the sidewall coring tool \n12\n described herein may instead utilize cylindrical coring tubing not having an angled axial end, such as the muleshoes \n36\n illustrated in \nFIGS. \n5\n and \n6\n.', 'However, the muleshoes \n36\n illustrated in \nFIGS.', '5\n and \n6\n may be particularly effective at cutting into the formation \n14\n when the respective muleshoe \n36\n is pushed against the formation \n14\n and rotated about its longitudinal axis \n50\n (e.g., to begin forming the core sample) before being further axially pushed into the formation \n14\n (e.g., to further form the core sample), as described in greater detail herein.', 'FIG.', '7\n is a cutaway side view of another coring cylinder \n36\nC (e.g., having a knife edge) of the sidewall coring tool \n12\n of the coring system \n10\n of \nFIG.', '1\n.', 'As illustrated in \nFIG.', '7\n, the coring cylinder \n36\nC does not include a muleshoe, half muleshoe, or other partial muleshoe \n36\n.', 'Rather, the coring cylinder \n36\nC illustrated in \nFIG.', '7\n includes cylindrical coring tubing not having an angled axial end, but rather having “knife edge” (e.g., triangular) points \n38\nC formed at the axial end \n38\n of the coring cylinder \n36\nC that enable the coring cylinder \n36\nC to more effectively cut into the formation \n14\n when the coring cylinder \n36\n is axially pushed into the formation \n14\n, as described in greater detail herein.', 'In addition, in certain embodiments, the coring cylinders \n36\n described herein may include serrated edge axial ends (e.g., having a plurality of serrated teeth).', 'Returning now to \nFIGS.', '5\n and \n6\n, in certain embodiments, the muleshoes \n36\nA, \n36\nB may include one or more debris holes \n82\n through walls of the cylindrical tubular bodies \n80\n of the muleshoes \n36\nA, \n36\nB that enable fluids, mud, debris, and so forth, to be displaced from interiors of the muleshoes \n36\nA, \n36\nB, which in turn enables the muleshoes \n36\nA, \n36\nB to penetrate the formation \n14\n, as described in greater detail herein.', 'It will be appreciated that the coring cylinder \n36\nC illustrated in \nFIG.', '3\n may also include one or more similar debris holes \n82\n through the wall of the cylindrical tubular body \n80\n of the coring cylinder \n36\n.', 'In addition, \nFIGS.', '8\nA through \n8\nC\n illustrate various embodiments of coring cylinders \n36\n having “knife edge” (e.g., triangular) points \n38\n.', 'In particular, \nFIG.', '8\nA\n illustrates a coring cylinder \n36\nD having a single (e.g., continuous) knife edge end \n38\nD. In addition, \nFIGS.', '8\nB and \n8\nC\n illustrate coring cylinders \n36\nE, \n36\nF having serrated knife edge ends \n38\nE, \n38\nF that include a plurality of knife edge segments \n84\nE, \n84\nF (e.g., serrations or teeth) with corresponding interruptions \n86\nE, \n86\nF between neighboring knife edge segments \n84\nE, \n84', 'E. The embodiments illustrated in \nFIGS.', '8\nB and \n8\nC\n include coring cylinders \n36\nE, \n36\nF having serrated knife edge ends \n38\nE, \n38\nF that include four knife edge segments \n84\nE and fifteen knife edge segments \n84\nF, respectively.', 'However, in other embodiments, the coring cylinders \n36\n may have serrated knife edge ends \n38\n having any number of two or more knife edge segments \n84\n.\n \nFIG.', '9\n is a flow diagram of a method \n88\n of operating the sidewall coring tools \n12\n described herein.', 'In certain embodiments, the method \n88\n includes deploying a sidewall coring tool \n12\n into a wellbore \n16\n extending through a subterranean formation \n14\n (block \n90\n).', 'In certain embodiments, the method \n88\n also includes rotating a coring cylinder (e.g., a muleshoe \n36\n, in certain embodiments) of the sidewall coring tool \n12\n less than a full rotation while pushing the coring cylinder \n36\n of the sidewall coring tool \n12\n against a bore wall \n18\n of the wellbore \n16\n (block \n92\n).', 'In certain embodiments, the method \n88\n further includes pushing the coring cylinder \n36\n of the sidewall coring tool \n12\n into the subterranean formation \n14\n to enable extraction of the core sample \n66\n of the subterranean formation \n14\n (block \n94\n).', 'In addition, in certain embodiments, the method \n88\n may optionally include rotating the coring cylinder \n36\n of the sidewall coring tool \n12\n to break a pressure seal formed by drilling mud, for example, when such a pressure seal exists (block \n96\n) and the core cannot be extracted due to the pressure differential across such pressure seal.', 'In other embodiments, the pressure seal may be broken using relatively rapid axial movement of the coring cylinder \n36\n at a relatively small amplitude.', 'In addition, in certain embodiments, the method \n88\n includes retracting the coring cylinder \n36\n to retrieve the core sample \n66\n of the subterranean formation \n14\n (block \n98\n).', 'In addition, as described in greater detail herein, the sidewall coring tool \n12\n includes a coring cylinder \n36\n, and one or more coring actuators \n34\n configured to rotate the coring cylinder \n36\n less than a full rotation while pushing the coring cylinder \n36\n of the sidewall coring tool \n12\n against a bore wall \n18\n of a wellbore \n16\n, and to push the coring cylinder \n36\n of the sidewall coring tool \n12\n into the subterranean formation \n14\n to enable extraction of the core sample \n66\n of the subterranean formation \n14\n.', 'In certain embodiments, the one or more coring actuators \n34\n are configured to rotate the coring cylinder \n36\n of the sidewall coring tool \n12\n back and forth relative to the longitudinal axis \n50\n less than 90 degrees while pushing the coring cylinder \n36\n of the sidewall coring tool \n12\n against the bore wall \n18\n of the wellbore \n16\n.', 'In addition, in certain embodiments, the sidewall coring tool \n12\n includes a single coring actuator \n34\nA coupled to the coring cylinder \n36\n and configured to directly rotate and push the coring cylinder \n36\n of the sidewall coring tool \n12\n into the subterranean formation \n14\n.', 'In other embodiments, the sidewall coring tool \n12\n includes two opposing coring actuators \n34\nB, \n34\nC configured to indirectly rotate and push the coring cylinder \n36\n of the sidewall coring tool \n12\n into the subterranean formation \n14\n via respective linkages \n56\nB, \n56\nC coupled to the coring actuators \n34\nB, \n34\nC and the coring cylinder \n36\n of the sidewall coring tool \n12\n.', 'In addition, in certain embodiments, the coring cylinder \n36\n includes a full muleshoe \n36\nA, a half muleshoe \n36\nB, or other partial muleshoe \n36\n.', 'In addition, in certain embodiments, the coring cylinder \n36\n includes a knife edge axial end \n38\nC.', 'In addition, in certain embodiments, a coring system \n10\n includes a sidewall coring tool \n12\n having a coring cylinder and one or more coring actuators \n34\n configured to perform sidewall coring of a subterranean formation \n14\n using a combination of rotary and percussive coring.', 'In addition, in certain embodiments, the coring system \n10\n includes a surface unit \n22\n configured to send control signals to the sidewall coring tool \n12\n to control the sidewall coring of the subterranean formation \n14\n.', 'While the present disclosure may be susceptible to various modifications and alternative forms, specific embodiments have been shown by way of example in the drawings and have been described in detail herein.', 'However, it should be understood that the present disclosure is not intended to be limited to the particular forms disclosed.', 'For example, while some embodiments described herein contain specific combinations of coring systems, other combinations may also be possible.', 'Rather, the present disclosure is intended to cover all modifications, equivalents, and alternatives falling within the spirit and scope of the present disclosure as defined by the following appended claims.', 'In particular, it will be appreciated that any and all combinations and sub-combinations of the various features described herein may be included or omitted from any particular embodiment.', 'The techniques presented and claimed herein are referenced and applied to material objects and concrete examples of a practical nature that demonstrably improve the present technical field and, as such, are not abstract, intangible or purely theoretical.', 'Further, if any claims appended to the end of this specification contain one or more elements designated as “means for [perform]ing [a function] . . . ”', 'or “step for [perform]ing [a function] . .', '.', ',” it is intended that such elements are to be interpreted under 35 U.S.C. § 112(f).', 'However, for any claims containing elements designated in any other manner, it is intended that such elements are not to be interpreted under 35 U.S.C. § 112(f).', 'This written description uses examples to disclose the invention, including the best mode, and also to enable any person skilled in the art to practice the invention, including making and using any devices or systems and performing any incorporated methods.', 'The patentable scope of the invention is defined by the claims, and may include other examples that occur to those skilled in the art.', 'Such other examples are intended to be within the scope of the claims if they have structural elements that do not differ from the literal language of the claims, or if they include equivalent structural elements with insubstantial differences from the literal languages of the claims.']

['1.', 'A method, comprising:\ndeploying a sidewall coring tool into a wellbore extending through a subterranean formation;\nrotating a coring cylinder of the sidewall coring tool back and forth less than a full rotation while pushing the coring cylinder of the sidewall coring tool against a bore wall of the wellbore;\npushing the coring cylinder of the sidewall coring tool into the subterranean formation to enable extraction of a core sample of the subterranean formation; and\nretracting the coring cylinder to retrieve the core sample of the subterranean formation.', '2.', 'The method of claim 1, comprising rotating the coring cylinder of the sidewall coring tool to break a pressure seal formed by drilling mud prior to retracting the coring cylinder to retrieve the core sample of the subterranean formation.', '3.', 'The method of claim 1, comprising rotating the coring cylinder of the sidewall coring tool back and forth less than 90 degrees while pushing the coring cylinder of the sidewall coring tool against the bore wall of the wellbore.', '4.', 'The method of claim 1, wherein the sidewall coring tool comprises one or more actuators configured to rotate and push the coring cylinder of the sidewall coring tool into the subterranean formation.', '5.', 'The method of claim 1, wherein the sidewall coring tool comprises a single actuator coupled to the coring cylinder and configured to directly rotate and push the coring cylinder of the sidewall coring tool into the subterranean formation.', '6.', 'The method of claim 1, wherein the sidewall coring tool comprises two opposing actuators configured to indirectly rotate and push the coring cylinder of the sidewall coring tool into the subterranean formation via respective linkages coupled to the two opposing actuators and the coring cylinder of the sidewall coring tool.', '7.', 'The method of claim 1, wherein the coring cylinder comprises a full muleshoe.', '8.', 'The method of claim 1, wherein the coring cylinder comprises a partial muleshoe.', '9.', 'The method of claim 1, wherein the coring cylinder comprises a knife edge axial end.', '10.', 'The method of claim 9, wherein the knife edge axial end comprises a serrated knife edge axial end having two or more segments.', '11.', 'A sidewall coring tool, comprising:\na coring cylinder; and\none or more actuators configured to: rotate the coring cylinder back and forth less than a full rotation while pushing the coring cylinder against a bore wall of a wellbore; and push the coring cylinder into a subterranean formation to enable extraction of a core sample of the subterranean formation.\n\n\n\n\n\n\n12.', 'The sidewall coring tool of claim 11, wherein the one or more actuators are configured to rotate the coring cylinder back and forth less than 90 degrees while pushing the coring cylinder against the bore wall of the wellbore.', '13.', 'The sidewall coring tool of claim 11, comprising a single actuator coupled to the coring cylinder and configured to directly rotate and push the coring cylinder into the subterranean formation.', '14.', 'The sidewall coring tool of claim 11, comprising two opposing actuators configured to indirectly rotate and push the coring cylinder into the subterranean formation via respective linkages coupled to the actuators and the coring cylinder of the sidewall coring tool.', '15.', 'The sidewall coring tool of claim 11, wherein the coring cylinder comprises a full muleshoe.', '16.', 'The sidewall coring tool of claim 11, wherein the coring cylinder comprises a partial muleshoe.', '17.', 'The sidewall coring tool of claim 11, wherein the coring cylinder comprises a knife edge axial end.', '18.', 'The sidewall coring tool of claim 17, wherein the knife edge axial end comprises a serrated knife edge axial end having two or more segments.', '19.', 'A coring system, comprising:\na sidewall coring tool comprising a coring cylinder and one or more actuators configured to perform sidewall coring of a subterranean formation using a combination of rotary and percussive coring; and\na surface unit configured to send control signals to the sidewall coring tool to control the sidewall coring of the subterranean formation,\nwherein the one or more actuators are configured to rotate the coring cylinder of the sidewall coring tool back and forth less than 90 degrees while pushing the coring cylinder of the sidewall coring tool against a bore wall of a wellbore extending through the subterranean formation.']

['FIG.', '1 is a schematic view of an embodiment of a coring system, according to one or more embodiments of the present disclosure;; FIG.', '2 is a schematic diagram of a surface unit of the coring system of FIG.', '1, according to one or more embodiments of the present disclosure;; FIG. 3 illustrates a coring actuator of a sidewall coring tool that includes a hydraulic piston, according to one or more embodiments of the present disclosure;; FIG.', '4 illustrates a coring actuator of a sidewall coring tool that includes a set of opposing hydraulic pistons, according to one or more embodiments of the present disclosure;; FIG.', '5 is a cutaway side view of a full muleshoe of a sidewall coring tool of the coring system of FIG.', '1, according to one or more embodiments of the present disclosure;; FIG.', '6 is a cutaway side view of a half muleshoe of a sidewall coring tool of the coring system of FIG.', '1, according to one or more embodiments of the present disclosure;; FIG. 7 is a cutaway side view of another coring cylinder (e.g., having a “knife edge”) of the sidewall coring tool of the coring system of FIG.', '1, according to one or more embodiments of the present disclosure;;', 'FIGS.', '8A through 8C illustrate various embodiments of coring cylinders having a “knife edge”, according to one or more embodiments of the present disclosure; and; FIG.', '9 is a flow diagram of a method of operating sidewall coring tools, according to one or more embodiments of the present disclosure.; FIG.', '2 is a schematic diagram of the surface unit 22 of the coring system 10 of FIG.', '1.', 'As illustrated, in certain embodiments, the surface unit 22 may include one or more processor(s) 40, memory media 42, storage media 44, and/or a display 46.', 'In certain embodiments, the surface unit 22 may send control signals to, among other things, the coring actuators 34 of the sidewall coring tools 12 to enable the coring actuators 34 to cause the rotation and axial movement of the respective coring cylinders 36, as described in greater detail herein.', 'In particular, the processor(s) 40, using instructions stored in the memory media 42 and/or storage media 44, may determine when and how to control operational parameters of the sidewall coring tools 12.', 'As such, the memory media 42 and/or the storage media 44 of the surface unit 22 may be any suitable article of manufacture that can store the instructions.', 'The memory media 42 and/or the storage media 44 may be read-only memory (ROM), random-access memory (RAM), flash memory, an optical storage medium, or a hard disk drive, to name a few examples.', 'The display 46 may be any suitable electronic display that can display logs, indices, and/or indicators that enable monitoring of operation of the sidewall coring tools 12, as described in greater detail herein.', 'In certain embodiments, the sidewall coring tool 12 may include processing circuitry similar to the surface unit 22 to enable the sidewall coring tool 12 to at least partially control the rotation and axial movement of its respective coring cylinder 36, as described in greater detail herein.; FIG.', '7 is a cutaway side view of another coring cylinder 36C (e.g., having a knife edge) of the sidewall coring tool 12 of the coring system 10 of FIG.', '1.', 'As illustrated in FIG. 7, the coring cylinder 36C does not include a muleshoe, half muleshoe, or other partial muleshoe 36.', 'Rather, the coring cylinder 36C illustrated in FIG.', '7 includes cylindrical coring tubing not having an angled axial end, but rather having “knife edge” (e.g., triangular) points 38C formed at the axial end 38 of the coring cylinder 36C that enable the coring cylinder 36C to more effectively cut into the formation 14 when the coring cylinder 36 is axially pushed into the formation 14, as described in greater detail herein.', 'In addition, in certain embodiments, the coring cylinders 36 described herein may include serrated edge axial ends (e.g., having a plurality of serrated teeth).', '; FIG.', '9 is a flow diagram of a method 88 of operating the sidewall coring tools 12 described herein.', 'In certain embodiments, the method 88 includes deploying a sidewall coring tool 12 into a wellbore 16 extending through a subterranean formation 14 (block 90).', 'In certain embodiments, the method 88 also includes rotating a coring cylinder (e.g., a muleshoe 36, in certain embodiments) of the sidewall coring tool 12 less than a full rotation while pushing the coring cylinder 36 of the sidewall coring tool 12 against a bore wall 18 of the wellbore 16 (block 92).', 'In certain embodiments, the method 88 further includes pushing the coring cylinder 36 of the sidewall coring tool 12 into the subterranean formation 14 to enable extraction of the core sample 66 of the subterranean formation 14 (block 94).', 'In addition, in certain embodiments, the method 88 may optionally include rotating the coring cylinder 36 of the sidewall coring tool 12 to break a pressure seal formed by drilling mud, for example, when such a pressure seal exists (block 96) and the core cannot be extracted due to the pressure differential across such pressure seal.', 'In other embodiments, the pressure seal may be broken using relatively rapid axial movement of the coring cylinder 36 at a relatively small amplitude.', 'In addition, in certain embodiments, the method 88 includes retracting the coring cylinder 36 to retrieve the core sample 66 of the subterranean formation 14 (block 98).']

US11925958

System and method for locking a weight assembly

Aug 6, 2020

Muneeb Ahmed, Robert Lunnemann, James McCoy

SCHLUMBERGER TECHNOLOGY CORPORATION

International Search Report and Written Opinion issued in International Patent application PCT/US2020/045190 dated Nov. 18, 2020, 9 pages.; International Preliminary Report on Patentability issued in International Patent application PCT/US2020/045190 dated Mar. 10, 2022, 6 pages.

3863765; February 1975; Gray; 5134893; August 4, 1992; Hukki et al.; 6401933; June 11, 2002; Cohen et al.; 20070084762; April 19, 2007; Mainwaring et al.; 20160230802; August 11, 2016; Emmerich; 20160339477; November 24, 2016; McLean; 20200047217; February 13, 2020; Lunnemann

2018080852; May 2018; WO

['A lock assembly for a vibratory separator includes a latch.', 'The latch includes a first inner protrusion and a first outer protrusion.', 'The first outer protrusion defines a first outer protrusion opening.', 'The lock assembly also includes a first spacer.', 'The first spacer includes a first fastener that is configured to be inserted into the first outer protrusion opening.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is the National Stage Entry of International Application No. PCT/US2020/045190, filed Aug. 6, 2020, which claims the benefit of U.S. Provisional Application No. 62/894,154, filed Aug. 30, 2019, which is incorporated by reference in its entirety.', 'BACKGROUND\n \nVibratory separators are used to separate solid particles from fluids and/or to separate solid particles of different sizes from one another.', 'In the oil and gas industry, vibratory separators, such as shale shakers, are used to remove cuttings and other solid particles from used drilling fluid (e.g., mud) that is returned from a wellbore.', 'A vibratory separator includes a motor that generates rotary motion.', 'An eccentric weight assembly is coupled to the motor to convert at least a portion of the rotary motion into vibratory motion, which facilitates the separation process.', 'The vibratory motion may also inadvertently have the effect of creating relative motion between two or more portions of the weight assembly, which may create a spark.', 'A wellsite where the vibratory separator is employed may include gases or liquids that may ignite in response to such a spark.', 'Therefore, it would be desirable to have a system and method for preventing relative motion within the weight assembly to prevent the creation of a spark.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'A lock assembly for a vibratory separator is disclosed.', 'The lock assembly includes a latch.', 'The latch includes a first inner protrusion and a first outer protrusion.', 'The first outer protrusion defines a first outer protrusion opening.', 'The lock assembly also includes a first spacer including a first fastener that is configured to be inserted into the first outer protrusion opening.', 'A system is also disclosed.', 'The system includes a weight assembly.', 'The weight assembly includes a weight arm defining a first weight arm opening.', 'The weight assembly also includes an upper weight plate and a lower weight plate.', 'The weight arm is positioned at least partially between the upper weight plate and the lower weight plate.', 'The system also includes a lock assembly.', 'The lock assembly includes a latch.', 'The latch includes a first inner protrusion configured to be inserted into the first weight arm opening, and a first outer protrusion that defines a first outer protrusion opening.', 'The lock assembly also includes a first spacer configured to be positioned within a first recess defined at least partially between the upper weight plate and the lower weight plate.', 'The first spacer includes a first fastener that is configured to be inserted into the first outer protrusion opening.', 'A method is also disclosed.', 'The method includes positioning a first spacer at least partially within a first recess defined between an upper weight plate and a lower weight plate.', 'The first spacer comprises a first fastener.', 'The method also includes inserting a second fastener at least partially through a first spacer opening in the first spacer.', 'The method also includes positioning a latch such that the first fastener extends through a first outer protrusion opening in the latch.', 'The latch includes a first outer protrusion that defines the first outer protrusion opening.', 'The method also includes moving the latch in a first direction to align a first inner protrusion of the latch with a first weight arm opening in a weight arm.', 'The weight arm is positioned at least partially between the upper weight plate and the lower weight plate.', 'The method also includes moving the latch in a second direction to insert the first inner protrusion at least partially into the first weight arm opening.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is best understood from the following detailed description when read with the accompanying Figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n is a perspective view of a vibratory separator, according to one or more examples of the disclosure.\n \nFIG.', '2\n is a perspective view of a motor and a weight assembly of the vibratory separator of \nFIG.', '1\n, with the remainder of the vibratory separator removed for clarity, according to one or more examples of the disclosure.', 'FIG.', '3\n is a perspective view of the weight assembly of \nFIG.', '2\n with an exploded lock assembly, according to one or more examples of the disclosure.', 'FIG.', '4\n is a flowchart of a method for assembling the vibratory separator, according to one or more examples of the disclosure.\n \nFIG.', '5\n is a perspective view of the weight assembly with the lock assembly coupled thereto, according to one or more examples of the disclosure.', 'DETAILED DESCRIPTION\n \nIllustrative examples of the subject matter claimed below will now be disclosed.', 'In the interest of clarity, not all features of an actual implementation are described in this specification.', "It will be appreciated that in the development of any such actual implementation, numerous implementation-specific decisions may be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which will vary from one implementation to another.", 'Moreover, it will be appreciated that such a development effort, even if complex and time-consuming, would be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.', 'Further, as used herein, the article “a” is intended to have its ordinary meaning in the patent arts, namely “one or more.”', 'Herein, the term “about” when applied to a value generally means within the tolerance range of the equipment used to produce the value, or in some examples, means plus or minus 10%, or plus or minus 5%, or plus or minus 1%, unless otherwise expressly specified.', 'Further, herein the term “substantially” as used herein means a majority, or almost all, or all, or an amount with a range of about 51% to about 100%, for example.', 'Moreover, examples herein are intended to be illustrative only and are presented for discussion purposes and not by way of limitation.\n \nFIG.', '1\n is a perspective view of a vibratory separator \n100\n, according to one or more examples of the disclosure.', 'The vibratory separator \n100\n may be a vibratory shaker, such as a shale shaker, used in the oilfield industry to process wellbore fluids.', 'The vibratory separator \n100\n may also or instead be used in the food industry, cleaning industry, waste water treatment industry, and others.', 'As shown, the vibratory separator \n100\n may include a first (e.g., upper) weight assembly \n110\nA and a second (e.g., lower) weight assembly \n110\nB.', 'The first and second weight assemblies \n110\nA, \n110\nB may be the same or may be different from one another.\n \nFIG.', '2\n is a perspective view of a motor \n130\n of the vibratory separator \n100\n with the first weight assembly \n110\nA coupled thereto, according to one or more examples of the disclosure.', 'The remainder of the vibratory separator \n100\n shown in \nFIG.', '1\n has been removed for clarity.', 'The first weight assembly \n110\nA may include a weight arm \n210\n.', 'The weight arm \n210\n may include a first (e.g., upper) arm \n212\nA and a second (e.g., lower) arm \n212\nB that are coupled (e.g., welded) together.', 'The weight arm \n210\n may define a plurality of openings (referred to as weight arm openings) \n214\n extending at least partially therethrough.', 'For example, the weight arm openings \n214\n may extend from an upper surface of the upper arm \n212\nA to a lower surface of the lower arm \n212\nB.', 'At least some of the weight arm openings \n214\n may be longitudinally-offset from one another with respect to a central longitudinal axis \n211\n that extends through the weight arm \n210\n.', 'As shown, in one embodiment, the weight arm openings \n214\n may be arranged in two longitudinal rows.', 'The first weight assembly \n110\nA may also include a hub \n220\n that couples the first weight assembly \n110\nA to the motor \n130\n.', 'More particularly, the hub \n220\n may couple the weight arm \n210\n to a shaft of the motor \n130\n.', 'The first weight assembly \n110\nA may also include a first (e.g., upper) weight plate \n232\nA and a second (e.g., lower) weight plate \n232\nB.', 'The weight arm \n210\n may be positioned at least partially between the upper and lower weight plates \n232\nA, \n232\nB. More particularly, the upper weight plate \n232\nA may be positioned above and/or in contact with the upper surface of the upper arm \n212\nA, and the lower weight plate \n232\nB may be positioned below and/or in contact with the lower surface of the lower arm \n212\nB.', 'As a result, a first recess \n234\nA and a second recess \n234\nB may be defined between the upper and lower weight plates \n232\nA, \n232\nB and laterally-outward from opposing sides of the weight arm \n210\n.', 'The upper and lower weight plates \n232\nA, \n232\nB may be coupled together via one or more fasteners (four are shown: \n236\n).', 'The fasteners \n236\n may be or include screws, bolts, or the like.', 'In addition, the upper and lower weight plates \n232\nA, \n232\nB may each define one or more openings extending at least partially therethrough.', 'For example, the upper weight plate \n232\nA may define two upper weight plate openings \n238\nA, \n239\nA that extend from the upper surface thereof to the lower surface thereof, and the two upper weight plate openings \n238\nA, \n239\nA may be positioned proximate to opposing lateral sides of the upper weight plate \n232\nA such that the weight arm \n210\n is configured to be positioned therebetween.', 'Similarly, the lower weight plate \n232\nB may define two lower weight plate openings (one is shown: \n238\nB) that extend from the upper surface thereof to the lower surface thereof, and the two lower weight plate openings \n238\nB may be positioned proximate to opposing lateral sides of the lower weight plate \n232\nB such that the weight arm \n210\n is configured to be positioned therebetween.', 'Each of the upper weight plate openings \n238\nA, \n239\nA in the upper weight plate \n232\nA may be configured to be aligned with a corresponding lower weight plate opening \n238\nB in the lower weight plate \n232\nB, and the weight arm \n210\n may not obstruct a line of sight through the aligned openings (e.g., openings \n238\nA, \n238\nB).', 'The position of the upper and lower weight plates \n232\nA, \n232\nB along the weight arm \n210\n may affect the amount (e.g., amplitude and/or force) of vibratory motion generated by the vibratory separator \n100\n.', 'For example, as the upper and lower weight plates \n232\nA, \n232\nB are moved toward a distal end \n216\n of the weight arm \n210\n, the amount of force generated by the vibratory motion increases.', 'Once the desired position of the upper and lower weight plates \n232\nA, \n232\nB is selected with respect to the weight arm \n210\n, the upper and lower weight plates \n232\nA, \n232\nB may be coupled to the weight arm \n210\n via a weight lock \n240\n.', 'More particularly, the weight lock \n240\n may be coupled to or integral with the upper and lower weight plates \n232\nA, \n232\nB and extend at least partially into and/or through one or more of the weight arm openings \n214\n in the weight arm \n210\n.', 'This may help to prevent the upper and lower weight plates \n232\nA, \n232\nB from moving longitudinally and/or laterally relative to the weight arm \n210\n.', 'However, as mentioned above, one or more portions of the first weight assembly \n110\nA may still move relative to one another.', 'To reduce or prevent such movement between the one or more portions of the first weight assembly \n110\nA, a lock assembly may be coupled to the first weight assembly \n110\nA.\n \nFIG.', '3\n is a perspective view of the first weight assembly \n110\nA with an exploded lock assembly \n300\n, according to one or more examples of the disclosure.', 'The lock assembly \n300\n may include a first spacer \n310\nA and a second spacer \n310\nB.', 'The first spacer \n310\nA may be configured to be inserted into the first recess \n234\nA, and the second spacer \n310\nB may be configured to be inserted into the second recess \n234\nB (not shown in \nFIG.', '3\n; see \nFIG.', '2\n).', 'The first spacer \n310\nA may define an opening (referred to as a first spacer opening) \n312\nA that extends at least partially therethrough.', 'Similarly, the second spacer \n310\nB may define an opening (referred to as a second spacer opening) \n312\nB that extends at least partially therethrough.', 'The first spacer \n310\nA may include a first fastener \n314\nA coupled thereto or integral therewith.', 'Similarly, the second spacer \n310\nB may include a second fastener \n314\nB coupled thereto or integral therewith.', 'The fasteners \n314\nA, \n314\nB may be or include threaded rods, bolts, or screws.', 'Central longitudinal axes through the openings \n312\nA, \n312\nB may be substantially perpendicular with central longitudinal axes through the fasteners \n314\nA, \n314\nB. Each fastener \n314\nA, \n314\nB may have a corresponding nut \n316\nA, \n316\nB that is configured to be coupled thereto.', 'The lock assembly \n300\n may also include a third fastener \n318\nA and a fourth fastener \n318\nB.', 'The fasteners \n318\nA, \n318\nB may be or include bolts or screws (e.g., hex head screws).', 'The third fastener \n318\nA may be configured to be inserted at least partially into the first spacer opening \n312\nA. Similarly, the fourth fastener \n318\nB may be configured to be inserted at least partially into the second spacer opening \n312', 'B. Each fastener \n318\nA, \n318\nB may have a corresponding nut \n320\nA, \n320\nB that is configured to be coupled thereto.', 'The lock assembly \n300\n may also include a latch \n330\n.', 'The latch \n330\n may include a first inner protrusion \n332\nA and a second inner protrusion \n332\nB.', 'The inner protrusions \n332\nA, \n332\nB may extend in a downward direction and be configured to be inserted at least partially into corresponding weight arm openings \n214\n in the weight arm \n210\n.', 'The lock assembly \n300\n may also include top central protrusion \n311\n defining a top central protrusion opening \n313\n.', 'The top central protrusion opening \n313\n may be configured to receive a central tab \n315\n, extending out of the upper weight plate \n232\nA in a direction parallel to the weight arm \n210\n.', 'The latch \n330\n may also include a first outer protrusion \n334\nA and a second outer protrusion \n334\nB.', 'The outer protrusions \n334\nA, \n334\nB may also extend in a downward direction and be positioned laterally-outward from the weight arm \n210\n.', 'The outer protrusions \n334\nA, \n334\nB may define openings (referred to as outer protrusion openings) \n336\nA, \n336\nB at least partially therethrough.', 'The first outer protrusion opening \n336\nA may be configured to be aligned with the first spacer \n310\nA, such that the first fastener \n314\nA may extend at least partially through the first outer protrusion opening \n336\nA. Similarly, the second outer protrusion opening \n336\nB may be configured to be aligned with the second spacer \n310\nB, such that the second fastener \n314\nB may extend at least partially through the second outer protrusion opening \n336\nB.\n \nFIG.', '4\n is a flowchart of a method \n400\n for assembling the vibratory separator \n100\n, according to one or more examples of the disclosure.', 'More particularly, the method \n400\n is directed to coupling the lock assembly \n300\n to the first weight assembly \n110\nA. An illustrative order of the method \n400\n is provided below; however, one or more portions of the method \n400\n may be performed in a different order, combined, or omitted.', 'To prevent redundancy, the method \n400\n is described with respect to the first weight assembly \n110\nA; however, as will be appreciated, the method \n400\n may also or instead be directed to coupling the lock assembly \n300\n (or a second lock assembly) to the second weight assembly \n110\nB.\n \nThe method \n400\n may include positioning the weight arm \n210\n at least partially between the upper and lower weight plates \n232\nA, \n232\nB, as at \n402\n.', 'As mentioned above, the longitudinal position of the upper and lower weight plates \n232\nA, \n232\nB along the weight arm \n210\n may affect the vibratory motion generated by the vibratory separator \n100\n.', 'The method \n400\n may also include coupling the upper and lower weight plates \n232\nA, \n232\nB to the weight arm \n210\n, as at \n404\n.', 'As mentioned above, the upper and lower weight plates \n232\nA, \n232\nB may be coupled to the weight arm \n210\n via the weight lock \n240\n.', 'The method \n400\n may also include positioning the spacers \n310\nA, \n310\nB at least partially within the recesses \n234\nA, \n234\nB between the upper and lower weight plates \n232\nA, \n232\nB, as at \n406\n.', 'More particularly, the first spacer \n310\nA may be positioned within the first recess \n234\nA such that the first spacer opening \n312\nA in the first spacer \n310\nA is aligned with the first upper weight plate opening \n238\nA in the upper weight plate \n232\nA and the first lower weight plate opening \n238\nB in the lower weight plate', '232\nB. Similarly, the second spacer \n310\nB may be positioned within the second recess \n234\nB such that the second spacer opening \n312\nB in the second spacer \n310\nB is aligned with the second upper weight plate opening \n239\nA in the upper weight plate \n232\nA and the second lower weight plate opening (not shown) in the lower weight plate', '232\nB.\n \nThe method \n400\n may also include inserting the fasteners \n318\nA, \n318\nB at least partially through the openings \n312\nA, \n312\nB in the spacers \n310\nA, \n310\nB, as at \n408\n.', 'More particularly, the fastener \n318\nA may be inserted through the first upper weight plate opening \n238\nA in the upper weight plate \n232\nA, the first spacer opening \n312\nA in the first spacer \n310\nA, and the first lower weight plate opening \n238\nB in the lower weight plate', '232\nB. Similarly, the fastener \n318\nB may be inserted through the second upper weight plate opening \n239\nA in the upper weight plate \n232\nA, the second spacer opening \n312\nB in the second spacer \n310\nB, and the second lower weight plate opening (not shown) in the lower weight plate \n232\nB.\n \nThe method \n400\n may also include coupling the nuts \n320\nA, \n320\nB to the fasteners \n318\nA, \n318\nB, as at \n410\n.', 'More particularly, the first nut \n320\nA may be coupled to the distal end of the fastener \n318\nA proximate to the lower surface of the lower weight plate', '232\nB. Similarly, the second nut \n320\nB may be coupled to the distal end of the fastener \n318\nB proximate to the lower surface of the lower weight plate \n232\nB.\n \nThe method \n400\n may also include positioning the latch \n330\n such that the fasteners \n314\nA, \n314\nB extend through the openings \n336\nA, \n336\nB of the latch \n330\n, as at \n412\n.', 'As shown, the first and second outer protrusion openings \n336\nA, \n336\nB may be elongated in a vertical direction.', 'The fastener \n314\nA may be inserted into the first outer protrusion opening \n336\nA proximate to a lower end of the first outer protrusion opening \n336\nA. Similarly, the fastener \n314\nB may be inserted into the second outer protrusion opening \n336\nB proximate to a lower end of the second outer protrusion opening \n336\nB.', 'The method \n400\n may also include moving the latch \n330\n in a first direction to align the inner protrusions \n332\nA, \n332\nB with two of the openings \n214\n in the weight arm \n210\n, as at \n414\n.', 'This may include moving the latch \n330\n longitudinally/horizontally with respect to central longitudinal axis \n211\n of the weight arm \n210\n and the fasteners \n314\nA, \n314\nB.', 'The fastener \n314\nA may remain extending through the first outer protrusion opening \n336\nA while the latch \n330\n moves in the first direction.', 'The fastener \n314\nB may also remain extending through the second outer protrusion opening \n336\nB while the latch \n330\n moves in the first direction.', 'The method \n400\n may also include moving the latch \n330\n in a second direction to insert the inner protrusions \n332\nA, \n332\nB through the two of the openings \n214\n in the weight arm \n210\n, as at \n416\n.', 'This may include moving the latch \n330\n vertically (e.g., downward) with respect to the weight arm \n210\n and the fasteners \n314\nA, \n314\nB.', 'The fastener \n314\nA may remain extending through first outer protrusion opening \n336\nA while the latch \n330\n moves in the second direction.', 'The fastener \n314\nB may also remain extending through second outer protrusion opening \n336\nB while the latch \n330\n moves in the second direction.', 'The first and second directions may be substantially perpendicular to one another.', 'As mentioned above, the first and second outer protrusion openings \n336\nA, \n336\nB in the latch \n330\n may be elongated in a vertical direction.', 'Thus, when the latch \n330\n moves downward, the fastener \n314\nA may move upward within the first outer protrusion opening \n336\nA, and the fastener \n314\nB may move upward within the second outer protrusion opening \n336\nB.\n \nThe method \n400\n may also include coupling the nuts \n316\nA, \n316\nB to the fasteners \n314\nA, \n314\nB, as at \n418\n.', 'More particularly, the first nut \n316\nA may be coupled to the distal end of the fastener \n314\nA proximate to an outer surface of the latch \n330\n.', 'Similarly, the second nut \n316\nB may be coupled to the distal end of the fastener \n314\nB proximate to the outer surface of the latch \n330\n.', 'At this point, latch \n330\n may be positioned and secured between the first and second nuts \n316\nA, \n316\nB on one side, and the upper and lower weight plates \n232\nA, \n232\nB and the first and second spacers \n310\nA, \n310\nB on the other side.', 'Thus, the lock assembly \n300\n is coupled to the first weight assembly \n110\nA, which is shown in \nFIG.', '5\n.', 'Coupling the lock assembly \n300\n to the first weight assembly \n110\nA may help to reduce or prevent movement between two or more portions of the first weight assembly \n110\nA.', 'For example, this may help to reduce or prevent movement between the upper weight plate \n232\nA and the weight arm \n210\n, between the upper weight plate \n232\nA and the hub \n220\n, between the lower weight plate \n232\nB and the weight arm \n210\n, between the lower weight plate \n232\nB and the hub \n220\n, or a combination thereof.', 'Reducing or preventing movement between two or more of the portions of the first weight assembly \n110\nA may reduce or prevent the likelihood that a spark will be generated due to such movement.', 'In a first example, a lock assembly \n300\n for a vibratory separator \n100\n is disclosed.', 'The lock assembly \n300\n includes a latch \n330\n.', 'The latch \n330\n includes a first inner protrusion \n332\nA and a first outer protrusion \n334\nA.', 'The first outer protrusion \n334\nA defines a first outer protrusion opening \n336\nA.', 'The lock assembly \n300\n also includes a first spacer \n310\nA that includes a first fastener \n314\nA that is configured to be inserted into the first outer protrusion opening \n336\nA.', 'In a second example that may be independent from or build upon example 1, the first inner protrusion \n332\nA is configured to be inserted into a first weight arm opening \n214\n in a weight arm \n210\n.', 'In a third example that may be independent from or build upon the example 1 and/or example 2, the first outer protrusion \n334\nA is configured to be positioned laterally-offset from or laterally-abutting the weight arm \n210\n when the first inner protrusion \n332\nA is inserted into the first weight arm opening \n214\n.', 'In a fourth example that may be independent from or build upon any combination of examples 1-3, the latch \n330\n further includes a second inner protrusion \n332\nB.', 'The second inner protrusion \n332\nB is configured to be inserted into a second weight arm opening \n214\n in the weight arm \n210\n.', 'The latch \n330\n also includes a second outer protrusion \n334\nB.', 'The first inner protrusion \n332\nA and the second inner protrusion \n332\nB are positioned between the first outer protrusion \n334\nA and the second outer protrusion \n334\nB.', 'The weight arm \n210\n is configured to be positioned between the first outer protrusion \n334\nA and the second outer protrusion \n334\nB when the second inner protrusion \n332\nB is inserted into the second weight arm opening \n214\n.', 'The second outer protrusion \n334\nB defines a second outer protrusion opening \n336\nB.\n \nIn a fifth example that may be independent from or build upon any combination of examples 1-4, the lock assembly also includes a second spacer \n310\nB including a second fastener \n314\nB that is configured to be inserted into the second outer protrusion opening \n336\nB.\n \nIn a sixth example that may be independent from or build upon any combination of examples 1-5, the first outer protrusion opening \n336\nA is elongated to allow the first fastener \n314\nA to move (e.g., vertically) within first outer protrusion opening \n336\nA.', 'In a seventh example that may be independent from or build upon any combination of examples 1-6, the first spacer \n310\nA defines a first spacer opening \n312\nA that is substantially perpendicular to the first fastener \n314\nA.', 'In an eighth example that may be independent from or build upon any combination of examples 1-7, the lock assembly \n300\n includes a third fastener \n318\nA that is configured to be inserted into the first spacer opening \n312\nA, such that the third fastener \n318\nA is substantially perpendicular to the first fastener \n314\nA.', 'In a ninth example that may be independent from or build upon any combination of examples 1-8, a system is also disclosed.', 'The system includes a weight assembly \n110\nA.', 'The weight assembly \n110\nA includes a weight arm \n210\n defining a first weight arm opening \n214\n.', 'The weight assembly \n110\nA also includes an upper weight plate \n232\nA and a lower weight plate \n232\nB.', 'The weight arm \n210\n is positioned at least partially between the upper weight plate \n232\nA and the lower weight plate \n232\nB.', 'The system also includes a lock assembly \n300\n.', 'The lock assembly \n300\n includes a latch \n330\n.', 'The latch \n330\n includes a first inner protrusion \n332\nA configured to be inserted into the first weight arm opening \n214\n.', 'The latch \n330\n also includes a first outer protrusion \n334\nA that defines a first outer protrusion opening \n336\nA.', 'The lock assembly \n300\n also includes a first spacer', '310\nA configured to be positioned within a first recess \n234\nA defined at least partially between the upper weight plate \n232\nA and the lower weight plate \n232', 'B. The first spacer \n310\nA includes a first fastener \n314\nA that is configured to be inserted into the first outer protrusion opening \n336\nA.', 'In a tenth example that may be independent from or build upon any combination of examples 1-9, the first outer protrusion \n334\nA is configured to be positioned laterally-offset from or laterally-abutting the weight arm \n210\n when the first inner protrusion \n332\nA is inserted into the first weight arm opening \n214\n.', 'In an eleventh example that may be independent from or build upon any combination of examples 1-10, the first outer protrusion opening \n336\nA is elongated to allow the first fastener \n314\nA to move within the first outer protrusion opening \n336\nA.', 'In a twelfth example that may be independent from or build upon any combination of examples 1-11, the first spacer \n310\nA defines a first spacer opening \n312\nA that is substantially perpendicular to the first fastener \n314\nA.', 'The lock assembly \n300\n also includes a third fastener \n318\nA that is configured to be inserted into the first spacer opening \n312\nA, such that the third fastener \n318\nA is substantially perpendicular to the first fastener \n314\nA.', 'In a thirteenth example that may be independent from or build upon any combination of examples 1-12, the latch \n330\n further includes a second inner protrusion \n332', 'B.', 'The second inner protrusion \n332\nB is configured to be inserted into a second weight arm opening \n214\n in the weight arm \n210\n.', 'The latch \n330\n further includes a second outer protrusion \n334\nB.', 'The first inner protrusion \n332\nA and the second inner protrusion \n332\nB are positioned between the first outer protrusion \n334\nA and the second outer protrusion \n334\nB.', 'The weight arm \n210\n is positioned between the first outer protrusion \n334\nA and the second outer protrusion \n334\nB when the second inner protrusion \n332\nB is inserted into the second weight arm opening \n214\n.', 'The second outer protrusion \n334\nB defines a second outer protrusion opening \n336\nB.\n \nIn a fourteenth example that may be independent from or build upon any combination of examples 1-13, a method is also disclosed.', 'The method includes positioning a first spacer \n310\nA at least partially within a first recess \n234\nA defined between an upper weight plate \n232\nA and a lower weight plate \n232', 'B.', 'The first spacer \n310\nA includes a first fastener \n314\nA.', 'The method also includes inserting a third fastener \n318\nA at least partially through a first spacer opening \n312\nA in the first spacer \n310\nA.', 'The method also includes positioning a latch \n330\n such that the first fastener \n314\nA extends through a first outer protrusion opening \n336\nA in the latch \n330\n.', 'The latch \n330\n includes a first outer protrusion \n334\nA that defines the first outer protrusion opening \n336\nA.', 'The method also includes moving the latch \n330\n in a first direction to align a first inner protrusion \n332\nA of the latch \n330\n with a first weight arm opening \n214\n in a weight arm \n210\n.', 'The weight arm \n210\n is positioned at least partially between the upper weight plate \n232\nA and the lower weight plate \n232\nB.', 'The method also includes moving the latch \n330\n in a second direction to insert the first inner protrusion \n332\nA at least partially into the first weight arm opening \n214\n.', 'In a fifteenth example that may be independent from or build upon any combination of examples 1-14, the upper weight plate \n232\nA defines an upper weight plate opening \n238\nA. The lower weight plate \n232\nB defines a lower weight plate opening \n238\nB. Positioning the first spacer \n310\nA comprises aligning the first spacer opening \n312\nA with the upper weight plate opening \n238\nA and the lower weight plate opening \n238\nB.\n \nIn a sixteenth example that may be independent from or build upon any combination of examples 1-15, inserting the third fastener', '318\nA includes inserting the third fastener \n318\nA through the upper weight plate opening \n238\nA, the first spacer opening \n312\nA, and the lower weight plate opening \n238\nB.\n \nIn a seventeenth example that may be independent from or build upon any combination of examples 1-16, the third fastener \n318\nA is substantially perpendicular to the first fastener \n314\nA when the third fastener \n318\nA is inserted.', 'In an eighteenth example that may be independent from or build upon any combination of examples 1-17, the first recess \n234\nA is defined at least partially by the upper weight plate \n232\nA, the lower weight plate \n232\nB, and the weight arm \n210\n.', 'In a nineteenth example that may be independent from or build upon any combination of examples 1-18, the first direction is substantially parallel to a central longitudinal axis \n211\n through the weight arm \n210\n, and the second direction is substantially perpendicular to the first direction.', 'In a twentieth example that may be independent from or build upon any combination of examples 1-19, the first fastener \n314\nA remains extending through the first outer protrusion opening \n336\nA while the latch \n330\n is moved in the first direction and the second direction.', 'The foregoing description, for purposes of explanation, used specific nomenclature to provide a thorough understanding of the disclosure.', 'However, it will be apparent to one skilled in the art that the specific details are not required in order to practice the systems and methods described herein.', 'The foregoing descriptions of specific examples are presented for purposes of illustration and description.', 'They are not intended to be exhaustive of or to limit this disclosure to the precise forms described.', 'Many modifications and variations are possible in view of the above teachings.', 'The examples are shown and described in order to best explain the principles of this disclosure and practical applications, to thereby enable others skilled in the art to best utilize this disclosure and various examples with various modifications as are suited to the particular use contemplated.', 'It is intended that the scope of this disclosure be defined by the claims and their equivalents below.']

['1.', 'A lock assembly for a vibratory separator, comprising:\na latch comprising: a first inner protrusion; and a first outer protrusion, wherein the first outer protrusion defines a first outer protrusion opening; and\na first spacer comprising a first fastener that is configured to be inserted into the first outer protrusion opening, wherein the first outer protrusion opening is an elongated opening extending in a direction perpendicular to the first fastener.', '2.', 'The lock assembly of claim 1, wherein the first inner protrusion is configured to be inserted into a first weight arm opening in a weight arm.', '3.', 'The lock assembly of claim 2, wherein the first outer protrusion is configured to be positioned laterally-offset from or laterally-abutting the weight arm when the first inner protrusion is inserted into the first weight arm opening.', '4.', 'The lock assembly of claim 3, wherein the latch further comprises:\na second inner protrusion, wherein the second inner protrusion is configured to be inserted into a second weight arm opening in the weight arm; and\na second outer protrusion, wherein the first inner protrusion and the second inner protrusion are positioned between the first outer protrusion and the second outer protrusion, wherein the weight arm is configured to be positioned between the first outer protrusion and the second outer protrusion when the second inner protrusion is inserted into the second weight arm opening, and wherein the second outer protrusion defines a second outer protrusion opening.', '5.', 'The lock assembly of claim 4, further comprising a second spacer comprising a second fastener that is configured to be inserted into the second outer protrusion opening, wherein the second outer protrusion opening is an elongated opening extending in a direction perpendicular to the second fastener.', '6.', 'The lock assembly of claim 1, wherein the first spacer defines a first spacer opening that is substantially perpendicular to the first fastener.', '7.', 'The lock assembly of claim 6, further comprising a second third fastener that is configured to be inserted into the first spacer opening, such that the first fastener is substantially perpendicular to the second third fastener.\n\n\n\n\n\n\n8.', 'The lock assembly of claim 1, wherein the first spacer comprises a rectangular body configured to be positioned within a first recess defined at least partially between an upper weight plate and a lower weight plate, wherein the first spacer further comprises a cylindrical fastener protruding from the rectangular body.', '9.', 'The lock assembly of claim 1, wherein the latch further comprises a top central protrusion defining a top central protrusion opening, wherein the top central protrusion opening is configured to receive a central tab attached to an upper weight plate.', '10.', 'A system, comprising:\na weight assembly comprising: a weight arm defining a first weight arm opening; an upper weight plate; and a lower weight plate, wherein the weight arm is positioned at least partially between the upper weight plate and the lower weight plate; and\na lock assembly comprising: a latch comprising: a first inner protrusion configured to be inserted into the first weight arm opening; and a first outer protrusion that defines a first outer protrusion opening; and a first spacer configured to be positioned within a first recess defined at least partially between the upper weight plate and the lower weight plate, wherein the first spacer comprises a first fastener that is configured to be inserted into the first outer protrusion opening, wherein the first outer protrusion opening is an elongated opening extending in a direction perpendicular to the first fastener.', '11.', 'The system of claim 10, wherein the first outer protrusion is configured to be positioned laterally-offset from or laterally-abutting the weight arm when the first inner protrusion is inserted into the first weight arm opening.', '12.', 'The system of claim 10, wherein the first spacer defines a first spacer opening that is substantially perpendicular to the first fastener, and wherein the lock assembly further comprises a third fastener that is configured to be inserted into the first spacer opening, such that the first fastener is substantially perpendicular to the third fastener.', '13.', 'The system of claim 10, wherein the latch further comprises:\na second inner protrusion, wherein the second inner protrusion is configured to be inserted into a second weight arm opening in the weight arm; and\na second outer protrusion, wherein the first inner protrusion and the second inner protrusion are positioned between the first outer protrusion and the second outer protrusion, wherein the weight arm is positioned between the first outer protrusion and the second outer protrusion when the second inner protrusion is inserted into the second weight arm opening, and wherein the second outer protrusion defines a second outer protrusion opening.', '14.', 'A method, comprising:\npositioning a first spacer at least partially within a first recess defined between an upper weight plate and a lower weight plate, wherein the first spacer comprises a first fastener;\ninserting a third fastener at least partially through a first spacer opening in the first spacer;\npositioning a latch such that the first fastener extends through a first outer protrusion opening in the latch, wherein the latch comprises a first outer protrusion that defines the first outer protrusion opening and the first outer protrusion opening is an elongated opening extending in a direction perpendicular to the first fastener;\nmoving the latch in a first direction to align a first inner protrusion of the latch with a first weight arm opening in a weight arm, wherein the weight arm is positioned at least partially between the upper weight plate and the lower weight plate; and\nmoving the latch in a second direction to insert the first inner protrusion at least partially into the first weight arm opening.', '15.', 'The method of claim 14, wherein the upper weight plate defines an upper weight plate opening, wherein the lower weight plate defines a lower weight plate opening, and wherein positioning the first spacer comprises aligning the first spacer opening with the upper weight plate opening and the lower weight plate opening.\n\n\n\n\n\n\n16.', 'The method of claim 15, wherein inserting the third fastener comprises inserting the third fastener through the upper weight plate opening, the first spacer opening, and the lower weight plate opening.\n\n\n\n\n\n\n17.', 'The method of claim 16, wherein the third fastener is substantially perpendicular to the first fastener when the third fastener is inserted.', '18.', 'The method of claim 14, wherein the first recess is defined at least partially by the upper weight plate, the lower weight plate, and the weight arm.\n\n\n\n\n\n\n19.', 'The method of claim 14, wherein the first direction is substantially parallel to a central longitudinal axis through the weight arm, and wherein the second direction is substantially perpendicular to the first direction.', '20.', 'The method of claim 14, wherein the first fastener remains extending through the first outer protrusion opening while the latch is moved in the first direction and the second direction.']

['FIG.', '1 is a perspective view of a vibratory separator, according to one or more examples of the disclosure.', '; FIG.', '2 is a perspective view of a motor and a weight assembly of the vibratory separator of FIG.', '1, with the remainder of the vibratory separator removed for clarity, according to one or more examples of the disclosure.', '; FIG.', '3 is a perspective view of the weight assembly of FIG.', '2 with an exploded lock assembly, according to one or more examples of the disclosure.', '; FIG.', '4 is a flowchart of a method for assembling the vibratory separator, according to one or more examples of the disclosure.', '; FIG.', '5 is a perspective view of the weight assembly with the lock assembly coupled thereto, according to one or more examples of the disclosure.', '; FIG. 1 is a perspective view of a vibratory separator 100, according to one or more examples of the disclosure.', 'The vibratory separator 100 may be a vibratory shaker, such as a shale shaker, used in the oilfield industry to process wellbore fluids.', 'The vibratory separator 100 may also or instead be used in the food industry, cleaning industry, waste water treatment industry, and others.', 'As shown, the vibratory separator 100 may include a first (e.g., upper) weight assembly 110A and a second (e.g., lower) weight assembly 110B.', 'The first and second weight assemblies 110A, 110B may be the same or may be different from one another.; FIG.', '2 is a perspective view of a motor 130 of the vibratory separator 100 with the first weight assembly 110A coupled thereto, according to one or more examples of the disclosure.', 'The remainder of the vibratory separator 100 shown in FIG. 1 has been removed for clarity.; FIG.', '3 is a perspective view of the first weight assembly 110A with an exploded lock assembly 300, according to one or more examples of the disclosure.', 'The lock assembly 300 may include a first spacer 310A and a second spacer 310B.', 'The first spacer 310A may be configured to be inserted into the first recess 234A, and the second spacer 310B may be configured to be inserted into the second recess 234B (not shown in FIG.', '3; see FIG. 2).', 'The first spacer 310A may define an opening (referred to as a first spacer opening) 312A that extends at least partially therethrough.', 'Similarly, the second spacer 310B may define an opening (referred to as a second spacer opening) 312B that extends at least partially therethrough.', 'The first spacer 310A may include a first fastener 314A coupled thereto or integral therewith.', 'Similarly, the second spacer 310B may include a second fastener 314B coupled thereto or integral therewith.', 'The fasteners 314A, 314B may be or include threaded rods, bolts, or screws.', 'Central longitudinal axes through the openings 312A, 312B may be substantially perpendicular with central longitudinal axes through the fasteners 314A, 314B. Each fastener 314A, 314B may have a corresponding nut 316A, 316B that is configured to be coupled thereto.; FIG.', '4 is a flowchart of a method 400 for assembling the vibratory separator 100, according to one or more examples of the disclosure.', 'More particularly, the method 400 is directed to coupling the lock assembly 300 to the first weight assembly 110A.', 'An illustrative order of the method 400 is provided below; however, one or more portions of the method 400 may be performed in a different order, combined, or omitted.', 'To prevent redundancy, the method 400 is described with respect to the first weight assembly 110A; however, as will be appreciated, the method 400 may also or instead be directed to coupling the lock assembly 300 (or a second lock assembly) to the second weight assembly 110B.']

US11892584

Marine to borehole electromagnetic survey

Nov 18, 2018

Alberto Marsala, Nestor Herman Cuevas Maldonado, Andrea Lovatini, Mohammed Badri

SCHLUMBERGER TECHNOLOGY CORPORATION

Kong et al., “Casing effects in the sea-to-borehole electromagnetic method”, Geophysics, vol. 74, No. 5, Sep.-Oct. 2009, pp. F77-F87.; Marsala et al., “3D inversion practice for crosswell electromagnetic surveys in horizontal wells in Saudi Arabia”, 2015 SEG Annual meeting proceedings, pp. 869-873.; Marsala et al., “Crosswell Electromagnetic Tomography: Resistivity Mapping to Interwell Fluid Distribution”, IPTC 12229, International Petroleum Technology Conference, Session: Meeting the Energy Needs of a Growing World Economy, 6 pages.; Search Report and Written Opinion of International Patent Application No. PCT/US2018/062152 dated Jul. 30, 2019; 14 pages.; Wilt et al. , “Crosswell Electromagnetic Tomography in Saudi Arabia—From Field Surveys to Resistivity Mapping”, 70th EAGE Conference and Exhibition incorporating SPE EUROPEC 2008, Session: Reservoir Monitoring and Management II, 5 pages.; Marsala et al., “Fluid Distribution Inter-Well Mapping in Multiple Reservoirs by Innovative Borehole to Surface Electromagnetic: Survey Design and Field Acquisition”, IPTC 17045, International Petroleum Technology Conference, 2013, 4 pages.; Marsala et al., “First Pilot of Borehole to Surface Electromagnetic in Saudi Arabia—A New Technology to Enhance Reservoir Mapping & Monitoring”, 73rd EAGE Conference and Exhibition incorporating SPE EUROPEC 2011, 5 pages.; Ali et al., “Constraining Interwell Water Flood Imaging with Geology and Petrophysics: An example from the Middle East”, SPE 120558, 2009 SPE Middle East Oil and Gas Show and Conference, 11 pages.; Wilt et al., “Crosswell Electromagnetic Tomography: System Design Considerations and Field Results”, Geophysics, vol. 60, No. 3, May-Jun. 1995, pp. 871-885.; Wilt et al., “Using Crosswell Electromagnetic to Map Water Saturation and Formation Structure at Lost Hills”, 2001, SPE 68802, Society of Petroleum Engineers, 6 pages.; Liang-Jun et al., “Continuous TDEM for monitoring shale hydraulic fracturing”, Applied Geophysics, Chinese Geophysical Society, Heidelberg, vol. 15, No. 1, May 9, 2018, pp. 26-34.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2018/062152 dated Jun. 3, 2021, 10 pages.

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2010123696; October 2010; WO

['Methods of marine to borehole measurement may include dispersing one or more borehole receivers in one or more boreholes; distributing one or more marine receivers in marine water at a seabed; immersing an electromagnetic dipole source in the marine water above the seabed; energizing the electromagnetic dipole source; measuring one or more borehole signal measurements using the one or more borehole receivers and one or more seabed signal measurements using the one or more marine receivers; and determining a three-dimensional property distribution of a reservoir of interest by processing the one or more borehole signal measurements and the one or more seabed signal measurements.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThis disclosure relates generally to oil and gas exploration and/or monitoring systems and more specifically to three-dimensional imaging of the earth subsurface.', 'In the field of petroleum exploration and production the percentage volume of each fluid (oil, water, and gas) in the pore space of reservoir rock is referred to as saturation of each fluid phase.', 'In the exploration phase, saturation provides an indication of the economic potential of a reservoir.', 'When the reservoir enters production, saturation may also be monitored to gauge the production efficiency as a function of time during the life of the reservoir.', 'The measurement and use of fluid saturation further continues during the enhanced recovery period.', 'During the production phase, the local permeability variations can cause non-uniform saturation distribution and, in some situations, may cause large sections of reservoir to be bypassed or at least less efficiently produced.', 'To map such saturation distributions deep looking techniques, especially techniques based on electromagnetic (EM) techniques, are often used to measure fluid saturation at depths of up to a few kilometers away from the borehole.', 'Such EM techniques are collectively called Deep EM.', 'Increasing recovery factors, and the associated economic gains, requires an understanding of the spatial distribution and flow dynamics of various fluid interfaces.', 'This understanding is an important factor in supporting reservoir management practices, production optimization, and Enhanced Oil Recovery (EOR) processes.', 'In this context, Deep EM can provide spatial information regarding electrical resistivity distributions within the reservoir, which may then be used to infer fluid saturation at various locations.', 'Crosswell EM is one of the Deep EM techniques that are offered as a commercial service by SCHLUMBERGER™.', 'The measurement is made by placing an EM source (also called a transmitter antenna) in a primary well and a receiver antenna or array of antennas in one or more secondary wells.', 'The receiver array may include multiple receivers and measure the response of earth formation energized by the EM source at a range of locations simultaneously.', 'The measurement starts with placing the source at a location in the primary well and energizing it.', 'At each source location, the receiver or receiver array in the secondary wells is moved to sequentially different depths and data points are collected.', 'The source is then moved to the next location within the primary well and data collection by the receiver or receiver array is repeated.', 'The distance between the primary and secondary wells is often close enough for the received signal to be measurable in a reasonable time.', 'In most cases, this distance is up to about 2 km.', 'The measurement principle is described, for example, in “Crosshole electromagnetic tomography: System design considerations and field results,” Society of Exploration Geophysics, Vol. 60, No. 3, 1995.', 'An example apparatus for performing Crosswell EM is described in co-owned U.S. Pat.', 'No. 6,393,363, entitled “A Method and Apparatus for The Measurement of The Electrical Resistivity of Geologic Formations Employing Modeling Data”, the contents of which are herein incorporated by reference.', 'In the application, the measurement results are inverted to obtain a resistivity image of the space between the two wells which is further processed to convert resistivity to saturation at each point, as described in “Using Crosswell Electromagnetic to Map Water Saturation and Formation Structure at Lost Hills”, by M. Wilt et al., 2001 (SPE paper 68802).', 'The authors further describe a qualitative method of estimating the change in water saturation from time-lapse Crosswell EM data by repeating the measurements after the reservoir has been producing for a period of time.', 'In Crosswell EM methods, downhole magnetic sources directly energize the reservoir fluids between a primary well containing the EM source and one or more secondary wells containing receiving antennas.', 'The earth response measured between the primary and secondary wells enables the generation of 2D tomographic images of the electrical resistivity distributions, which are generally better resolved than those obtained from surface-based methods.', 'However, the deployment of Crosswell EM measurements is not always feasible, as it depends on the availability of at least two wells, with at least one of them open or fiber glass completed in order to obtain suitable measurement signal to noise ratio (SNR).', 'An extension of Crosswell EM involves the use of a single well technique in which the source is deployed at reservoir depth, while the receiver antenna is located at the surface.', 'Single well Deep EM methods yield three-dimensional (3D) lateral information about the subsurface strata.', 'In this technique, the receivers are not confined to the limited space available in a borehole and they can be deployed over extensive areas on the surface to track the distribution of the oil/water in the reservoir away from the borehole.', 'Previous works have shown that energizing a vertical source extending from the surface down to reservoir depth can provide a useful response in a borehole to surface configuration.', 'In this approach, the source is in the borehole, while the receivers are on the surface to gather EM energy from the borehole.', 'In a borehole to surface configuration, the receivers could be deployed over vast areas, which may provide a description of reservoir properties leading from the borehole on a deeper scale than is possible with Crosswell EM.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'In one aspect, methods in accordance with the present disclosure may include dispersing one or more borehole receivers in one or more boreholes: distributing one or more marine receivers in marine water at a seabed; immersing an electromagnetic dipole source in the marine water above the seabed; energizing the electromagnetic dipole source; measuring one or more borehole signal measurements using the one or more borehole receivers and one or more seabed signal measurements using the one or more marine receivers; and determining a three-dimensional property distribution of a reservoir of interest by processing the one or more borehole signal measurements and the one or more seabed signal measurements.', 'In another aspect, apparatuses in accordance with the present disclosure may include a marine electromagnetic source; one or more borehole receivers dispersed in one or more borehole locations; one or more marine receivers dispersed in one or more seabed locations; and a processor configured to calculate a three-dimensional property distribution of a reservoir of interest from data received by the one or more borehole receivers and the one or more marine receivers.', 'In another aspect, methods in accordance with the present disclosure may include providing marine to borehole measurements comprising borehole signal measurements with corresponding depths and seabed signal measurements with corresponding seabed coordinates; using the seabed signal measurements and an inversion to infer electromagnetic parameters of earth subsurface strata intervening between seabed and a reservoir of interest; inverting the borehole signal measurements and the electromagnetic parameters of earth subsurface strata, wherein the electromagnetic parameters of earth subsurface strata are kept constant; and inferring a three-dimensional property distribution of the reservoir of interest from the inverted borehole signal measurements.', 'Other aspects and advantages of the claimed subject matter will be apparent from the following description and the appended claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is further described in the detailed description which follows, in reference to the noted plurality of drawings by way of non-limiting examples of the present disclosure, in which like reference numerals represent similar parts throughout the several views of the drawings, and wherein:\n \nFIG.', '1\n is a projected view of a marine layer and an apparatus to perform the marine to borehole measurement in accordance with embodiments of the present disclosure;\n \nFIG.', '2\n is a cross-sectional view of the earth layer showing how conventional well logs, seismic, and logs that are run in an adjacent well are used to estimate initial values for the electromagnetic parameters and geometry of earth layers in accordance with embodiments of the present disclosure;\n \nFIG.', '3\nA\n is a drawing of a two-dimensional plane within the marine water in which the electromagnetic source is transported in a linear path in accordance with embodiments of the present disclosure;\n \nFIG.', '3\nB\n is a drawing of a two-dimensional plane within the marine water in which the electromagnetic source is transported in a spiral path in accordance with embodiments of the present disclosure;\n \nFIG.', '4\n is a workflow showing a first and second stage inversion for seabed signal and borehole signal in accordance with embodiments of the present disclosure;\n \nFIG.', '5\nA\n is a schematic drawing of single axis electric dipole antenna to be used as a transmitter (source) in marine to borehole (MTB) measurements in accordance with embodiments of the present disclosure;\n \nFIG.', '5\nB\n is a schematic drawing of a bi-axial electric dipole antenna to be used as a transmitter (source) in MTB measurements in accordance with embodiments of the present disclosure;\n \nFIG.', '5\nC\n is a schematic drawing of tri-axial electric dipole antenna to be used as a transmitter (source) in MTB measurements in accordance with embodiments of the present disclosure; and\n \nFIG.', '6\n is a schematic drawing of a tri-axial magnetic dipole antenna to be used as a source in MTB measurements in accordance with embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'The particulars shown herein are by way of example and for purposes of illustrative discussion of the embodiments of the present disclosure only and are presented in the cause of providing what is believed to be the most useful and readily understood description of the principles and conceptual aspects of the present disclosure.', 'In this regard, no attempt is made to show structural details in more detail than is necessary for the fundamental understanding of the present disclosure, the description taken with the drawings making apparent to those skilled in the art how the several forms of the present disclosure may be embodied in practice.', 'Furthermore, like reference numbers and designations in the various drawings indicate like elements.', 'In one aspect, embodiments of the present disclosure relate to the acquisition and processing of marine to borehole (MTB) electromagnetic data.', 'In another aspect, embodiments of the present disclosure relate to equipment that may be used to acquire such data.', 'In one or more embodiments, MTB EM emitted from one or more submersible electromagnetic sources deployed in a marine environment and one or more receivers positioned in a borehole, terrestrial surface, or marine surface.', 'In one or more embodiments, the receivers may gather data for formation regions between the EM source and the respective receivers.', 'For example, marine receivers may be positioned at the sea floor to gather data pertinent to the subsurface regions of interest intervening between the marine layer and the EM source.', 'Because the EM waves propagate from marine environment to well borehole, where borehole receivers are located, the method is referred to as marine to borehole (MTB).', 'FIG.', '1\n is a projected view of a marine wellbore operation and an apparatus to perform the marine to borehole measurement.', 'The marine water environment \n120\n is shown in which an offshore platform \n110\n is positioned for oil exploration, reservoir development and petroleum production.', 'Multiple wells \n104\n and \n106\n have been drilled from the platform \n110\n into the earth, traversing the subsurface strata \n122\n, \n124\n, \n126\n, and', '128\n.', 'Well \n104\n passes through subsurface strata \n122\n, \n124\n, and \n126\n to reach the reservoir of interest \n112\n.', 'The earth above the reservoir \n112\n up to the marine water environment \n120\n may be referred to as overburden.', 'The overburden may include many geological formations and is not limited by the four subsurface strata shown in \nFIG. \n1\n.', 'Well \n106\n extends from platform \n110\n and traverses reservoir \n114\n.', 'The wells \n104\n and \n106\n, being drilled from the same platform, are near to each other before they change direction towards different reservoirs.', 'It is worth noting that \nFIG.', '1\n is a cross sectional view of several subsurface strata and is not reflective of the geometry outside this plane.', 'In general, both the geometry and formation properties may vary in three dimensions from point to point in each stratum.', 'The reservoir of interest \n112\n, as well as many earth subsurface strata, have complex distributions of petrophysical, and electromagnetic properties.', 'Reasons for the variation may include heterogeneity in factors such as porosity, fluid permeability, and fluid saturation.', 'As such, reservoirs such as \n112\n may be considered a 3D distribution of petrophysical and electromagnetic parameters.', 'In one aspect, embodiments of the present disclosure are directed to characterizing the complex properties of a reservoir in a 3D property image.', 'Returning to \nFIG.', '1\n, a marine submersible EM source \n130\n (also referred to as transmitter) is shown immersed in the marine layer \n120\n.', 'The source \n130\n is attached to and is towed by a marine vessel \n132\n through a cable \n134\n.', 'In some embodiments, the marine EM source \n130\n may be electrically and mechanically connected to a marine vessel \n132\n, where the marine vessel is equipped to excite and drag the electromagnetic source immersed in marine water.', 'In addition to mechanical towing, the cable \n134\n provides electrical connections to the source \n130\n, which may include power delivery and any diagnostics and command lines needed to communicate and operate the source \n130\n.', 'The source \n130\n may be immersed at some depth below the surface of marine water layer \n120\n.', 'Deployment of marine sources and receivers has been used successfully to monitor and characterize shallower reservoirs located below the marine water.', 'However, as the depth of target reservoir of interest increases, the spatial resolution of measurement decreases so that marine measurements alone are not suitable for determining the 3D property image of deeper lying reservoirs.', 'The resolution loss is largely attributed to the diffusive behavior of EM fields at lower frequencies (1,000 Hz) that are normally used for Deep EM.\n \nAlso shown in \nFIG.', '1\n are borehole receiver arrays \n144\n located in wells \n104\n and \n106\n respectively.', 'Borehole receiver arrays \n144\n are composed of multiple receiver antennas capable of measuring the EM signal at its location.', 'In one or more embodiments, the number of receiver antennas and the spacing between them in the array may vary and may be chosen such that the length of array covers at least a part of the borehole passing though the reservoir of interest.', 'In some embodiments, the length of receiver array is long enough to extend passed the reservoir and span a part of the adjacent earth subsurface strata.', 'For thinner reservoirs, the length of the receiver array may be configured to be relatively shorter by reducing the number of receiver antennas or by positioning the antennas closer together in the array.', 'During measurement, source \n130\n is energized and the borehole receiver arrays \n144\n measure the EM signal at the position of each receiver antenna within the array generating one or more data points.', 'In one or more embodiments, the number of data points may be increased by increasing the number of receiver antennas in the array.', 'Additionally, one or more marine receiver arrays \n148\n may be deployed on the bottom of marine water \n120\n, on top of the overburden.', 'When the source \n130\n is energized, each marine receiver array \n148\n measures an EM signal induced in the earth and available at the location the receiver is deployed.', 'As discussed below, these seabed signals received by the marine receiver arrays \n148\n are used to calculate electromagnetic properties of earth strata in the overburden.', 'In one or more embodiments, the positions of the borehole and marine receivers are selected based on pre-operation modeling studies.', 'In some embodiments, pre-operation modeling studies may be performed prior to the deployment and measurement operation.', 'In one or more embodiments, borehole receiver arrays in accordance with the present disclosure may be deployed within a well using different conveyance techniques that may include wireline, slick line, coil tubing, drill collar, downhole tractor, and the like.', 'If a well is substantially vertical, for example, wireline may be used as a mode of conveyance to deliver the borehole receiver array(s) to a proper depth in the well, in addition to providing power, communication, and control lines that may be used to initiate measurement and telemeter the measured data to the surface location.', 'In some embodiments, particularly where a well is highly deviated and horizontal wells, borehole receivers may be emplaced by wireline, slick line, coil tubing, drill collar, or downhole tractor.', 'In some embodiments, receiver arrays may be equipped to operate using battery power and store data locally, such as when there is no direct power or communication from the surface.', 'In one or more embodiments, marine receiver arrays \n148\n may be deployed to the bottom of the marine water layer \n120\n using the force of gravity.', 'Marine receivers in accordance with the present disclosure may be connected to the marine vessel \n132\n by electrically insulated wires for power, communication, and data transfer.', 'In some embodiments, marine receiver arrays may be equipped to operate using battery power and store data locally, such as when there is no direct power or communication from the surface.', 'Once the source and all receiver arrays are in place the measurement is performed.', 'The EM source \n130\n is energized by providing EM current through the cable \n134\n causing it to radiate EM waves.', 'In one or more embodiments, the EM current may be in a frequency domain or time domain.', 'The EM waves propagate through the marine layer and earth medium presenting a signal at all locations.', 'In downhole locations, in one or multiple boreholes (\n104\n and \n106\n, for example), the borehole receiver arrays \n144\n measure signals, referred to here as borehole signals.', 'The borehole signal is measured by each receiver in the array, for each source position, leading to a plurality of borehole signal data points.', 'In addition, marine receivers within the marine receiver arrays \n148\n measure an earth response at the respective location on the seabed, which is then collected as seabed signal data points.', 'Methods in accordance with the present disclosure may utilize a pre-operation modeling study that uses a model of the earth formation (earth model) along with other information that may include source locations, receiver antenna locations, antenna sensitivity, and EM power delivered to the electromagnetic source to calculate an expected received signal by each receiver.', 'In one or more embodiments, the earth model may account for the EM wave propagation and any reflections from the discontinuities in the earth, such as bed boundaries and other geological features.', 'In some embodiments, the model may also include the depth of source from the marine surface and the depth of marine water layer \n120\n.', 'To account for earth subsurface strata below the marine water layer \n120\n, the earth model incorporates structure from the subsurface strata such as bed thickness, tilt, as well as the electromagnetic parameters such as resistivity, EM anisotropy, and the like.', 'Subsurface data may be obtained from well log data obtained by conventional logging tools in some embodiments but may only be valid for the near wellbore area.', 'Seismic data may also be used in some embodiments to provide information for greater distances from the borehole regarding formation geometry and structural heterogeneity, however, seismic data does not provide information about the EM-related properties.\n \nFIG.', '2\n shows an example scenario where wells \n230\n and \n240\n are drilled from a platform in the marine water layer \n202\n and passes the earth subsurface strata \n204\n, \n206\n, \n208\n, \n210\n, \n212\n, \n214\n, and \n216\n.', 'The boundaries \n220\n around well \n230\n show the distance from the well borehole where the data from conventional logs is valid which is too small for Deep EM purposes.', 'In this particular example, the stratum \n218\n does not intersect with the well \n230\n and is unlikely to be detected by conventional logging techniques.', 'However, the bed \n218\n may be detected from well \n230\n by seismic measurements, which may provide limited information regarding geometrical parameters, but not EM-related properties.', 'Nearby well \n240\n drilled from the same platform intersects with strata \n210\n and \n218\n and conventional logs measured in well \n240\n provide information regarding the thickness and electromagnetic properties of strata \n210\n and \n218\n.', 'If well \n240\n does not exist or it does not intersect with \n218\n, approximate values may be used for the electromagnetic properties of stratum \n218\n.', 'In the next step, the initial EM properties and the earth geometries are input to a computer-based model that calculates the signal level at each receiver location as a function of source locations.', 'In one or more embodiments, the model generated from the receiver signal location may be used to define the optimum boundaries and depth(s) of a two-dimensional horizontal plane that represents a projected collection region for a marine submersible EM source to maximize receiver data collection.', 'MTB measurements are convenient logistically because a marine EM source can be towed continuously and at a desired speed.', 'During measurement, a marine EM source may operate continuously and may be transported to a second location following measurement at a first location.', 'Continuous measurement may lead to smoother and denser source signal intensity reaching receiver locations in which data is measured.', 'In one or more embodiments, the shortest distance between consecutive measurements is controlled by the time it takes for the receivers to record the data and the speed at which the source is moved which is well under control by the marine vessel speed.', 'In some embodiments, the source may be stopped at discrete locations where the measurements are performed before moving the source to the next location, which may increase data resolution at the expense of increased data acquisition time.', 'In \nFIGS.', '3\nA and \n3\nB\n, projected travel paths for a marine EM source during a MTB measurement in accordance with the present disclosure are shown, as based on the generated two-dimensional horizontal plane.', 'With respect to \nFIG.', '3\nA\n, a top view of a two-dimensional horizontal plane generated in accordance with methods of the present disclosure is shown.', 'During computer modeling, the position of source from the platform \n102\n is increased while monitoring the signal to noise ratio (SNR) of signal at borehole receivers, where signal intensity is inversely proportional at further distances from the EM.', 'In one or more embodiments, a model may incorporate presets that are based on SNR.', 'For example, a preset SNR may be established based on a distance from the EM source at which the signal is below a workable SNR.', 'The SNR preset may be used to define boundary point \n320\n.', 'Repeating the same study in different directions, horizontal plane \n310\n may be mapped for based on a central reservoir source \n102\n and available receiver array locations.', 'If desired, studies may be repeated by varying the borehole receiver array design (e.g., size, receiver number, inter-receiver distance, and the like) to provide the optimum receiver array locations and number.', 'In \nFIG.', '3\nA\n, travel paths for a marine EM source are designed in straight path crisscross grid \n330\n.', 'Marine EM source travel paths may be parallel in some embodiments, and in some embodiments where the source is unidirectional, they may be repeated in perpendicular directions.', 'In the embodiment shown in \nFIG.', '3\nA\n, the antenna is transported in two substantially perpendicular directions to form a path resembling a rectangular grid (grid path).', 'In this case, the source is transported in a first set of paths and then measurements are repeated in a second, perpendicular set of paths.', 'Methods incorporating a grid path may be particularly useful when the source is unidirectional and dragging it in two orientations leads to more independent measurements.', 'FIG.', '3\nB\n depicts a further embodiment in which a marine EM source travel path is executed in a spiral path \n350\n that covers the same horizontal plane.', 'The present disclosure contemplates any combinations of these and other dragging paths.', 'In one or more embodiments, measurements may continue while the marine EM source is transported along the projected travel path.', 'In \nFIG.', '3\nA\n, the source may start at location \n322\n and be transported in the direction of location \n324\n, at which point the marine vessel changes direction and moves to point \n326\n from which it continues in the opposite direction without having to stop.', 'This continues until the marine vessel reaches location \n340\n and covers the entire two-dimensional plane \n310\n.', 'Variations in speed may also be minimized by introducing curved elements into the travel path.', 'For example, in the spiral path embodiment of \nFIG.', '3\nB\n, there is no need for the marine vessel to make large path changes as the path naturally lends itself to a continuous and smooth travel.', 'Methods of MTB measurement in accordance with the present disclosure may avoid the common problems of data undersampling near the transmitter location by increasing the number of source positions surveyed per measurement.', 'Knowing the impedance of medium close to the antenna allows the source to be designed to be impedance matched to the water conductivity causing close to perfect coupling between the source antenna and the surrounding medium.', 'The proper impedance match causes most of the EM wave energy to couple to the marine water layer and be transmitted instead of being reflected back to the source.', 'The high intensity broadcasted EM wave, couples to the earth strata beneath the marine level and propagates to the reservoir of interest which in turn increases the signal to noise ratio of both borehole receivers and marine receivers.', 'Because the marine EM source used in embodiments of the present disclosure is immersed in conductive sea water (which often has an electrical conductivity around 5 S/m), the impedance surrounding the source is well-defined, constant, and accessible for measurement.', 'In some embodiments, methods may assume that sea water is a constant that is approximately 5 S/m.', 'In one or more embodiments, the measured data at each receiver location is repeated and signal averaged to reach a target SNR.', 'In some embodiments, EM wave coupling between the marine EM source and the surrounding sea water may result in higher measured signal levels and a minimization or elimination of a need for repeated measurements to achieve a targeted SNR.', 'The improved SNR permits the marine EM source to be transported further away from the target well in the reservoir of interest and receivers, which enables the survey area traveled by the marine EM source to be increased and may translate to the creation of a deeper map of reservoir EM properties.', 'In one or more embodiments, the marine EM source transport speed by marine vessel \n132\n may be optimized for the given application.', 'At high transport speeds, rapid source movement may obscure the location of the source as receivers are making measurements.', 'In contrast, at low transport speed, source movement may be slower than receiver data acquisition time, which leads to idle time as the source reaches the next set location without added benefit.', 'Optimization methods in accordance with the present disclosure may include selecting a target SNR, the signal level of an individual measurement, and the length of time for each measurement.', 'With these factors the time required to make a reliable measurement may be determined, which may then be converted to an optimized transport speed for the marine EM source.', 'In some embodiments, the marine EM source transport speed may vary in one or more areas of the measurement plane.', 'For example, in locations close to the well head, the EM source and borehole receiver array are closer to each other causing the borehole signal to be stronger so that the marine vessel speed can be set faster.', 'In contrast, far away from the well head and close to the boundaries of the two-dimensional measurement plane, the signal becomes weaker and the source may need to be transported slower.', 'The measurements obtained by a marine receiver array \n148\n may be used to generate one or more seabed signal data points from signals intercepted from EM source \n130\n.', 'This transmitter-receiver combination is used in a control source EM (CSEM) measurement.', 'In CSEM, the EM wave broadcasted from the EM source travels through the earth strata below the sea floor and propagates down until it reaches a bed boundary with different EM properties.', 'Part of the EM energy is reflected at the bed boundary and propagates back to the sea floor where it is measured by the marine receivers in array \n148\n.', 'The remaining part of EM continues to propagate lower until it encounters the next bed boundary at which point it gets reflected and eventually detected by the marine receivers.', 'The propagation-reflection-propagation steps continue until the EM energy level falls below the detectable limit of the seafloor receivers.', 'The measured data can be modeled and interpreted to obtain the resistivity and geometry of earth strata lying below the sea floor.', 'CSEM is typically used before initiating a drilling operation and has been shown to be able to detect shallower reservoirs.', 'Once these reservoirs are detected the drilling can commence.', 'Referring again to \nFIG.', '1\n, the received signals by the marine receiver array \n148\n is a CSEM response.', 'In one or more embodiments, this signal alone can be processed to obtain a resistivity distribution of the earth lying below the seafloor down to the reservoir depth.', 'In some embodiments, an EM forward model accounting for the geometries and antennas is used iteratively to invert the CSEM response.', 'Forward models in accordance with the present disclosure may provide a modeled seabed signal using initial EM properties and geometries of subsurface strata (collectively referred to as inversion parameters).', 'In an inversion routine, the modeled seabed signals are compared with the actual measured data and the difference is used to update the inversion parameters, which are used in the forward model again.', 'This process is repeated iteratively until a conversion is reached.', 'Following inversion of the CSEM response, the final inversion parameters provide enhanced agreement between the modeled and measured seabed signals and may be taken as the EM properties and geometries of earth below the seafloor.', 'These steps are outlined in \nFIG.', '4\n.', 'In step \n410\n, the forward model is populated by the data obtained from one or more data sources including conventional log responses, seismic maps, data from any adjacent wells, and the like.', 'The forward model is run in step \n414\n to produce modeled seabed signals.', 'In step \n416\n modeled seabed signals are compared with the measured data and a difference is calculated.', 'In step \n420\n, the difference is compared with the conversion criteria.', 'If the difference does not meet the conversion criteria, inversion parameters of the earth strata may be adjusted in step \n424\n and returned to step \n410\n.', 'This procedure may be repeated until conversion is reached in step \n420\n.', 'The latest EM properties and geometries are recorded as the parameters that best reproduce the measured seabed signal data.', 'The CSEM derived EM parameters and geometries from step \n420\n may be used as a priori input to step \n430\n, which is the first step for processing the borehole signal data.', 'This part of inversion is focused on obtaining optimum 3D EM property distribution of the reservoir of interest.', 'The CSEM parameters are frozen in step \n430\n while the EM parameters and geometry of the reservoir of interest can vary iteratively as shown in \nFIG.', '4\n.', 'The forward model is then run in step \n440\n, leading to modeled borehole signal.', 'In step \n442\n, the modeled and measured borehole signals are compared, and a difference is calculated.', 'In step \n450\n, the calculated difference is compared with convergence condition.', 'If convergence is not reached, latest parameters are modified in step \n460\n and returned to step \n430\n.', 'These steps are repeated iteratively until convergence is reached in step \n450\n and the latest parameters are forwarded to step \n470\n.', 'Different approaches are available to express the geometry of subsurface strata in an inversion routine.', 'In one approach, the EM properties of a formation are assumed not to vary from point to point within the same earth formation.', 'With this approximation, the subsurface strata are treated as having effectively uniform parameters at all points in the medium, and the inversion result is the effective medium EM properties of the formation.', 'This approach ignores variations in the EM properties that invariably exist within the same formation and instead the inversion searches for an average value for these properties.', 'In another approach, the earth stratum is subdivided into smaller spatial units, usually cubes, and the inversion attempts to find the EM properties of each small spatial unit.', 'In a 2D geometry each small spatial unit is called a pixel while in 3D geometries the spatial units are called voxels.', 'With this approach, the number of variables to be inverted are multiplied by at least the number of spatial units.', 'As a result, to perform the inversion requires more independent measurements compared to the effective medium approach.', 'Depending on the application, the approach may be selected with consideration of available independent measurements and computing power, and the level of detail required about the formation.', 'In one or more embodiments, the forward model in step \n410\n of \nFIG.', '4\n treats the geometry of each intervening formation as an effective medium and proceeds with the inversion.', 'If there are enough seabed signal data points available, some or all the intervening formations may be subdivided into smaller spatial units and inverted.', 'A larger number of seabed measurements may require a deployment of a larger number of marine receivers which may be possible if the detailed EM parameters of an intervening earth strata are desired and contemplated at the time when the seabed receivers are deployed.', 'For the reservoir of interest, a layer may be subdivided into smaller spatial units.', 'Methods in accordance with the present disclosure that consider smaller units may enable higher measurement resolution, which may be used to identify bypassed zones in the reservoir of interest.', 'Accordingly, in step \n430\n, the petroleum bearing reservoir of interest is subdivided into three-dimensional spatial units (voxels or cubes) and the inversion is performed to obtain the EM properties of each special unit.', 'The maximum number of special units that can be inverted for is determined by the number of independent measured data points and the number of unknown parameters.', 'A higher number of MTB measurements allow the space to be divided into more special units with smaller dimensions.', 'As the inversion provides formation properties at smaller voxels, MTB measurement has proportionally higher resolution.', 'The outcome of the inversion is a three-dimensional EM property distribution of a reservoir of interest.', 'In a further embodiment, depending on the objective of measurement, it may be sufficient to use the effective medium approach for the reservoir of interest.', 'In this case, step \n430\n treats the reservoir of interest as an effective medium.', 'The present disclosure is not limited to any particular type of inversion approach and all existing inversion approaches are contemplated by this disclosure.', 'Other approaches may be used for further enhancing the quality and resolution of inversion results.', 'In one or more embodiments, measurements of the fields excited in a Crosswell EM configuration may exist.', 'Because these measurements have higher resolution, they can also be added to the processing step of MTB data, providing added constraints and a priori information about the 3D EM property distribution.', 'In a further embodiment, a method is provided to simultaneously invert both the data sets recorded downhole and on the seafloor for the EM property of overburden and the 3D EM property distribution of the reservoir of interest.', 'Once a 3D EM property distribution of the reservoir is determined, it can be interpreted to learn about the fluid volume distribution in the pore space of the reservoir.', 'Higher resistivity values are known to be associated with less water and thus more hydrocarbon.', 'In one or more embodiments, a colored 3D resistivity distribution (or equivalent 3D conductivity distribution), which is a subset of 3D EM property distribution, provides a quick impression of locations where more oil may exist.', 'The 3D resistivity distribution is quantitatively interpreted when values of each voxel is converted to an average saturation within the voxel; converting a 3D resistivity distribution to a 3D saturation distribution.', 'To perform this conversion a relationship between the rock resistivity and water content (water saturation) is needed.', "In petrophysics, this relation is provided by Archie's law, among others, which can be used to transform the resistivity to water saturation at each voxel.", 'The water and hydrocarbon (oil and gas) saturations are related as, by definition, their sum is unity.', 'Thus, the hydrocarbon saturation in each pixel is easily derived from the water saturation at the same voxel leading to a 3D hydrocarbon saturation distribution.', 'Methods in accordance with the present disclosure may include one or more of: 1) displaying and/or recording the 3D EM properties distribution of the subsurface area, 2) identifying a hydrocarbon deposit within the subsurface stratum using the electromagnetic properties, 3) displaying and/or recording the 3D fluid saturation distribution of the subsurface stratum of interest, and 4) identifying a hydrocarbon deposit within the subsurface stratum using the 3D saturation distribution of the subsurface area.', 'Methods may also include using 3D EM property distributions to design a drilling operation or secondary recovery operation.', 'In situations where the reservoir has been producing by water injection, there should not be any gas left in the pore space of the formation.', 'In this case, the hydrocarbon saturation may be assumed as equivalent to oil saturation and it can be interpreted accordingly.', 'In one or more embodiments, a heat map of oil saturation may be produced from the inversion data that helps emphasize the zones in which the oil saturation is higher than average, indicating zones where the hydrocarbon is substantially bypassed.', 'In one or more embodiments, inversion data may be used by a reservoir engineer to devise a strategy for drilling and constructing new wells or remedial action to extract hydrocarbons from bypassed zones, for example, by drilling new wells, modifying secondary recovery techniques, and the like.', 'The 3D EM property distributions generated by methods in accordance with the present disclosure include formation resistivity and other electromagnetic properties of a reservoir such as induced polarization.', 'For example, the data acquired during MTB measurement includes information on induced polarization.', 'In one or more embodiments, the forward model can be generalized to account for the induced polarization in the MTB measurement, and other effects as well.', 'The induced polarization may then be processed by an inversion routine described above to calculate the 3D induced polarization distribution of the reservoir.', 'Similarly, other properties such as anisotropy distribution characterized by MTB measurements may be converted to 3D distributions of the reservoir.', 'In one or more embodiments, 3D distributions may include a three-dimensional electromagnetic property distribution, three-dimensional resistivity distribution, three-dimensional induced polarization distribution, three-dimensional anisotropy distribution, three-dimensional saturation distribution, three-dimensional fracture distribution, three-dimensional permeability distribution, three-dimensional pore pressure distribution, three-dimensional hydraulic boundary distribution, three-dimensional trapped fluids distribution, and the like.', 'In one or more embodiments, the marine EM source \n130\n can be an electric dipole or a magnetic dipole.', 'FIG.', '5\nA\n shows an embodiment of an electric dipole antenna that may be used in CESM measurements in accordance with the present disclosure.', 'In the dipole antenna, two conductive (metallic) bars \n510\n are shown in line with each other, while a gap \n512\n in the center serves to electrically isolate the two bars and is the location of the EM emission when electrical current is provided to the source.', 'In a further embodiment shown in \nFIG.', '5\nB\n, a two-dimensional electric dipole is made of two bars \n510\n aligned with an X-axis while two other bars \n520\n are aligned with Y or Z-axis.', 'In yet another embodiment shown in \nFIG.', '5\nC\n, three mutually perpendicular electric dipoles are aligned with the X, Y, and Z-axes.', 'The tri-axial electric dipole antenna of \nFIG.', '5\nC\n includes two bars \n510\n along the X-axis, two bars \n520\n along the Y-axis, and two bars \n530\n along the Z-axis.', 'Electric dipoles in accordance with the present disclosure may be configured to withstand the high EM currents available in marine environments.', 'In some embodiments, EM sources may be powered with currents of up to 10,000 Amperes or more to excite the source antenna.', 'In embodiments in which multiple electric dipole antennas of \nFIGS.', '5\nB and \n5\nC\n are used, the dipole antennas may be energized independently, where each dipole antenna acts as an independent transmitter, increasing the number of borehole signal and seabed signal data sets.', 'Multiple dipole antennas may be multidirectional, in contrast with electric dipoles sources in borehole applications, where any electric dipole having a length larger than the borehole diameter can only be unidirectional and oriented along the axis of the well.', 'Thus, the electric dipole for borehole applications may often be a one-dimensional antenna.', 'In one or more embodiments, magnetic dipoles may be used as sources for MTB measurement.', 'These antennas are wound around a magnetic core of high magnetic permeability.', 'The number of windings is optimized for the antenna to have high efficiency and strong coupling to the marine water.', 'In an embodiment, shown in \nFIG. \n6\n, the magnetic dipoles are made in three perpendicular directions and can be used to generate correspondingly more measured data.', 'The windings \n610\n, \n620\n, and \n630\n use relatively thick wires enabling the antenna to handle high EM currents.', 'In one or more embodiments, both electric and magnetic fields may be measured by the receivers located in the borehole and seabed.', 'The borehole receiver arrays (such as \n144\n shown in \nFIG.', '1\n) may be made up of many receiver (antennas), which may contain in some embodiments, up to 1000 receivers.', 'During measurement, receiving sensors inside a wellbore may measure some or all of the components of the electric field tensor, as well as magnetic field tensor in some embodiments.', 'Receiving sensors in accordance with the present disclosure may be selected from electrode contact dipoles, coils, and capacitive sensors of any kind as deemed appropriate for the specific operating conditions.', 'In one or more embodiments, the borehole receivers are magnetic field detectors and magnetic dipole antennas are used as receivers.', 'In their simplest design, magnetic dipole antennas are made by winding many turns and are designed to fit in the confined space of a borehole.', 'In some embodiments, magnetic dipole antennas are made with thin magnet wires and are available as tri-axial antennas oriented along perpendicular axes that define a local Cartesian coordinate system.', 'Tri-axial antennas may be preferable to single axis antennas for some applications because they are sensitive to different components of the EM field and provide more detailed information which helps with inversion and increases the measurement resolution.', 'In some embodiments, electric dipole receivers are used in the borehole, such as an electric dipole receiver oriented in the direction of the well.', 'In one or more embodiments, borehole receiver arrays may be placed in the borehole as part of a permanent or semi-permanent wellbore completion.', 'Receiver arrays in accordance with the present disclosure may use power and telemetry cables of their own or they may share with other completion components.', 'In some embodiments, deployment facilities may repeat the MTB measurement at later times in a wellbore operation and with receivers already in the borehole, to obviate the need for a rig for receiver conveyance during each repeat measurement, which saves time and effort for time lapse measurements.', 'For example, methods in accordance with the present disclosure may include measuring the three-dimensional property distribution at one or more time-points to establish a time lapse three-dimensional property distribution.', 'In some embodiments, the time lapse three-dimensional property distribution may be used to infer a three-dimensional distribution selected from a three-dimensional relative permeability distribution or a three-dimensional fracture conductivity distribution.', 'Time lapse 3D EM property distribution measurements in accordance with the present disclosure may include information for 3D resistivity and 3D saturation distributions as a function of time and can be interpreted to obtain a wealth of information about the fluid flow in the reservoir of interest.', 'The time dependent 3D saturation distributions can be converted to 3D permeability distribution of the reservoir where relative fluid movement is highlighted.', 'Using such a distribution, zones with higher and lower permeability can be identified and used in a reservoir production plan.', 'The thin zones of very high permeability can be identified as fractures and their conductivity can be calculated.', 'Similarly, hydraulic boundaries can be mapped.', 'This information can be used to optimize water injection strategies which help prevent early water breakthrough and maximize hydrocarbon recovery.', 'In one or more embodiments, seabed receivers may use tri-axial electric dipole and/or tri-axial magnetic dipole antennas.', 'The size of these antennas is not limited by the borehole diameter and can be much larger than the corresponding antennas used in a borehole.', 'In a marine environment, multiple wells may be drilled from the same platform and it is common to have at least portions of some wells close to each other.', 'The proximity of wells may make multi-well receiving possible by placing receiver arrays in multiple boreholes close enough to sense EM signal of comparable intensity.', 'As the EM source is transported through the water body, exciting the medium, the earth response is measured downhole in multiple boreholes, through electric and/or magnetic field sensors oriented in the direction of the well trajectory as well as perpendicular to it.', 'In some embodiments, methods may also include sea floor receivers, which may use electric and magnetic fields sensors oriented in all 3 directions (X, Y and Z).', 'The multi-well measurements add extra data and help with the inversion process.', 'In some embodiments, the MTB signal measured can be processed to create a higher resolved 3D EM property distribution of the space between the wells.', 'Some of the methods and processes described above, can be performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any device type or system.', 'The processor may include a computer system.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, or general-purpose computer) for executing any of the methods and processes described above.', 'The computer system may further include a memory such as a semiconductor memory device (e.g., a RAM, ROM, PROM, EEPROM, or Flash-Programmable RAM), a magnetic memory device (e.g., a diskette or fixed disk), an optical memory device (e.g., a CD-ROM), a PC card (e.g., PCMCIA card), or other memory device.', 'Some of the methods and processes described above, can be implemented as computer program logic for use with the computer processor, such as a processor configured to calculate a three-dimensional property distribution of a reservoir of interest from data received by the one or more borehole receivers and the one or more marine receivers.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Alternatively, or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.', 'Although only a few examples have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the examples without materially departing from this present disclosure.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112 (f) for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.']

['1.', 'A method, comprising:\ndispersing one or more borehole receivers in one or more boreholes;\ndistributing one or more marine receivers in marine water at a seabed;\nimmersing an electromagnetic source in the marine water above the seabed;\nenergizing the electromagnetic source to generate electromagnetic waves;\nmeasuring one or more borehole signal measurements using the one or more borehole receivers, wherein the one or more borehole signal measurements comprise propagations of the electromagnetic waves received at respective borehole receivers;\nmeasuring one or more seabed signal measurements using the one or more marine receivers, wherein the one or more seabed signal measurements comprise reflections of the electromagnetic waves from earth subsurface strata of the seabed received at respective marine receivers; and\ndetermining, via a processor, a three-dimensional property distribution of a reservoir of interest by: using the one or more seabed signal measurements to determine electromagnetic parameters of the earth subsurface strata intervening between the seabed and the reservoir of interest via a first inversion operation; using the one or more borehole signal measurements and the electromagnetic parameters of the earth subsurface strata to generate inverted one or more borehole signal measurements via a second inversion operation; and determining the three-dimensional property distribution of the reservoir of interest based on the inverted one or more borehole signal measurements.', '2.', 'The method of claim 1, further comprising:\ndesigning a drilling operation or secondary recovery operation based on the three-dimensional property distribution.', '3.', 'The method of claim 1, wherein the three-dimensional property distribution comprises at least one of a three-dimensional electromagnetic property distribution, a three-dimensional resistivity distribution, a three-dimensional induced polarization, a three-dimensional anisotropy distribution, a three-dimensional saturation distribution, a three-dimensional fracture distribution, a three-dimensional permeability distribution, a three-dimensional pore pressure distribution, or a three-dimensional hydraulic boundary distribution.', '4.', 'The method of claim 1, wherein the one or more borehole receivers are permanently or semi-permanently installed in the one or more boreholes.', '5.', 'The method of claim 1, wherein the electromagnetic source is excited in a time domain or in a frequency domain.', '6.', 'The method of claim 3, wherein the three-dimensional property distribution is the three-dimensional saturation distribution and is used to infer a three-dimensional trapped fluids distribution.', '7.', 'The method of claim 1, wherein the three-dimensional property distribution is used to optimize a water injection strategy.', '8.', 'The method of claim 1, wherein the electromagnetic source is transported in the marine water in a dragging plane determined from using a pre-operation model.', '9.', 'The method of claim 1, wherein the reservoir of interest includes hazardous materials.', '10.', 'The method of claim 1, further comprising:\ndetermining the three-dimensional property distribution at one or more-time points to establish a time lapse three-dimensional property distribution.', '11.', 'The method of claim 10, wherein the time lapse three-dimensional property distribution is used to infer a three-dimensional distribution selected from a three-dimensional relative permeability distribution or a three-dimensional fracture conductivity distribution.', '12.', 'An apparatus comprising:\na marine electromagnetic source immersed in marine water above a seabed, wherein the marine electromagnetic source is configured to generate electromagnetic waves;\none or more borehole receivers dispersed in one or more borehole locations to measure one or more borehole signal measurements, wherein the one or more borehole signal measurements comprise propagations of the electromagnetic waves received at respective borehole receivers;\none or more marine receivers dispersed in one or more seabed locations to measure one or more seabed signal measurements, wherein the one or more seabed signal measurements comprise reflections of the electromagnetic waves from earth subsurface strata of the seabed received at respective marine receivers; and\na processor configured to calculate a three-dimensional property distribution of a reservoir of interest by: using the one or more seabed signal measurements to determine electromagnetic parameters of the earth subsurface strata intervening between the seabed and the reservoir of interest via a first inversion operation; using the one or more borehole signal measurements and the electromagnetic parameters of the earth subsurface strata to generate inverted one or more borehole signal measurements via a second inversion operation; and determining the three-dimensional property distribution of the reservoir of interest based on the inverted one or more borehole signal measurements.', '13.', 'The apparatus of claim 12, wherein the marine electromagnetic source is selected from a group comprising: one-dimensional electric dipole, two-dimensional electric dipole, three-dimensional electric dipole, one-dimensional magnetic dipole, two-dimensional magnetic dipole, and three-dimensional magnetic dipole.', '14.', 'The apparatus of claim 12, wherein the one or more borehole receivers comprise a combination of an electric dipole antenna and a magnetic dipole antenna.', '15.', 'The apparatus of claim 12, wherein the one or more marine receivers comprise a combination of a multi-dimensional electric dipole antenna and a multidimensional magnetic dipole antenna.', '16.', 'The apparatus of claim 12, wherein the marine electromagnetic source is electrically and mechanically connected to a marine vessel.', '17.', 'The apparatus of claim 16, wherein the marine vessel can excite and drag the marine electromagnetic source immersed in the marine water.', '18.', 'A method, comprising:\nproviding, from one or more borehole receivers in one or more boreholes, one or more borehole signal measurements with corresponding depths, wherein the one or more borehole signal measurements comprise propagations of electromagnetic waves generated by an electromagnetic source and received at respective borehole receivers, and wherein the electromagnetic source is immersed in marine water above a seabed and configured to generate the electromagnetic waves;\nproviding, from one or more marine receivers at the seabed, one or more seabed signal measurements with corresponding seabed coordinates, wherein the one or more seabed signal measurements comprise reflections of the electromagnetic waves from earth subsurface strata of the seabed received at respective marine receivers;\nusing the one or more seabed signal measurements to determine electromagnetic parameters of the earth subsurface strata intervening between the seabed and a reservoir of interest via a first inversion operation;\nusing the one or more borehole signal measurements and the electromagnetic parameters of the earth subsurface strata to generate inverted one or more borehole signal measurements via a second inversion operation; and\ndetermining, via a processor, a three-dimensional property distribution of the reservoir of interest from the inverted one or more borehole signal measurements.', '19.', 'The method of claim 18, further comprising:\ndesigning a drilling operation or secondary recovery operation based on the three-dimensional property distribution.', '20.', 'The method of claim 18, wherein the inverting comprises a three-dimensional inversion.', '21.', 'The method of claim 18, wherein the three-dimensional property distribution comprises at least one of a three-dimensional electromagnetic property distribution, a three-dimensional resistivity distribution, a three-dimensional induced polarization, a three-dimensional anisotropy distribution, a three-dimensional saturation distribution, a three-dimensional fracture distribution, a three-dimensional permeability distribution, a three-dimensional pore pressure distribution, or a three-dimensional hydraulic boundary distribution.', '22.', 'The method of claim 21, wherein the three-dimensional saturation distribution is used to infer a three-dimensional trapped fluids distribution.']

['FIG. 1 is a projected view of a marine layer and an apparatus to perform the marine to borehole measurement in accordance with embodiments of the present disclosure;; FIG.', '2 is a cross-sectional view of the earth layer showing how conventional well logs, seismic, and logs that are run in an adjacent well are used to estimate initial values for the electromagnetic parameters and geometry of earth layers in accordance with embodiments of the present disclosure;; FIG.', '3A is a drawing of a two-dimensional plane within the marine water in which the electromagnetic source is transported in a linear path in accordance with embodiments of the present disclosure;; FIG.', '3B is a drawing of a two-dimensional plane within the marine water in which the electromagnetic source is transported in a spiral path in accordance with embodiments of the present disclosure;; FIG. 4 is a workflow showing a first and second stage inversion for seabed signal and borehole signal in accordance with embodiments of the present disclosure;; FIG.', '5A is a schematic drawing of single axis electric dipole antenna to be used as a transmitter (source) in marine to borehole (MTB) measurements in accordance with embodiments of the present disclosure;; FIG.', '5B is a schematic drawing of a bi-axial electric dipole antenna to be used as a transmitter (source) in MTB measurements in accordance with embodiments of the present disclosure;; FIG.', '5C is a schematic drawing of tri-axial electric dipole antenna to be used as a transmitter (source) in MTB measurements in accordance with embodiments of the present disclosure; and; FIG.', '6 is a schematic drawing of a tri-axial magnetic dipole antenna to be used as a source in MTB measurements in accordance with embodiments of the present disclosure.', '; FIG. 1 is a projected view of a marine wellbore operation and an apparatus to perform the marine to borehole measurement.', 'The marine water environment 120 is shown in which an offshore platform 110 is positioned for oil exploration, reservoir development and petroleum production.', 'Multiple wells 104 and 106 have been drilled from the platform 110 into the earth, traversing the subsurface strata 122, 124, 126, and 128.', 'Well 104 passes through subsurface strata 122, 124, and 126 to reach the reservoir of interest 112.', 'The earth above the reservoir 112 up to the marine water environment 120 may be referred to as overburden.', 'The overburden may include many geological formations and is not limited by the four subsurface strata shown in FIG.', '1.', 'Well 106 extends from platform 110 and traverses reservoir 114.', 'The wells 104 and 106, being drilled from the same platform, are near to each other before they change direction towards different reservoirs.; FIG.', '2 shows an example scenario where wells 230 and 240 are drilled from a platform in the marine water layer 202 and passes the earth subsurface strata 204, 206, 208, 210, 212, 214, and 216.', 'The boundaries 220 around well 230 show the distance from the well borehole where the data from conventional logs is valid which is too small for Deep EM purposes.', 'In this particular example, the stratum 218 does not intersect with the well 230 and is unlikely to be detected by conventional logging techniques.', 'However, the bed 218 may be detected from well 230 by seismic measurements, which may provide limited information regarding geometrical parameters, but not EM-related properties.', 'Nearby well 240 drilled from the same platform intersects with strata 210 and 218 and conventional logs measured in well 240 provide information regarding the thickness and electromagnetic properties of strata 210 and 218.', 'If well 240 does not exist or it does not intersect with 218, approximate values may be used for the electromagnetic properties of stratum 218.']

US11835674

Methods of analyzing cement integrity in annuli of a multiple-cased well using machine learning

Nov 7, 2022

Bo Fan, Maja Skataric, Sandip Bose, Shuchin Aeron, Smaine Zeroug

SCHLUMBERGER TECHNOLOGY CORPORATION

“Isolating potential flow zones during well construction,” in American Petroleum Institute Recommended Practice, vol. 65—Part 2, 96 pages, 2010.; Pistre et al., “A modular wireline sonic tool for measurements of 3d (Azimuthal, Radial, and Axial) formation acoustic properties,” in SPWLA 46th Annual Logging Symposium, 2005, 13 pages.; Bose et al., “Semblance criterion modification to incorporate signal energy threshold”, in SEG Annual Meeting, 2009, 6 pages.; Search Report and Written Opinion of International Patent Application No. PCT/US2018/057429 dated Mar. 11, 2019; 10 pages.; International Preliminary Report on Patentability of International Patent Application No. PCT/US2018/057429 dated May 7, 2020; 7 pages.; Kimball and Marzetta, “Semblance processing of borehole acoustic array data”, Geophysics, vol. 49, No. 3, Mar. 1984, pp. 274-281.; Rama Rao and Toksoz, “Dispersive wave analysis—method and applications”, Earth Resources Laboratory Industry Consortia Annual Report, MIT, 2005, 20 pages.; Hsu and Lin, “A comparison of methods for multiclass support vector machines”, IEEE Trans Neural Network, vol. 13, No. 2, pp. 415-425, 2002.; Chollet, “Building autoencoders in keras”, in The Keras Blog. Https://blog.keras.io/building-autoencoders-in-keras.html, May 14, 2016, 18 pages.; Prahallad, “Speech technology: A practical introduction”, in Carnegie Mellon University International Instittue of Information Technology Hyderabad PPT, 2003, 50 pages.; Young et al., The HTK Book (Version 3.4), Cabridge University Engineering Department, 2006.; Wikipedia, “Convolutional neural network”, in Online, 2016.; Karpathy et al., “Large-scale video classification with convolutional neural networks”, in Conference on Computer on Computer Vision and Pattern Recognition (Cvpr), IEEE, 2014, 8 pages.; Tompson et al., “Efficient object localization using convolutional networks”, in Conference on Computer Vision and Pattern Recognition (CVPR), IEEE, 2015, pp. 648-658.; Ruder, “An overview of gradient descent optimization algorithms”, in Online, Jan. 19, 2016, Available: http://sebastianruder.com/optimizing-gradient-descent/, 17 pages.; Radon, “On the Determination of Functions from their Integral Values Along Certain Manifolds”, IEEE Transactions on Medical Imaging, vol. MI-5, No. 4, pp. 170-176, Dec. 1986.; Extended Search Report issued in European Patent Application No. 18869615.7 dated Jun. 21, 2021, 9 pages.; Liu J. C. et al., “Intelligent Evaluation Model for Cementing Quality Based on PSO-SVM and Application”, Applied Mechanics and Materials, 2011, vols. 71-78, pp. 4293-4299.; Communication Pursuant to Article 94(3) issued in European Patent Application No. 18869615.7 dated Mar. 10, 2023, 8 pages.

4594691; June 10, 1986; Kimball; 10705056; July 7, 2020; Lei; 10858933; December 8, 2020; Bose; 10995606; May 4, 2021; Skataric; 11493659; November 8, 2022; Fan; 20020183930; December 5, 2002; Plona et al.; 20090168597; July 2, 2009; Wu; 20120037423; February 16, 2012; Geerits; 20150219780; August 6, 2015; Zeroug et al.; 20160003036; January 7, 2016; Mickael; 20180142545; May 24, 2018; Lei; 20190055830; February 21, 2019; Skataric; 20210181366; June 17, 2021; Fan

2015108639; July 2015; WO; 2016187239; November 2016; WO; 2016187240; November 2016; WO; 2016187242; November 2016; WO; 2017151834; September 2017; WO

['A sonic tool is activated in a well having multiple casings and annuli surrounding the casing.', 'Detected data is preprocessed using slowness time coherence (STC) processing to obtain STC data.', 'The STC data is provided to a machine learning module which has been trained on labeled STC data.', 'The machine learning module provides an answer product regarding the states of the borehole annuli which may be used to make decision regarding remedial action with respect to the borehole casings.', 'The machine learning module may implement a convolutional neural network (CNN), a support vector machine (SVM), or an auto-encoder.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application is a continuation patent application of U.S. patent application Ser.', 'No. 16/759,667, filed Apr. 27, 2020, now U.S. Pat.', 'No. 11,493,659 which is a 35 U.S.C. 371 application of International Patent Application: PCT/US2018/057429, filed on Oct. 25, 2018 and which claimed the benefit of priority under 35 U.S.C. 119(e) to U.S. Provisional Patent Application No. 62/577,945, filed Oct. 27, 2017, the entire contents of which are incorporated herein by reference.', 'FIELD', 'This disclosure relates to well logging in oil and gas fields.', 'In particular, this disclosure relates to analyzing the status, for example, the cement integrity of annuli in a multiple-cased oil and gas well.', 'BACKGROUND\n \nEffective diagnosis of well zonal isolation has become important with the recent advent of harsher governmental regulations that call for oil and gas operators to deliver and maintain wells with competent pressure seals.', 'The goal is to prevent uncontrolled flow of subterranean formation fluids causing leaks into the atmosphere or into other formations.', 'See, e.g., “Isolating potential flow zones during well construction,” \nAmerican Petroleum Institute Recommended Practice\n, Vol. 65-Part 2, 2010.', 'The diagnosis could be carried out following a cementation job or during the life of a well or at the end of its life before plug and abandonment.', 'Acoustic measurements are widely used to diagnose the condition and placement of the cement and its bond to interfaces in contact with it.', 'The current methods, encompassing high frequency sonic CBL-VDL (See, V. Piste, et al., “A modular wireline sonic tool for measurements of 3d formation acoustic properties,” \nSPWLA \n46\nth Annual Logging Symposium, \n2005) and ultrasonic measurements, are designed for single casing strings and therefore can be used at best only for the diagnosis of the annulus behind the innermost casing string and the bonds therein.', 'However, in several markets including plug and abandonment, there is increasing interest in diagnosing the placement and bond of cement behind more than one string to avoid costly operations of cutting and pulling casing and multiple logging runs.', 'To address this market, there is a need for additional measurements and/or processing approaches that leverage the possibility of probing deeper than the first casing and annulus while addressing the challenges of diagnosing the cement placement behind second casings despite the increased complexity of the measurement physics in multiple casing strings.', 'Co-owned patent applications to S. Zeroug, et al., U.S. 20150219780 and to S. Bose et al., WO/2016US32965A propose a joint diagnosis of multiple acoustic modalities leveraging their independent sensitivities.', 'The anticipated result is a more robust diagnosis of the content of the annulus and whether it provides hydraulic isolation based on quantitative inversion of relevant parameters.', 'The S. Zeroug et al. application proposes a model-based inversion of the relevant parameters.', 'In practice, however, continuous logs covering thousands of feet along the well must be generated and it may not be feasible with the available computational resources to invert beyond a few selected locations.', 'For such a scenario, to cover the tens of thousands of depth frames, the S. Bose et al. application proposed a different approach of extracting attributes or features from all the available measurements and using those in machine learning algorithms to make a categorical diagnosis of not only the first annulus but also the annuli and bond conditions beyond the second casing.', 'In addition, the sonic measurements are in themselves quite rich as they include monopole and dipole logging modes that interrogate the cased hole system in diverse ways, enabling such a diagnosis.', 'Three additional co-owned patent applications to B. Sinha, et al., WO2014/US70255A, and to T. Lei, et al., WO2016/186240 and WO2016/187239 are devoted to techniques employing sonic data for well integrity diagnosis.', 'In another co-owned patent application to M. Skataric, et al., WO2017/151834, a methodology is outlined to process and display data over depth intervals with emphasis on features that indicate discontinuities indicative of such depth dependent transitions.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'This subject disclosure relates to cement barrier integrity in cased oil and gas wells with multiple casing strings.', 'The subject disclosure outlines an approach for the evaluation of well integrity in dual and multi-string casings using sonic data that reads deeper than the first casing and annulus.', 'The array sonic data comprising one or more of monopole, dipole and quadrupole modalities from one or more sources is pre-processed via a transform such as the (normalized) slowness time coherence (STC) transform, or the related (non-normalized)', 'Radon transform into a geophysical meaningful domain such as slowness-time domain.', 'The resulting 2-D or 1-D intermediate results are fed into a machine learning module such as a support vector machine (SVM), an auto-encoder, or a convolutional neural network (CNN) which has been trained with a training data set having labeled samples to learn features and discriminators particularly for the state of annuli behind the casings.', 'The structure of the network is heuristically designed to achieve reliable performance.', 'The output of the machine learning module is an answer product as to the states of the annuli behind the casings at the depth in the formation from which the array sonic data was gathered.', 'Data from multiple depths may be used to obtain answer products at different locations along the wellbore and the answer products may be used for determining remedial or other actions to be taken.', 'BRIEF DESCRIPTION OF DRAWINGS', 'The subject disclosure is further described in the detailed description which follows, in reference to the noted plurality of drawings by way of non-limiting examples of the subject disclosure, in which like reference numerals represent similar parts throughout the several views of the drawings, and wherein:\n \nFIG.', '1\n is a high-level flow-chart of disclosed methods for analyzing annuli of a multiple-cased well using machine learning;\n \nFIGS.', '1\na \nand \n1\nb \ndepict a wireline Sonic Scanner tool, showing the transmitters and receiver array and cross-dipole firings;\n \nFIG.', '2\n is a depiction of a sonic tool located in a multiple-casing string well;\n \nFIGS.', '3\na \nand \n3\nb \nrespectively depict monopole and dipole modalities excited by a Sonic Scanner™ tool, together with their waveforms and direction of source firing;\n \nFIG.', '4\n depicts a synthetic dataset showing a training set encompassing five possible cases of fill in annulus A and B on the left and two test set scenarios on the right for evaluating the classification performance of the algorithm;\n \nFIG.', '5\n shows training and testing datasets;\n \nFIGS.', '6\na \nand \n6\nb \nrespectively depict Butterworth filters (bands) with different cutoff frequencies on a normalized frequency scale and on an original frequency scale;\n \nFIGS.', '7\na\n-\n7\nd \nrespectively depict a sonic acquisition tool acquiring data, the receiver data as a function of receiver and time, an STC two-dimensional (2D) image, and an STC one-dimensional image obtained from a projection of the STC 2D image;\n \nFIG.', '8\n is a classification result using SVM on unlabeled full frequency band monopole data (Scenario 1);\n \nFIG.', '9\n is a classification result using SVM on unlabeled full frequency band monopole data (Scenario 2);\n \nFIG.', '10\n is a classification result using SVM on unlabeled full frequency band dipole data (Scenario 1);\n \nFIG.', '11\n is a classification result using SVM on unlabeled full frequency band dipole data (Scenario 2);\n \nFIG.', '12\n is a classification result using SVM on unlabeled multiband data (Scenario 1) where M1, and M2 denote monopole data in frequency ranges BPF1, and BPF2; D1, D2, D3, denote dipole data in frequency ranges BPF1, BPF2, and BPF3; M denotes combined monopole frequency bands; D denotes combined dipole frequency bands, and MD denotes combined monopole and dipole frequency bands;\n \nFIG.', '13\n is a classification result using SVM on unlabeled multiband data (Scenario 2) where M1, and M2 denote monopole data in frequency ranges BPF1, and BPF2; D1, D2, D3, denote dipole data in frequency ranges BPF1, BPF2, and BPF3; M denotes combined monopole frequency bands; D denotes combined dipole frequency bands, and MD denotes combined monopole and dipole frequency bands;\n \nFIG.', '14\n is a schematic of a convolutional auto-encoder;\n \nFIG.', '15\n depicts parameters of the auto-encoder of \nFIG.', '14', ';\n \nFIGS.', '16\na\n-\n16\ne \nshow learned bottleneck features with the x-axis being the pixel index of the bottleneck feature, and the y-axis representing the training set index;\n \nFIG.', '17\n is a training/testing diagram of auto-encoder with SVM;\n \nFIG.', '18\n is a cross validation diagram of auto-encoder with SVM;\n \nFIG.', '19\n shows original and reconstructed STC 2D images for label 1 (Cubes 1 through 250) for Cube #25;\n \nFIG.', '20\n shows original and reconstructed STC 2D images for label 2 (Cubes 151-300) for Cube #201;\n \nFIG.', '21\n shows original and reconstructed STC 2D images for label 3 (Cubes 301-450) for Cube #325;\n \nFIG.', '22\n shows original and reconstructed STC 2D images for label 4 (Cubes 451-600) for Cube #476;\n \nFIG.', '23\n shows original and reconstructed STC 2D images for label 5 (Cubes 601-750) for Cube #667;\n \nFIG.', '24\n shows a classification result using auto-encoding plus SVM (AE+SVM) on unlabeled multiband multimodality data (Scenario 1) where the data used is as given on \nFIG. \n12\n;\n \nFIG.', '25\n shows a classification result using AE+SVM on unlabeled multiband multimodality data (Scenario 2) where the data used is as given on \nFIG.', '13', ';\n \nFIGS.', '26\na\n-\n26\nh \ndepict support vectors corresponding to various multiband modalities for five labels of interest;\n \nFIG.', '27\n depict Mel-frequency cepstral coefficient (MFCC) methods;\n \nFIGS.', '28\na \nand \n28\nb \nrespectively depict convolutional neural network (CNN) parameters for monopole and dipole data;\n \nFIG.', '29\n depicts dimensions of single stream CNN (dipole input);\n \nFIGS.', '30\na \nand \n30\nb \nrespectively depict STC 2D images (3 dipole bands) used in generating the activation maps, and filter weights computed from the first convolution stage;\n \nFIGS.', '31\na \nand \n31\nb \nrespectively depict activation maps for dipole inputs after a CONV1 layer and after a CONV2 layer;\n \nFIGS.', '32\na \nand \n32\nb \nrespectively depicts STC 2D images (2 monopole bands) used in generating the activation maps, and filter weights computed from the first convolution operation;\n \nFIGS.', '33\na \nand \n33\nb \nrespectively depict monopole activation maps after a CONV1 layer and after a CONV2 layer;\n \nFIGS.', '34\na\n-\n34\nc \nare two stream CNN frameworks for combining results from monopole and dipole data; and\n \nFIGS.', '35\na \nand \n35\nb \ndepict classification of multiband multimodality data from Scenario 1 & 2 using CNN methods, with the first panel of both \nFIGS.', '35\na \nand \n35\nb \nshowing classification using two band monopole data, the second panel showing classification results using three band dipole data, and the last three panels showing three methods for combining two streams of data, respectively.', 'DETAILED DESCRIPTION', 'The particulars shown herein are by way of example and for purposes of illustrative discussion of the embodiments of the subject disclosure only and are presented in the cause of providing what is believed to be the most useful and readily understood description of the principles and conceptual aspects of the subject disclosure.', 'In this regard, no attempt is made to show structural details in more detail than is necessary for the fundamental understanding of the subject disclosure, the description taken with the drawings making apparent to those skilled in the art how the several forms of the subject disclosure may be embodied in practice.', 'Furthermore, like reference numbers and designations in the various drawings indicate like elements.', 'In the subject disclosure, machine learning approaches are presented to extract and train on features of sonic data over depth using any of a variety of algorithms to identify several proposed classes for two annuli (“annulus A” and “annulus B”) given the availability of data with labels for those classes.', 'Thus, as suggested in \nFIGS. \n1\n, at \n100\n, \n102\n, \n104\n, \n106\n, and \n108\n, a machine learning module is trained with a training data set having labeled samples to learn features and discriminators for the state of annuli behind casings of a wellbore.', 'More particularly, at \n100\n, sonic data is collected or synthesized with respect to a borehole having a plurality of casings with annuli surrounding the casings.', 'The sonic data that is collected may include one or both of monopole and dipole sonic data.', 'At \n102\n, the sonic data may be divided into multiple frequency bands, and the data is processed to obtain 2D STC time-slowness maps or 1D slowness projection vectors.', 'At \n104\n, labels for various status conditions of interest of the annuli surrounding the casings are generated.', 'The labels and the preprocessed sonic data in the form of the STC maps or vectors are then used at \n106\n to create a training dataset of labeled samples of 1D and/or 2D STC outputs for one or more frequency bands of the monopole and/or dipole data.', 'The training dataset is then used to train a machine learning module which receives and trains on the information.', 'Examples of suitable machine learning modules include a support vector machine (SVM), an auto-encoder—SVM combination, or a convolutional neural network (CNN).', 'To ascertain whether the machine learning module is properly trained, a cross-validation set of preprocessed STC 2D or projected 1D information (e.g., a portion of the training dataset) may be utilized at \n110\n.', 'Regardless, once the machine learning module is suitably trained, an acoustic borehole tool may be placed at \n120\n at a location in a borehole having a plurality of casings with annuli surrounding the casings, and the (monopole and/or dipole) transmitter(s) may be activated at \n130\n so that acoustic energy is radiated into the casings surrounding the borehole and waveforms are detected at the detectors of the acoustic borehole tool.', 'At \n140\n, the detected waveforms are preprocessed using slowness-time-coherence (STC) processing to obtain a 2D STC map, or a 1D STC vector projection.', 'At \n150\n, the 2D STC map or 1D STC vector projection is provided to the trained machine learning module, and at \n160\n, the machine learning module provides an answer product as to the states of the annuli behind the casings of the wellbore.', 'As suggested in \nFIG.', '1\n, the borehole tool may be moved at \n170\n to another location in the borehole where the transmitter(s) may be activated and waveforms detected at \n130\n, STC processing conducted at \n140\n, and resulting STC map or vector projection provided to the trained machine learning module at \n150\n so that additional answer product may be generated at \n160\n for that location in the borehole.', 'The answer products for one or more depths in the borehole may be used at \n180\n in a decision regarding the necessity or not of taking remedial action with respect to the borehole.', 'Thus, by way of example only, if it is determined that both annuli are not properly cemented in a wellbore which is going to be abandoned, a decision may be made to remove the casings from the wellbore prior to injecting cement into and capping the wellbore.', 'The following disclosure relates to details of implementing aspects of certain elements of \nFIG.', '1\n.', 'FIG.', '1\na \ndepicts a wireline tool such as the Sonic Scanner with a multiplicity of transmitters and a 2-D axial and azimuthal array of receivers which may be used in conjunction with the activation of transmitters so that acoustic energy is radiated into the casings surrounding the borehole and detecting waveforms at the detectors of the acoustic borehole tool at \n130\n.', 'It may also be used in conjunction with the collection of sonic data at \n100\n for the purpose of generating training datasets at \n106\n.', 'The Sonic Scanner has the capability of acquiring wideband sonic modal logging measurements with the signal frequency ranging from 200 Hz to 12 kHz.', 'In a “Record-All-Data” acquisition mode of the tool, the measurement is very rich in data as multiple borehole modes are excited and detected using the multiple transmitters and individual recordings of receivers in the 2-D array.', 'These include the monopole mode that can be excited both at low and high frequencies and with far and near (to the receiver array) monopole sources, and the dipole mode that can be excited at two orthogonal directions yielding cross-dipole excitation as seen in \nFIG.', '1\nb\n.', 'While these sonic measurements have not previously been used for well integrity applications and have some of the same limitations such as a lack of azimuthal resolution (monopole) or only two quadrant resolution (dipole), low axial resolution (of the order of 1 m), and sensitivity to multiple mechanisms over the probed region, they have the capability to probe beyond the first casing and annulus, and therefore bring the capacity for a diagnosis of the annuli in multiple casing configurations.', 'This is particularly true if the inner casing and annulus state are known or determined by another measurement such as the high resolution ultrasonic from the Isolation Scanner.\n \nFIG.', '2\n depicts a typical multiple casing configuration in an oil and gas well in which the acoustic borehole tool is placed at \n120\n of \nFIG.', '1\n.', 'A series of casings are deployed inside the wellbore in telescopic fashion.', 'The annulus behind each casing is partially or fully filled with cement to assure well integrity and zonal isolation of various formations layers.', 'In some situations, it may be necessary to evaluate the annular fill and bond in cement behind multiple overlapping casings with a tool deployed in the fluid filled innermost casing.', 'Examples of potential diagnoses of annulus A (behind first casing; i.e., between the first and second casings) and annulus B (behind second casing) are depicted for a dual casing scenario.', 'In one aspect, in assessing the necessity or desirability of taking remedial action with respect to the borehole, those of skill in the art may be interested in some or all of the following scenarios or answer products (such as are obtained at \n160\n):', '1.', 'Full bond (both annuli are cemented);\n \n2.', 'The inner annulus (annulus A) is liquid, and the outer annulus (annulus B) is cemented;\n \n3.', 'Annulus B is liquid, and annulus A is cemented;\n \n4.', 'Both annuli are liquid-filled;\n \n5.', 'Barite sag in one or both annuli; and\n \n6.', 'Partial bond in one or both annuli.', 'Other scenarios may also be of interest to those of skill in the art.', 'In one embodiment, the six scenarios are considered for formations having distinct types of acoustic properties, such as formations that are “super-fast”, “fast”, “medium”, and “slow” (all referring to the velocity of sound waves in the formation), for the purpose of encompassing a range of possible sonic responses that could provide identifying features.', 'Typical range values for these formation types are summarized in Table 1 below, where DT\nc \nis the compressional slowness (with slowness being the inverse of velocity), DT\ns \nis the shear slowness, and ρ is the formation density.', 'For example, the type of formation (slow vs. fast) imposes constraints on the ranges of frequencies/slownesses in which to search for the distinguishing features as described below.', 'Hence, scenarios or features may be defined within a particular formation type, leading to a total of twenty-four classes where there are six scenarios and four formation types, (e.g., double casing with cemented annulus A and liquid annulus B, in a fast formation, etc.).', 'This framework can be extended to deal with partial bond cases in more detail, by determining at which interface the disbonding occurs.', 'With more scenarios, the number of classes increases accordingly.', 'In the following disclosure, methodologies are described to leverage machine learning in order to generate an indicator (answer product at \n160\n of \nFIG.', '1\n) for the onset of a free pipe (i.e., uncemented casing) for one or more strings in the multi-string cased hole.', 'The methodologies and conclusions are demonstrated on synthetic data.', 'In addition, depth dependent displays of dispersion and slowness semblance projections for identifying transitions in the annuli in such scenarios are described.', 'Synthetic Dataset Description\n \nSynthetic data which may be used for training a machine learning module may be generated through modeling software (\n100\n of \nFIG.', '1\n).', 'In one embodiment, the synthetic data may pertain to measurements obtained by a Sonic Scanner tool.', 'Acquired simulated data could be obtained from monopole and/or dipole sources, with \nFIGS.', '3\na \nand \n3\nb \nrespectively depicting monopole and dipole modalities excited by a Sonic Scanner tool, together with their waveforms and direction of source firing.', 'In the posited classification problem, for illustration purposes, classification of two sections encompassing double casing string scenarios with annulus A and B is considered for the following five scenarios: (A=Hard cement, B=Hard cement); (A=Lite cement, B=Lite cement); (A=Water, B=Hard cement), (A=Water, B=Lite cement), and (A=Water, B=Water).', 'Each scenario is provided as a “label” (\n104\n of \nFIG.', '1\n).', 'For example, the label W-HC corresponds to the third listed scenario with annulus A (between two casings) being water-filled (W) and annulus B (between the second casing and the formation) having hard cement (HC).', 'The goal is to identify these sections and the transitions.', 'HC, LC, and W may be used to represent hard cement, lite cement, and water, respectively.', 'Thus, as suggested above, the label W-HC may be used to indicate water in annulus A and hard cement in annulus B.\n \nFor purposes of illustration, and by way of example only, for each label and modality (monopole/dipole), twenty-five synthetic sonic data cubes (time, receiver, depth) are generated for the training step in the learning framework.', 'The nominal values and range of physical properties corresponding to each fill and formation type are shown in Table 1.\n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \nTable of acoustic properties with nominal values and ranges\n \n \n \nfor formation types and annular and borehole fill considered\n \n \n \nfor scenarios being tested.', 'For purpose of generating synthetics\n \n \n \nfor training, a range of values around each nominal value\n \n \n \nfor formation types is used and sampled to mimic typical\n \n \n \nvariation in natural sub-surface formations.', 'FORMATION\n \n \n \n \n \n \n \n \n \n \n \nType\n \nDT\nc \n(μs/ft)\n \nDT\ns \n(μs/ft)\n \nρ (g/cm\n3\n)', 'Super fast\n \n62.5 ± 10\n \n108.2 ± 20\n \n2.58 ± 0.1\n \n \n \nFast\n \n\u2009\u200280 ± 10\n \n\u2009\u2002160 ± 20\n \n\u20022.3 ± 0.1\n \n \n \nMedium 1\n \n\u2009100 ± 10\n \n\u2009\u2002240 ± 20\n \n\u20022.2 ± 0.1\n \n \n \nMedium 2\n \n\u2009120 ± 10\n \n\u2009\u2002250 ± 20\n \n\u20022.2 ± 0.1\n \n \n \n \n \n \n \n \nANNULUS\n \n \n \n \n \n \n \n \n \n \n \nContent\n \nDT\nc \n(μs/ft)\n \nDT\ns \n(μs/ft)\n \nρ (g/cm\n3\n)\n \n \n \nHard Cement\n \n\u200282\n \n149\n \n2\n \n \n \nLite Cement\n \n157\n \n406\n \n1.43\n \n \n \nMud in ansplus A\n \n260\n \ninf\n \n1.52\n \n \n \nMud in anmulus B\n \n220\n \ninf\n \n1.37\n \n \n \nBorehole Mud\n \n105\n \ninf\n \n1.2\n \n \n \n \n \n \n \n \n \n \nAt each location (corresponding to each data cube), the waveforms are sampled from 30 depth frames, and using a thirteen-receiver array (as shown in \nFIGS.', '1\na \nand \n1\nb\n).', 'For each waveform, there are 601 time samples.', 'For simplicity, only a subset of the generated 25 data cubes are used.', 'The above-mentioned cubes (or runs) of data, after appropriate processing (described hereinafter) are used to generate a “labeled dataset”, which are used for training the model (\n106\n of \nFIG.', '1\n).', 'The labeled dataset is subsequently split into a “training set” (\n108\n of \nFIG.', '1\n), used to learn the representation of the data, and a “cross-validation” (CV) Set, that may be used (at \n110\n of \nFIG.', '1\n) to compute the classification accuracy of the trained model, given the unseen new data, for which the exact labels are known as suggested by \nFIG.', '5\n.', 'TABLE 2\n \n \n \n \n \n \n \n \nScenarios and depth indices used to create Testing dataset.', 'Monopole and Dipole Data\n \n \n \n \n \n \n \n \n \n \n \n \nScenario\n \nSample range\n \nLabel\n \nAnnulus A\n \nAnnulus B\n \n \n \n \n \n \nScene 1\n \n\u20021:65\n \n1\n \nHC\n \nHC\n \n \n \n \n\u200266:135\n \n3\n \nW\n \nHC\n \n \n \n \n136:200\n \n5\n \nW\n \nW\n \n \n \nScene 2\n \n\u20021:75\n \n2\n \nLC\n \nLC\n \n \n \n \n\u200276:125\n \n4\n \nW\n \nLC\n \n \n \n \n126:200\n \n5\n \nW\n \nW\n \n \n \n \n \n \n \n \n \n \nFor testing purposes, two synthetic test sets (referred to here as “Scenario 1” or “Scene 1”, and “Scenario 2” or “Scene 2”) are generated, encompassing both monopole and dipole modalities, and representing data received over 200 depth frames.', 'These sets will be referred to as “Test data”, or “Unlabeled data”.', 'The detailed list of labels and their depth ranges for the two scenarios are shown in Table 2.', 'The classification accuracy of the learned network may be assessed on the unlabeled (test) datasets since labels have been created for the two scenarios.', 'However, in real applications the network will only have access to the labels for training and cross-validation from prior modeling, expert elicitation, or previous data labeling and acquisition.', 'The “ground truth” labels as a function of depth for the two scenarios of Table 2 are shown in \nFIG.', '4\n.', 'In the simulations, the formation can vary over a range of slownesses from 100-240 μs/ft to mimic typical bedding and variation in sub-surface formations.', 'Data Preprocessing\n \nAs previously indicated, the machine learning module is trained with a set of preprocessed acoustic information.', 'Embodiments of data preprocessing that lead to the specification of the classification methods are described hereinafter.', 'Bandpass Filters\n \nCompared to synthetic data sets, the real data usually contains some artifacts and noise and may not match the ideal conditions of the modeled data.', 'To make classifiers more robust, and to mimic imperfect field data, data with added noise to the signal (e.g., SNR=1 dB, and SNR=10 dB) may be utilized.', 'To account for the richness of modes seen in the field data, bandpass filters are optionally used at \n102\n of \nFIG.', '1\n to preprocess the waveforms.', 'In one embodiment, Butterworth filters are used for preprocessing: for monopole data, Butterworth filters with two bands are used, with bands picked as [1,5] kHz, and [5,12] kHz; and for dipole data, three frequency bands are used, namely: [1,2.5] kHz, [2.5,5.5] kHz, and', '[5.5,12] kHz respectively.', 'The plots of the Butterworth filters are illustrated in \nFIGS.', '6\na \nand \n6\nb \nshowing three Butterworth filters with different cutoff frequencies on the normalized frequency scale in \nFIG.', '6\na \nand on the original frequency scale in \nFIG.', '6\nb.', 'STC 2D Images\n \nOne manner of (pre-)processing the acoustic array data (at \n102\n) is the slowness time coherence (STC) approach described in co-owned C. V. Kimball and T. L. Marzetta, “Semblance processing of borehole acoustic array data,” \nGeophysics \nVol. 49, No. 3, (March 1984) pp.', '274-281; U.S. Pat.', 'No. 4,594,691 to Kimball et al., entitled “Sonic Well Logging”, and S. Bose, et al., “Semblance criterion modification to incorporate signal energy threshold,” \nSEG Annual Meeting \n(2009), each of which is hereby incorporated by reference herein in its entirety.', 'Although this approach is normally used in dispersive waves, for non-dispersive waves, it can be processed non-dispersively by bandpass filtering the data via multiple frequency bands.', 'See, V. Rama Rao and M. N. Toksoz, “Dispersive wave analysis—method and applications,” \nEarth Resources Laboratory Industry Consortia Annual Report, MIT, \n2005, which is hereby incorporated by reference herein in its entirety.', 'Thus, STC processing may still be used after bandpass filtering.', 'Standard STC processing generally involves taking the data of a multi-receiver sonic tool, stacking the moveout-corrected receiver outputs by depth level and identifying selected peaks of a coherence measure of the result, and producing logs of sonic properties of the formation versus borehole depth on the basis of selected parameters of the peaks.', 'More particularly, the generation of STC 2D images is explained in detail in the previously incorporated publications to Kimball et al., and to S. Bose et al.', 'Examples of STC 2D images are illustrated in the top portions of \nFIGS.', '19\n-\n23\n, where the first row shows the STC 2D images from two different frequency bands of monopole data and from three different frequency bands of dipole data.', 'In \nFIGS.', '19\n-\n23\n, the x axis denotes the slowness in μs/ft, while the y axis denotes the time in μs.', 'The value of each pixel (typically represented by color or shade) is called “semblance”.', 'STC 1D Projection\n \nWhen using Support Vector Machines (SVM) for classification as described hereinafter, it may be useful to vectorize the STC 2D images.', 'A straightforward way to vectorize the images is to project STC 2D images onto the slowness axis.', 'All that is required is to choose a window representing primary arrivals for projection and compute the maximum value along the time axis for each slowness value and use them as a 1D vector.', 'In \nFIG.', '7\na\n, a sonic tool is shown gathering data, plots of which are shown in \nFIG.', '7\nb\n.', 'An STC 2D image generated from the data of \nFIG.', '7\nb \nis shown in \nFIG.', '7\nc\n, with the projection window marked.', 'An STC 1D vector generated from a projection of the STC 2D image of \nFIG.', '7\nc \nis shown in \nFIG.', '7\nd\n.', 'Radon Images and Projections\n \nRadon transforms are closely related to standard STC transforms.', 'In STC processing, all amplitude information is removed in favor of a normalized semblance which takes values between zero and one, whereas in Radon processing the amplitude information is retained.', 'See, Radon, J. “On the Determination of Functions from their Integral Values Along Certain Manifolds”, IEEE Transactions on Medical Imaging 5:4 pp.', '170-176 (1986).', 'Accordingly, standard STC processing may be called a normalized version of Radon processing, or conversely, Radon processing may be called a non-normalized version of standard STC processing.', 'Therefore, for purposes of the specification and claims herein, the term “STC” is to be understood broadly to include Radon processing as well.', 'For purposes of brevity, generally only the results of the normalized STC processing are set forth.', 'In embodiments, Radon transforms are used to obtain 2D (“non-normalized STC”) maps (images) in one or more frequency bands.', 'In other embodiments, the 2D maps obtained via Radon transforms may be projected to obtain a 1D non-normalized STC vector.', 'Labeling\n \nIn embodiments, each 2D (normalized or non-normalized) STC map (or corresponding STC 1D (normalized or non-normalized) vector projection) in the training set is assigned a label corresponding to the annular condition (scenario) in which the data was acquired for real data or for generated for synthetic data.', 'Examples of such labels were previously described.', 'Classification Using Support Vector Machines\n \nIn machine learning, Support Vector Machine (SVM) is a supervised learning model with associated learning algorithms which analyze data used for binary class classification and regression.', 'The present disclosure, however, deals with a multiclass classification problem.', 'Thus, a strategy of one-to-all multiclass SVM may be utilized at \n108\n.', 'See, C.-W. Hsu and C.-J. Lin, “A comparison of methods for multiclass support vector machines.”', 'IEEE Trans Neural Network\n, Vol. 13, No. 2, pp.', '415-425, (2002).', 'Assume a training set is available with l samples paired with their labels as: (x\n1\n,y\n1\n), . . .', ',(x\nl\n,y\nl\n), where x\ni \n∈{1, . . .', 'l} are the training sets and y\ni \n∈{1, . .', '., l} are the labels.', 'The m-th SVM solves the following problems:\n \n \n \n \n \n \n \n \n \n \nmin\n \n \n \nw\n \nm\n \n \n,\n \n \nb\n \nm\n \n \n,\n \n \nε\n \nm\n \n \n \n \n \n1\n \n2\n \n \n\u2062\n \n \n \n(\n \n \nw\n \nm\n \n \n)\n \n \nT\n \n \n\u2062\n \n \nw\n \nm\n \n \n \n+\n \n \nC\n \n\u2062\n \n \n \n∑\n \n \ni\n \n=\n \n1\n \n \nl\n \n \n \n \n \nε\n \ni\n \nm\n \n \n \n \n \n \n \n \n(\n \n1\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \n \ns\n \n.\n \nt\n \n.', '(\n \n \nw\n \nm\n \n \n)\n \n \nT\n \n \n \n\u2062\n \n \nϕ\n \n\u2061\n \n(\n \n \nx\n \ni\n \n \n)\n \n \n \n+\n \n \nb\n \nm\n \n \n \n≥\n \n \n1\n \n-\n \n \nε\n \ni\n \nm\n \n \n \n \n,\n \n \n \nif\n \n\u2062\n \n \n \n \n \n \n \n\u2062\n \n \ny\n \ni\n \n \n \n=\n \nm\n \n \n,\n \n \n \n \n \n \n \n \n \n \n \n \n(\n \n \nw\n \nm\n \n \n)\n \n \nT\n \n \n\u2062\n \n \nϕ\n \n\u2061\n \n(\n \n \nx\n \ni\n \n \n)\n \n \n \n+\n \n \nb\n \nm\n \n \n \n≤\n \n \n \nε\n \ni\n \nm\n \n \n-\n \n1\n \n \n \n,\n \n \n \nif\n \n\u2062\n \n \n \n \ny\n \ni\n \n \n \n≠\n \nm\n \n \n,\n \n \n \n \n \n \n \n \n \nε\n \ni\n \nm\n \n \n≥\n \n0\n \n \n,\n \n \ni\n \n=\n \n1\n \n \n,\n \n…\n \n \n \n,\n \nl\n \n,\n \n \n \n \n where the training data x\ni \nare mapped to a higher dimensional space by the function ϕ, w\nm \nand b\nm \nare the SVM weight and bias coefficients respectively, ε\nm \nare margin coefficients in a penalty term CΣ\ni=1\nl\nε\ni\nm \nwith a penalty parameter C and the superscript T represents the transposed quantity.', 'The penalty term is used to address the general case when data is not linearly separable.', 'The coefficients are estimated as part of the learning process by minimizing the expression in equation 1.', 'After solving it, there are k possible decision functions: (w\n1\n)\nT\nϕ(x)+b\n1\n, . . .', ',(w\nk\n)\nT\nϕ(x)+b\nk\n.', 'It may be said that x belongs to the class which has the largest value of the decision function: \n \n \n \n \n \n \n \n \n \nclass\n \n\u2062\n \n \n \nof\n \n\u2062\n \n \n \n \n(\n \nx\n \n)\n \n \n \n≡\n \n \n \n \narg\n \n\u2062\n \nmax\n \n \n \n \nm\n \n=\n \n1\n \n \n,\n \n…\n \n \n \n,\n \nk\n \n \n \n\u2062\n \n \n(\n \n \n \n \n \n(\n \n \nw\n \nm\n \n \n)\n \n \nT\n \n \n\u2062\n \n \nϕ\n \n\u2061\n \n(\n \nx\n \n)\n \n \n \n+\n \n \nb\n \nm\n \n \n \n)\n \n \n \n \n \n \n \n(\n \n2\n \n)\n \n \n \n \n \n \n \n \nFull Frequency Band STC 2D and STC 1D Data Classification Using Support Vector Machine Classifier\n \nVarious combinations of full frequency band monopole and dipole data used for training and testing are analyzed.', 'For example, Table 3 provides a summary of the monopole data sets used for training and validation, while Table 5 provides a summary of the dipole data sets used for training and validation.', 'The monopole data sets include: clean data (no noise added to the waveforms); and data with additive noise (SNR=1 dB, and SNR=10 dB).', 'Data cubes 1:2:25 were used for training, and cubes 2:2:24 for validation.', 'In Table 3, classification rate (averaged over all 5 labels) is reported on the cross-validation (CV) dataset.', 'Additionally, included are examples where only one cube (with noisy or clean data) was used for training.\n \n \n \n \n \n \n \n \nTABLE 3\n \n \n \n \n \n \n \n \nSummary of monopole datasets used for training and validation.', 'Classification rate is computed on validation dataset.', 'MONOPOLE DATA\n \n \n \n \n \n \n \n \n \n \n \n \n \nValidation\n \nClassification\n \n \n \n \nTrain/Model Dataset\n \nDataset\n \nRate on CV data\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nclean data\n \nclean data\n \n1\n \n \n \n \nclean data\n \nSNR1\n \n0.2\n \n \n \n \nclean data\n \nSNR10\n \n0.2\n \n \n \n \nSNR1\n \nclean data\n \n0.945\n \n \n \n \nSNR1\n \nSNR1\n \n0.735\n \n \n \n \nSNR1\n \nSNR10\n \n1\n \n \n \n \nSNR10\n \nclean data\n \n0.8\n \n \n \n \nSNR10\n \nSNR1\n \n0.9994\n \n \n \n \nSNR10\n \nSNR10\n \n0.9917\n \n \n \n \nclean data, 1 cube\n \nclean data\n \n1\n \n \n \n \nclean data, 1 cube\n \nSNR1\n \n0.2\n \n \n \n \nclean data, 1 cube\n \nSNR10\n \n0.2\n \n \n \n \nSNR1, 1 cube\n \nclean data\n \n0.6372\n \n \n \n \nSNR1, 1 cube,\n \nSNR1\n \n0.9863\n \n \n \n \nSNR1, 1 cube\n \nSNR10\n \n0.9194\n \n \n \n \nSNR10, 1 cube\n \nclean data\n \n0.5806\n \n \n \n \nSNR10, 1 cube\n \nSNR1\n \n0.6422\n \n \n \n \nSNR10, 1 cube\n \nSNR10\n \n1\n \n \n \n \n \n \n \n \n \n \n \nThe learned models are used to classify the unlabeled data for two scenarios of interests (Scenario 1, and Scenario 2), with ground truth labels designed as in Table 2.', 'Classification rates corresponding to the two scenarios are provided in Table 4.\n \n \n \n \n \n \n \n \nTABLE 4\n \n \n \n \n \n \n \n \nClassification of two unlabeled monopole datasets (Scenario 1 and 2).', 'Classificationrate is computed based on ground truth labels from Table 2.\n \n \n \nMONOPOLE DATA\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nClassi-\n \n \nClassi-\n \n \n \n \n \nfication\n \n \nfication\n \n \n \nModel Dataset\n \nTest set\n \nRate\n \nTest set\n \nRate\n \n \n \n \n \n \nclean data\n \nscene 1, clean data\n \n1\u2003\u2003\u2009\n \nscene 2, clean data\n \n1\u2003\u2002\u2009\n \n \n \nclean data\n \nscene 1, SNR1\n \n0\u2003\u2003\u2009\n \nscene 2, SNR1\n \n0.375\n \n \n \nclean data\n \nscene 1, SNR10\n \n0\u2003\u2003\u2009\n \nscene 2, SNR10\n \n0.375\n \n \n \nSNR1\n \nscene 1, clean data\n \n1\u2003\u2003\u2009\n \nscene 2, clean data\n \n0.75\u2002\n \n \n \nSNR1\n \nscene 1, SNR1\n \n1\u2003\u2003\u2009\n \nscene 2, SNR1\n \n1\u2003\u2002\u2009\n \n \n \nSNR1\n \nscene 1, SNR10\n \n1\u2003\u2003\u2009\n \nscene 2, SNR10\n \n0.095\n \n \n \nSNR10\n \nscene 1, clean data\n \n1\u2003\u2003\u2009\n \nscene 2, clean data\n \n0.75\u2002\n \n \n \nSNR10\n \nscene 1, SNR1\n \n1\u2003\u2003\u2009\n \nscene 2, SNR1\n \n1\u2003\u2002\u2009\n \n \n \nSNR10\n \nscene 1, SNR10\n \n1\u2003\u2003\u2009\n \nscene 2, SNR10\n \n0.995\n \n \n \nclean data, \n \nscene 1, clean data\n \n1\u2003\u2003\u2009\n \nscene 2, clean data\n \n1\u2003\u2002\u2009\n \n \n \n1 cube\n \n \n \n \n \n \n \nclean data, \n \nscene 1, SNR1\n \n0\u2003\u2003\u2009\n \nscene 2, SNR1\n \n0.375\n \n \n \n1 cube\n \n \n \n \n \n \n \nclean data, \n \nscene 1, SNR10\n \n0\u2003\u2003\u2009\n \nscene 2, SNR10\n \n0.375\n \n \n \n1 cube\n \n \n \n \n \n \n \nSNR1, 1 cube\n \nscene 1, clean data\n \n0.6750\n \nscene 2, clean data\n \n0.75\u2002\n \n \n \nSNR1, 1 cube,\n \nscene 1, SNR1\n \n0.98\u2003\n \nscene 2, SNR1\n \n1\u2003\u2002\u2009\n \n \n \nSNR1, 1 cube\n \nscene 1, SNR10\n \n1\u2003\u2003\u2009\n \nscene 2, SNR10\n \n0.86\u2002\n \n \n \nSNR10, 1 cube\n \nscene 1, clean data\n \n0.62\u2003\n \nscene 2, clean data\n \n0.75\u2002\n \n \n \nSNR10, 1 cube\n \nscene 1, SNR1\n \n0.73\u2003\n \nscene 2, SNR1\n \n0.775\n \n \n \nSNR10, 1 cube\n \nscene 1, SNR10\n \n1\u2003\u2003\u2009\n \nscene 2, SNR10\n \n1\u2003\u2002\u2009\n \n \n \n \n \n \n \n \n \n \nThe same method is utilized with respect to the dipole source data, and report classification rates on cross-validation, and test set data are set forth in Tables 5 and 6.\n \nFIG.', '8\n is a classification result (map) using SVM on unlabeled full frequency band monopole data for Scenario 1 over a depth of interest.', 'FIG.', '9\n is a classification result (map) using SVM on unlabeled full frequency band monopole data for Scenario 2 over a depth of interest.', 'FIG.', '10\n is a classification result (map) using SVM on unlabeled full frequency band dipole data for Scenario 1 over a depth of interest.', 'FIG.', '11\n is a classification result (map) using SVM on unlabeled full frequency band dipole data for Scenario 2 over a depth of interest.', 'TABLE 5\n \n \n \n \n \n \n \n \nSummary of dipole datasets used for training and validation.', 'Classification rate is computed on validation dataset.', 'DIPOLE DATA\n \n \n \n \n \n \n \n \n \n \n \n \nTrain/Model\n \n \nClassification\n \n \n \n \nDataset\n \nValidation Dataset\n \nRate on CV data\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nclean data\n \nclean data\n \n1\n \n \n \n \nclean data\n \nSNR1\n \n0.4228\n \n \n \n \nSNR1\n \nclean data\n \n1\n \n \n \n \nSNR1\n \nSNR1\n \n0.9983\n \n \n \n \nclean data, 1 cube\n \nclean data\n \n1\n \n \n \n \nclean data, 1 cube\n \nSNR1\n \n0.4461\n \n \n \n \nSNR1, 1 cube\n \nclean data\n \n0.9878\n \n \n \n \nSNR1, 1 cube\n \nSNR1\n \n0.9561\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nTABLE 6\n \n \n \n \n \n \n \n \nClassification of two unlabeled dipole datasets (Scenario 1 and 2).', 'Classification rate is computed based\n \n \n \non ground truth labels from Table 2.\n \n \n \nDIPOLE DATA\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nClassi-\n \n \nClassi-\n \n \n \nModel\n \n \nfication\n \n \nfication\n \n \n \nDataset\n \nTest set\n \nRate\n \nTest set\n \nRate\n \n \n \n \n \n \nclean data\n \nscene 1, clean data\n \n1\u2003\u2002\u2009\n \nscene 2, clean data\n \n1\u2003\u2002\u2009\n \n \n \nclean data\n \nscene 1, SNR1\n \n0.61\u2002\n \nscene 2, SNR1\n \n0.39\u2002\n \n \n \nSNR1\n \nscene 1, clean data\n \n1\u2003\u2002\u2009\n \nscene 2, clean data\n \n1\u2003\u2002\u2009\n \n \n \nSNR1\n \nscene 1, SNR1\n \n1\u2003\u2002\u2009\n \nscene 2, SNR1\n \n1\u2003\u2002\u2009\n \n \n \nclean data, \n \nscene 1, clean data\n \n1\u2003\u2002\u2009\n \nscene 2, clean data\n \n1\u2003\u2002\u2009\n \n \n \n1 cube\n \n \n \n \n \n \n \nclean data, \n \nscene 1, SNR1\n \n0.565\n \nscene 2, SNR1\n \n0.315\n \n \n \n1 cube\n \n \n \n \n \n \n \nSNR1, 1 cube\n \nscene 1, clean data\n \n1\u2003\u2002\u2009\n \nscene 2, clean data\n \n1\u2003\u2002\u2009\n \n \n \nSNR1, 1 cube,\n \nscene 1, SNR1\n \n0.995\n \nscene 2, SNR1\n \n0.965\n \n \n \n \n \n \n \n \n \n \nMultiband STC 2D and STC 1D Data Classification Using Support Vector Machines\n \nIn one aspect, classification results can be improved by using Butterworth filters.', 'As previously mentioned, STC is a non-dispersive processing approach, so the data may be band-passed through multiple frequency bands such that the output of each band can be processed non-dispersively.', 'Classification rates for each label of Scenario 1 and Scenario 2 are reported separately in Table 7.', 'Frequency ranges for monopole and dipole data may be selected as follows.', 'For monopole data, Butterworth filters with two frequency bands are used: BPF1=[1,5] kHz, and BPF2=[5,12] kHz.', 'For dipole data, three frequency bands are used; BPF1=[1,2.5] kHz, BPF2=[2.5,5.5] kHz, and BPF3=[5.5,12] kHz.', 'Additionally, the data from monopole and dipole can be jointly combined within these frequency bands to enhance the SVM classifier (see Table 7).', 'TABLE 7\n \n \n \n \n \n \n \n \nClassification results for CV dataset and Scenario 1 and\n \n \n \nScenario 2 using multiband monopole and dipole data.', 'Classi-\n \nClassi-\n \n \n \n \n \nClassification\n \nfication\n \nfication\n \n \n \n \n \nRate per Label\n \nRate-\n \nRate-\n \n \n \n \nDataset\n \n(1-5) on CV Data\n \nScene 1\n \nScene 2\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nMONO BPF1\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \n \nMONO BPF2\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \n \nDIP BPF1\n \n0.9867, 0.94, 0.9267,\n \n0.92\n \n0.97\n \n \n \n \n \n0.76, 0.9867\n \n \n \n \n \n \nDIP BPF2\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \n \nDIP BPF3\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \n \nMONO BPF1-2\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \n \nDIP BPF 1-3\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \n \nMONO + DIP\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \n \n \n \n \n \nData used for training falls in one of the groups of multiband data: for monopole source, BPF1 = [1, 5] kHz, and BPF2 =', '[5, 12] kHz, and for dipole data, three frequency bands are BPF1 =', '[1, 2.5] kHz, BPF2 =', '[2.5, 5.5] kHz, and BPF3 =', '[5.5, 12] kHz.\n \n \n \n \n \n \n \nFIGS.', '12\n and \n13\n show classification maps over the depth interval of interest.', 'More particularly, \nFIG.', '12\n shows classification results using monopole bandpass filter 1 (MONO BPF1) (e.g., STC-1D) data (panel 1), monopole BPF2 data (panel 2), dipole BPF1 data (panel 3), monopole BPF2 data (panel 4), monopole BPF3 data (panel), all monopole bands (MONO BPF1-2) (panel 6), all dipole bands (DIP BPF1-3) (panel 7), and all monopole and dipole bands (panel 8), all for Scenario 1.', 'Similarly, \nFIG.', '13\n shows classification results using monopole BPF1 data (panel 1), monopole BPF2 data (panel 2), dipole BPF1 data (panel 3), monopole BPF2 data (panel 4), monopole BPF3 data (panel), all monopole bands (MONO BPF1-2) (panel 6), all dipole bands (DIP BPF1-3) (panel 7), and all monopole and dipole bands (panel 8), all for Scenario 2.', 'Feature Extractors\n \nAccording to embodiments, feature extractors such as auto-encoders and Mel-Frequency Cepstral Coefficients (MFCC) may be used in combination with Support Vector Machines for classification.', 'Auto-Encoders\n \nAn auto-encoder is an artificial neural network for learning efficient representations.', 'It consists of two parts: an encoder and a decoder.', 'See, e.g., F. Chollet, “Building autoencoders in keras,” in \nThe Keras Blog \n(2016).', 'Because massive training datasets are not necessarily being utilized, an auto-encoder will be designed using all the datasets available (the test sets and the training sets) for learning better features.', 'The mappings of the encoder and decoder are defined as: \n \n \n \nϕ:x→ρand ψ:ρ→x·\n \n \n \n \n \nThe features ρ generated from the auto encoder are called bottleneck features which will also be sent to the decoder for reconstruction.', 'Then, all that is required is to find the parameters for the following optimization problem:\n \n \n \n \n \n \n \n \n \n(\n \n \n \nϕ\n \n^\n \n \n,\n \n \nψ\n \n^\n \n \n \n)\n \n \n=\n \n \narg\n \n \n \n \nmin\n \n \nϕ\n \n,\n \nψ\n \n \n \n \n \n\uf605\n \n \nX\n \n-\n \n \n \n(\n \n \nψ\n \n∘\n \nϕ\n \n \n)', '\u2062\n \nX\n \n \n \n\uf606\n \n \n2\n \n2\n \n \n \n \n \n \n \n(\n \n3\n \n)\n \n \n \n \n \n \n \n \nThe goal of the auto-encoder is to learn a representation (coding) from a data set and is also used for dimensionality reduction.', 'While a principal component analysis (PCA) can only have linear mappings, auto-encoders can have nonlinear encodings as well.', 'Unlike PCA, auto-encoders can be easily extended as a stacked PCA.', 'Some auto-encoder variations include an denoising auto-encoder, a sparse auto-encoder, a variational Bayes auto-encoder and a convolutional auto-encoder.', 'In \nFIG.', '14\n, a convolutional auto-encoder is illustrated with only convolutional and pooling layers and without the fully connected layers.', 'The parameters of the auto-encoder of \nFIG.', '14\n (starting from an image) are shown on \nFIG.', '15\n, and the dimension of the bottleneck features can be tuned by using a different number of (max)pooling layers, where the maximum value of the values of pixels within a window is used to represent the window.', 'If a decrease in dimension is desired, more pooling layers are required.', 'FIGS.', '16\na\n-\n16\ne \nshow learned bottleneck features for monopole bandpass filter 1 (BPF1) (for STC-2D) data, monopole BPF2 data, dipole BPF1 data, dipole BPF2 data, and dipole BPF3 data respectively, with the x-axis being the pixel index of the bottleneck feature, and the y-axis representing the training set index.', 'In one embodiment, auto-encoding followed by SVM is utilized for training at \n108\n of \nFIG.', '1\n.', 'This combination falls into the class of semi-supervised learning methods. \nFIG.', '17\n shows a diagram for training and testing, and \nFIG.', '18\n shows a diagram for cross-validation.', 'As seen in \nFIG.', '17\n, the features are learned from the labeled data as well as the unlabeled scenario data.', 'To increase the number of samples, all the unlabeled data sets are also used as the input to the auto encoder in the training step.', 'More particularly, \nFIG.', '17\n shows an illustration of the step for an example where the STC-2D maps for all the 750 samples in the training set along with the 200 samples each from scenario 1 and 2 are fed from the testing set to the auto-encoder to arrive at a much lower dimensional learned feature set.', 'This process is repeated for each of the bandpass filtered STC maps for monopole and dipole data.', 'The learned features of the bands and modes are then jointly fed into an SVM which is trained and cross-validated using the labels from the training set as shown in \nFIG.', '18\n.', 'The trained SVM can now be applied to the features extracted from the testing set to complete the classification.', 'FIGS.', '19\n-\n23\n show examples of initial (original) and the reconstructed STC 2D images for the two different monopole bands and three different dipole bands generated by the convolutional auto-encoder of \nFIG. \n15\n.', 'Thus, \nFIG.', '19\n shows the original and reconstructed images for label one of a first cube; \nFIG.', '20\n shows the original and reconstructed images for label two of a second cube; \nFIG.', '21\n shows the original and reconstructed images for label three of a third cube; \nFIG.', '22\n shows the original and reconstructed images for label four of a fourth cube; and \nFIG.', '23\n shows the original and reconstructed images for label five of a fifth cube.', 'It will be appreciated that for some purposes, the reconstructed images are reasonable representations of the original images.', 'Supplying the bottleneck features of the auto-encoder to the SVM, classification maps over depth interval of interest are generated for the two test sets respectively in \nFIG.', '24\n and \nFIG.', '25\n.', 'In each figure, classification results are shown for eight modalities: monopole BPF1, monopole BPF2, dipole MPF1, dipole MPF2, dipole MPF3, monopole BPF1-2, dipole BPF1-3, and combined monopole BPF1-2 and dipole BPF1-3.', 'Classification rates on the cross-validation set and unlabeled multiband multimodality data are in Table 8.\n \n \n \n \n \n \n \n \nTABLE 8\n \n \n \n \n \n \n \n \nClassification results using AE + SVM on cross-validation\n \n \n \nset and two unlabeled multiband multimodality datasets.', 'Classi-\n \nClassi-\n \n \n \n \nClassification\n \nfication\n \nfication\n \n \n \nAE + SVM\n \nRate per Label\n \nRate-\n \nRate-\n \n \n \nDataset\n \n(1-5) on CV Data\n \nScene 1\n \nScene 2\n \n \n \n \n \n \n \n \n \n \n \n \n \n \nMONO BPF1\n \n1, 0.993, 0.993, 1, 0.98\n \n1\n \n1\n \n \n \nMONO BPF2\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \nDIP BPF1\n \n0.913, 0.75, 0.573,\n \n0.705\n \n0.75\n \n \n \n \n0.473, 0.793\n \n \n \n \n \nDIP BPF2\n \n0.98, 0.98, 0.993, 0.973, 0.980\n \n0.99\n \n0.99\n \n \n \nDIP BPF3\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \nMONO BPF1-2\n \n1, 1, 1, 1, 1\n \n1\n \n1\n \n \n \nDIP BPF 1-3\n \n1, 0.953, 0.98, 0.96, 0.98\n \n0.985\n \n0.99\n \n \n \nMONO+DIP\n \n1, 0.953, 0.993, 0.967, 0.98\n \n0.985\n \n0.99\n \n \n \n \n \n \nData used for Autoencoder features falls in one of the groups of multiband data: for monopole source, BPF1 = [1, 5] kHz, and BPF2 =', '[5, 12] kHz, and for dipole data, 3 frequency bands are BPF1 =', '[1, 2.5] kHz, BPF2 =', '[2.5, 5.5] kHz, and BPF3 =', '[5.5, 12] kHz.\n \n \n \n \n \n \n \nFIGS.', '26\na\n-\n26\nh \ndepict support vectors corresponding to various multiband modalities for the five labels of interest for the monopole BPF1 data, the monopole BPF2 data, the dipole BPF1 data, the dipole BPF2 data, the dipole BPF3 data, the aggregate monopole BPF1-2 data, the aggregate dipole BPF1-3 data, and the aggregate of all monopole and dipole data.', 'Mel-Frequency Cepstral Coefficients (MFCC)\n \nMFCC are known in the literature as Mel-frequency cepstral coefficients.', 'See, e.g., K. Prahalad, “Speech technology: A practical introduction,” \nCarnegie Mellon University \n& \nInternational Institute of Information Technology Hyderabad PPT\n, (2003).', 'They are widely used for signal classification and speech recognition.', 'In one embodiment, for a training dataset, MFCC may be used as the features for a SVM classifier.', 'These features can be generated through the following steps.', 'First, the short time Fourier transform (a windowed excerpt) is applied to a signal: \n \nX[k]=DFT\n(\nx[n]\n) \u2003\u2003(4)', 'The powers of the spectrum obtained above are mapped onto the Mel scale through:\n \n \n \n \n \n \n \n \n \nMel\n \n\u2061\n \n(\n \nf\n \n)\n \n \n=\n \n \n2595\n \n×\n \n \n \nlog\n \n10\n \n \n(\n \n \n1\n \n+\n \n \nf\n \n700\n \n \n \n)\n \n \n \n \n \n \n \n(\n \n5\n \n)', 'Next, triangular overlapping windows are used and logs of the powers at each of the mel frequencies are taken,\n \n \n \n \n \n \n \n \n \nY\n \n[\n \nm\n \n]\n \n \n=\n \n \nlog\n \n\u2061\n \n(\n \n \n \n∑\n \n \nk\n \n=\n \n \nf\n \n \nm\n \n-\n \n1\n \n \n \n \n \nf\n \n \nm\n \n+\n \n1\n \n \n \n \n \n \n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \nX\n \n[\n \nk\n \n]\n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n2\n \n \n\u2062\n \n \n \nB\n \nm\n \n \n[\n \nk\n \n]\n \n \n \n \n)\n \n \n \n \n \n \n(\n \n6\n \n)\n \n \n \n \n \n \n \n where: \n \n \n \n \n \n \n \n \n \n \nB\n \nm\n \n \n[\n \nk\n \n]', '=\n \n \n{\n \n \n \n \n0\n \n \n \n \n \n \n \n \nk\n \n-\n \n \nf\n \n \nm\n \n-\n \n1\n \n \n \n \n \n \nf\n \nm\n \n \n-\n \n \nf\n \n \nm\n \n-\n \n1\n \n \n \n \n \n,\n \n \nk\n \n∈\n \n \n[\n \n \n \nf\n \n \nm\n \n-\n \n1\n \n \n \n,\n \n \nf\n \nm\n \n \n \n]\n \n \n \n \n \n \n \n \n \n \n \n \nf\n \n \nm\n \n+\n \n1\n \n \n \n-\n \nk\n \n \n \n \nf\n \n \nm\n \n+\n \n1\n \n \n \n-\n \n \nf\n \nm\n \n \n \n \n,\n \n \nk\n \n∈\n \n \n[\n \n \n \nf\n \nm\n \n \n,\n \n \nf\n \n \nm\n \n+\n \n1\n \n \n \n \n]\n \n \n \n \n \n \n \n \n \n \n \n \n(\n \n7\n \n)', 'The last step involves taking the discrete cosine transform for the list of Mel log powers, as if it were a signal (see, S. Young, et al., \nThe HTK Book \n(Version 3.4), Cambridge University Engineering Department, (2006)):\n \n \n \n \n \n \n \n \n \nc\n \n[\n \nn\n \n]\n \n \n=\n \n \n \n1\n \nM\n \n \n\u2062\n \n \n \n∑\n \n \nm\n \n=\n \n1\n \n \nM\n \n \n \n \n \n \nY\n \n[\n \nm\n \n]\n \n \n\u2062\n \n \ncos\n \n\u2061\n \n(\n \n \n \nπ\n \n\u2062\n \n \nn\n \n\u2061\n \n(\n \n \nm\n \n-\n \n0.5\n \n \n)\n \n \n \nM\n \n \n)\n \n \n \n \n \n \n \n \n \n(\n \n8\n \n)', 'The MFCC are the amplitudes of the resulting spectrum after liftering (filtering in the cepstral domain) (see, S. Young, et al.', 'The HTK Book \n(Version 3.4), Cambridge University Engineering Department, (2006)),\n \n \n \n \n \n \n \n \n \n \nc\n \n′\n \n \n[\n \nn\n \n]\n \n \n=\n \n \n \n(\n \n \n1\n \n+\n \n \n \nL\n \n2\n \n \n\u2062\n \nsin\n \n\u2062\n \n \n \nπ\n \n\u2062\n \nn\n \n \nL\n \n \n \n \n)\n \n \n×\n \n \n \nc\n \n[\n \nn\n \n]\n \n \n.\n \n \n \n \n \n \n \n(\n \n9\n \n)\n \n \n \n \n \n \n \n \nMFCC is a time frequency representation.', 'One can vectorize the 2D MFCC features when using SVM.', 'In one embodiment, MFCCs are generated from each waveform.', 'The frame duration may be set at 2.6 ms, with 1 ms set as the frame shift.', 'By way of example, 30 filterbank channels and 22 cepstral coefficients (the number of cepstral coefficients should be less than the number of filterbank channels) are chosen.', 'The lower and upper frequency limits are set to 2000 and 10000 Hz, and the cepstral sine lifter parameter is 2000 (2000 is a default value in MFCCs processing).', 'Some classification results are shown in \nFIG.', '27\n.', 'For the monopole data, the classification rate on Scenario 2 data is 1, and classification rate on CV data is 0.9987, which breaks down as: classification rate equal to 1 for labels 1-4, and classification rate of 0.993 for label 5.', 'For the aggregate dipole data, the classification rate on Scenario 2 data is 0.995, and classification rate on CV data is 0.9973, which breaks down as: classification rate equal to 1 for labels 1, 2, 3, and 5, and classification rate of 9866 for label 4.', 'Finally, for combined monopole and dipole modalities (Mod MD scene 2), all above mentioned rates are equal to 1.\n \nClassification Using Convolutional Neural Networks (CNN)', 'Convolutional neural network (CNN) can be used for image recognition, video classification, semantic segmentation, and object localization.', 'A CNN consists of multiple layers of neurons which can process portions of the input images called receptive fields.', 'The outputs of these collections are then tiled so that their input regions overlap.', 'For better representation, this is repeated for each layer.', 'Tiling allows CNN to deal with translations of the input data.', 'Compared to multilayer perceptron (MLP), CNN does not suffer from dimensionality, and scales well to higher resolution images.', 'It has the following distinguishing features: 3D volumes of neurons, local connectivity and shared weights.', 'These properties allow CNN to achieve better generalization on computer vision problems.', 'CNN Parameters\n \nFor purposes of the machine learning module implementing CNN on STC images.', 'in order to reduce the computation burden, according to embodiments, the STC 2D images may be downsampled, e.g., to 40%.', 'Then, the downsampled images may be cropped and fed into the CNN.', 'As suggested by \nFIG.', '28\n, separate CNNs for the monopole and the dipole data may be designed.', 'Each training sample can be a 2D image or a 3D tensor.', 'By way of example only, 400 neurons may be used in the first fully-connected (FC) layer and 450 neurons for monopole and dipole data separately.', 'In \nFIG.', '28\n, two convolutional layers are shown applied with a receptive field of size of each neuron being 3*3.', 'A single max pooling layer is shown.', 'Except for the situation where STC 2D images are utilized, MFCCs and bottleneck features can also be put into the CNN.', 'In the next section, we will show how to combine the information from different modalities.\n \nVisualization of CNN\n \nFor purposes of illustrating CNN visualization results, the dipole data based CNN model is used as an example.', 'A specific arrangement of a CNN is shown in \nFIG.', '29\n corresponding to \nFIG.', '28\n where three 2D STC maps size 240×78 are scanned by a 3*3(*3) window to convolutional layer 1 (size 238×76×25).', 'A similar window of 3*3*25 is scanned to convolutional layer 2 (size 236×74×25), and a max pool layer is used to reduce the input into the fully connected layer to 118×37×25.', 'The fully connected layer is shown (in this case) to provide three output classes with associated weights, it being appreciated that in other embodiments, different numbers of classes may be generated.', 'The highest weight value is then selected (as suggested by equation (2)) as the determined label (answer product).', 'The multiband sample STC 2D data (maps) which are input into the CNN is shown in \nFIG.', '30\na\n, and the filter weights computed from convolutional layer 1 operation are shown in \nFIG.', '30\nb\n.', 'The weights look like edge detectors which can detect edges from different angles.', 'To observe the activation map, a training sample from label 3 in \nFIG.', '30\nb \nis selected and the activation maps from convolutional layers 1 and 2 are plotted separately.', 'The activation maps seem to be the combination of those three STC 2D images, and they are shown in \nFIG. \n31\na \nand \nFIG.', '31\nb.', 'Comparing activation map 1 of \nFIG.', '31\na \nand activation map 2 of \nFIG.', '31\nb\n, the features in activation map 2 appear much sharper.', 'For monopole data, similar STC 2D input maps and filter weights are shown in \nFIGS.', '32\na \nand \n32\nb\n, while similar activation maps are shown in \nFIGS.', '33\na \nand \n33\nb.', 'Joint Training With 2 Streams\n \nAccording to one aspect, three frameworks (embodiments) are provided for combining the features from monopole and dipole data, all based on CNNs.', 'As seen in \nFIG.', '34', ', a first type of CNN (denoted by CNN T1) adds (sums) the outputs from fully connected layers from different modalities (e.g., monopole and dipole) together before feeding into another fully connected layer.', 'The second type of CNN (denoted by CNN T2) concatenates the fully connected layers from monopole and dipole modalities.', 'The third type of CNN (denoted by CNN T3) also concatenates the fully connected layers from the monopole and dipole modalities but adds one more fully connected layer based on the second type of CNN, for further dimension reduction.', 'For a fast implementation of CNNs, an integrated development environment composed of Anaconda (a free and open source distribution of the Python and R programming languages, Theano (a Python library that permits defining, optimization, and evaluation of mathematic expressions), and Keras (a higher level library which operates over Theano and stream-lines the process of building deep learning networks) may be used.', 'To run the auto-encoder, OPENBLAS (or BLAS) library may be used.', 'Turning now to \nFIGS.', '37\na \nand \n37\nb\n, results for different CNN classifications for scenarios 1 and 2 respectively are shown side by side.', 'Thus, in each figure, the left-most plot shows results for CNN where the input is two-band monopole STC data, and from left to right, the next plots show results for three-band dipole STC data, and combined streams using summation of monopole and dipole (T1), concatenation of monopole and dipole (T2), and concatenation plus an additional fully connected layer (T3).', 'It may be concluded that in the synthetic data case, all CNN-based classifiers give perfect classification.', 'In one aspect, the CNN model parameters, such as the convolutional filter parameters are trained by optimizing an objective function similar to equation (1) using stochastic descent algorithms.', 'Some of the methods and processes described above, including, but not limited to the STC processing and the machine learning module, can be performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any particular device type or system.', 'The processor may include a computer system.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, or general purpose computer) for executing any of the methods and processes described above.', 'The computer system may further include a memory such as a semiconductor memory device (e.g., a RAM, ROM, PROM, EEPROM, or Flash-Programmable RAM), a magnetic memory device (e.g., a diskette or fixed disk), an optical memory device (e.g., a CD-ROM), a PC card (e.g., PCMCIA card), or other memory device.', 'Some of the methods and processes described above, can be implemented as computer program logic for use with the computer processor.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Alternatively or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention.', 'By way of example only, while particular examples were given of labels for specific combinations of states for the inner and outer annuli of a well, labels for other states and combinations thereof may be utilized such as a label for an inner annulus and an outer annulus of said annuli being filled with cement, a label for the inner annulus being filled with water and the outer annulus being filled with cement, a label for the inner annulus being filled with cement and the outer annulus being filled with water, and a label for the inner and outer annuli being filled with water.', 'Also, by way of example only, while CNNs having a particular window sizes and particular numbers of convolutional layers, maxpool layers, and fully connected layers were described, it will be appreciated that the CNNs may be constructed with different window sizes, and different numbers of layers.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.']

['1.', 'A method of characterizing the status of annuli of a multiple-cased well of interest, comprising:\nutilizing a dataset of labeled slowness time coherence (STC) samples obtained from processing at least one of (i) synthesized sonic data and (ii) measured sonic data obtained from a multiple-cased well, training a machine learning module to receive STC sample inputs and provide output labels for a plurality of states for annuli of a multiple-cased well;\nlocating a sonic tool having at least one transmitter and multiple detectors at a location in the well of interest;\nfiring the at least one transmitter, and detecting with the multiple detectors the resulting sonic waveforms impacted by annuli of the well of interest;\npreprocessing the sonic waveforms to obtain at least one STC map, wherein said preprocessing the sonic waveforms comprises bandpass filtering said sonic waveforms into at least two bands and conducting STC processing on each band separately;\nproviding the at least one STC map as the STC sample inputs of the machine learning module to obtain an indication of the status of the annuli of the multiple-cased well adjacent the location of the sonic tool.', '2.', 'The method of claim 1, wherein said machine learning module implements at least one of a convolutional neural network (CNN), a support vector machine (SVM), and an auto-encoder.\n\n\n\n\n\n\n3.', 'The method of claim 1, wherein said at least one transmitter includes a monopole transmitter and a dipole transmitter and said preprocessing the sonic waveforms comprises separately filtering sonic waveforms resulting from waves detected as a result of the firing of the monopole transmitter and waves detected as a result of the firing of the dipole transmitter.', '4.', 'The method of claim 3, wherein said preprocessing the sonic waveforms comprises separately bandpass filtering the sonic waveforms resulting from waves detected as a result of the firing of the monopole transmitter into at least two bands, and separately bandpass filtering the sonic waveforms resulting from waves detected as a result of the firing of the dipole transmitter into at least two bands.', '5.', 'The method of claim 1, wherein said machine learning module implements a CNN, said preprocessing the sonic waveforms to obtain at least one STC map comprises preprocessing the sonic waveforms to obtain at least one 2D STC map and said at least one 2D STC map is provided as the STC sample inputs to the CNN by scanning a window over pixels of the at least one 2D STC map.', '6.', 'The method of claim 5, wherein said preprocessing the sonic waveforms comprises bandpass filtering said sonic waveforms into at least two bands and conducting STC processing on each band separately such that said at least one 2D STC map comprises a plurality of 2D STC maps corresponding to each band.', '7.', 'The method of claim 6, wherein said at least one transmitter includes a monopole transmitter and a dipole transmitter and said preprocessing the sonic waveforms comprises separately filtering sonic waveforms resulting from waves detected as a result of the firing of the monopole transmitter and waves detected as a result of the firing of the dipole transmitter and separately bandpass filtering the sonic waveforms resulting from waves detected as a result of the firing of the monopole transmitter into at least two bands and separately bandpass filtering the sonic waveforms resulting from waves detected as a result of the firing of the dipole transmitter into at least two bands and conducting STC processing on each band separately such that said at least one 2D STC map comprises a plurality of 2D STC maps corresponding to each band.', '8.', 'The method of claim 7, wherein the CNN includes a plurality of convolutional layers, at least one maximum pooling layer, and at least one fully connected layer.', '9.', 'The method of claim 8, wherein the CNN has a first set of convolutional layers and a fully connected layer for 2D STC maps corresponding to the data from the monopole transmitter, and a second set of convolutional layers and fully connected layer for 2D STC maps corresponding to the data from the dipole transmitter, results of the fully connected layer for the data from the monopole transmitter and results of the fully connected layer for the data from the dipole transmitter being summed in the fully connected layer which provides said indication of the status of the annuli of the multiple-cased well.', '10.', 'The method of claim 9, wherein the CNN has a first set of neural network convolutional layers for 2D STC maps corresponding to the data from the monopole transmitter, a second set of neural network convolutional layers for 2D STC maps corresponding to the data from the dipole transmitter, and a fully connected layer where results of the first set and second set of neural networks are concatenated and which provides said indication of the status of the annuli of the multiple-cased well.', '11.', 'The method of claim 10, wherein the CNN has a first set of neural network convolutional layers for 2D STC maps corresponding to the data from the monopole transmitter, a second set of neural network convolutional layers for 2D STC maps corresponding to the data from the dipole transmitter, a first fully connected layer where results of the first set and second set of neural networks are concatenated, and a second fully connected layer that receives the output of the first fully connected layer and provides said indication of the status of the annuli of the multiple-cased well.\n\n\n\n\n\n\n12.', 'The method of claim 1, wherein said machine learning module implements a SVM, said preprocessing the sonic waveforms to obtain at least one STC map comprises preprocessing the sonic waveforms to obtain a 1D STC vector map and said 1D STC vector map is provided as the STC sample inputs to said SVM.', '13.', 'The method of claim 12, wherein said preprocessing the sonic waveforms comprises bandpass filtering said sonic waveforms into at least two bands and conducting STC processing on each band separately such that said at least one 1D STC vector map comprises a plurality of 1D STC vector maps corresponding to each band.', '14.', 'The method of claim 12, wherein said at least one transmitter includes a monopole transmitter and a dipole transmitter, and said preprocessing the sonic waveforms comprises separately filtering sonic waveforms resulting from waves detected as a result of the firing of the monopole transmitter and waves detected as a result of the firing of the dipole transmitter and separately bandpass filtering the sonic waveforms resulting from waves detected as a result of the firing of the monopole transmitter into at least two bands, and separately bandpass filtering the sonic waveforms resulting from waves detected as a result of the firing of the dipole transmitter into at least two bands and conducting STC processing on each band separately such that said at least one 1D STC vector map comprises a plurality of 1D STC vector maps corresponding to each band.', '15.', 'The method of claim 1 wherein said machine learning module implements an auto-encoder, said preprocessing the sonic waveforms to obtain at least one STC map comprises preprocessing the sonic waveforms to obtain either a 1D STC vector map or a 2D STC map which is provided as the STC sample inputs to said auto-encoder.', '16.', 'The method of claim 15, wherein said auto-encoder includes a bottleneck where bottleneck features are defined and said machine learning module further implements an SVM where said bottleneck features are provided as inputs to said SVM.', '17.', 'The method according to claim 1, further comprising: moving the sonic tool to another location in the well of interest, and repeating said firing, preprocessing and providing in order to obtain an indication of the status of the annuli of the multiple-cased well adjacent the other location of the sonic tool.', '18.', 'The method according to claim 17, further comprising: using the indications of the status of the annuli of the multiple-cased well, making a decision regarding remedial action with respect to the well of interest.\n\n\n\n\n\n\n19.', 'The method according to claim 1, wherein said output labels for said plurality of states for annuli include a label for an inner annulus and an outer annulus of said annuli being filled with cement, a label for the inner annulus being filled with water and the outer annulus being filled with cement, a label for the inner annulus being filled with cement and the outer annulus being filled with water, and a label for the inner and outer annuli being filled with water.']

['FIG.', '1 is a high-level flow-chart of disclosed methods for analyzing annuli of a multiple-cased well using machine learning;; FIGS.', '1a and 1b depict a wireline Sonic Scanner tool, showing the transmitters and receiver array and cross-dipole firings;; FIG. 2 is a depiction of a sonic tool located in a multiple-casing string well;; FIGS.', '3a and 3b respectively depict monopole and dipole modalities excited by a Sonic Scanner™ tool, together with their waveforms and direction of source firing;; FIG.', '4 depicts a synthetic dataset showing a training set encompassing five possible cases of fill in annulus A and B on the left and two test set scenarios on the right for evaluating the classification performance of the algorithm;; FIG.', '5 shows training and testing datasets;; FIGS.', '6a and 6b respectively depict Butterworth filters (bands) with different cutoff frequencies on a normalized frequency scale and on an original frequency scale;; FIGS.', '7a-7d', 'respectively depict a sonic acquisition tool acquiring data, the receiver data as a function of receiver and time, an STC two-dimensional (2D) image, and an STC one-dimensional image obtained from a projection of the STC 2D image;; FIG.', '8 is a classification result using SVM on unlabeled full frequency band monopole data (Scenario 1);; FIG.', '9 is a classification result using SVM on unlabeled full frequency band monopole data (Scenario 2);; FIG.', '10 is a classification result using SVM on unlabeled full frequency band dipole data (Scenario 1);; FIG.', '11 is a classification result using SVM on unlabeled full frequency band dipole data (Scenario 2);; FIG.', '12 is a classification result using SVM on unlabeled multiband data (Scenario 1) where M1, and M2 denote monopole data in frequency ranges BPF1, and BPF2; D1, D2, D3, denote dipole data in frequency ranges BPF1, BPF2, and BPF3; M denotes combined monopole frequency bands; D denotes combined dipole frequency bands, and MD denotes combined monopole and dipole frequency bands;; FIG. 13 is a classification result using SVM on unlabeled multiband data (Scenario 2) where M1, and M2 denote monopole data in frequency ranges BPF1, and BPF2; D1, D2, D3, denote dipole data in frequency ranges BPF1, BPF2, and BPF3; M denotes combined monopole frequency bands; D denotes combined dipole frequency bands, and MD denotes combined monopole and dipole frequency bands;; FIG.', '14 is a schematic of a convolutional auto-encoder;; FIG.', '15 depicts parameters of the auto-encoder of FIG.', '14;', '; FIGS.', '16a-16e show learned bottleneck features with the x-axis being the pixel index of the bottleneck feature, and the y-axis representing the training set index;; FIG.', '17 is a training/testing diagram of auto-encoder with SVM;; FIG.', '18 is a cross validation diagram of auto-encoder with SVM;; FIG.', '19 shows original and reconstructed STC 2D images for label 1 (Cubes 1 through 250) for Cube #25;; FIG.', '20 shows original and reconstructed STC 2D images for label 2 (Cubes 151-300) for Cube #201;; FIG.', '21 shows original and reconstructed STC 2D images for label 3 (Cubes 301-450) for Cube #325;; FIG.', '22 shows original and reconstructed STC 2D images for label 4 (Cubes 451-600) for Cube #476;; FIG.', '23 shows original and reconstructed STC 2D images for label 5 (Cubes 601-750) for Cube #667;; FIG.', '24 shows a classification result using auto-encoding plus SVM (AE+SVM) on unlabeled multiband multimodality data (Scenario 1) where the data used is as given on FIG.', '12;; FIG.', '25 shows a classification result using AE+SVM on unlabeled multiband multimodality data (Scenario 2) where the data used is as given on FIG. 13;; FIGS.', '26a-26h depict support vectors corresponding to various multiband modalities for five labels of interest;; FIG.', '27 depict Mel-frequency cepstral coefficient (MFCC) methods;; FIGS. 28a and 28b respectively depict convolutional neural network (CNN) parameters for monopole and dipole data;; FIG.', '29 depicts dimensions of single stream CNN (dipole input);; FIGS. 30a and 30b respectively depict STC 2D images (3 dipole bands) used in generating the activation maps, and filter weights computed from the first convolution stage;; FIGS. 31a and 31b respectively depict activation maps for dipole inputs after a CONV1 layer and after a CONV2 layer;; FIGS. 32a and 32b respectively depicts STC 2D images (2 monopole bands) used in generating the activation maps, and filter weights computed from the first convolution operation;; FIGS. 33a and 33b respectively depict monopole activation maps after a CONV1 layer and after a CONV2 layer;; FIGS.', '34a-34c are two stream CNN frameworks for combining results from monopole and dipole data; and; FIGS. 35a and 35b depict classification of multiband multimodality data from Scenario 1 & 2 using CNN methods, with the first panel of both FIGS.', '35a and 35b showing classification using two band monopole data, the second panel showing classification results using three band dipole data, and the last three panels showing three methods for combining two streams of data, respectively.; FIG.', '1a depicts a wireline tool such as the Sonic Scanner with a multiplicity of transmitters and a 2-D axial and azimuthal array of receivers which may be used in conjunction with the activation of transmitters so that acoustic energy is radiated into the casings surrounding the borehole and detecting waveforms at the detectors of the acoustic borehole tool at 130.', 'It may also be used in conjunction with the collection of sonic data at 100 for the purpose of generating training datasets at 106.', 'The Sonic Scanner has the capability of acquiring wideband sonic modal logging measurements with the signal frequency ranging from 200 Hz to 12 kHz.', 'In a “Record-All-Data” acquisition mode of the tool, the measurement is very rich in data as multiple borehole modes are excited and detected using the multiple transmitters and individual recordings of receivers in the 2-D array.', 'These include the monopole mode that can be excited both at low and high frequencies and with far and near (to the receiver array) monopole sources, and the dipole mode that can be excited at two orthogonal directions yielding cross-dipole excitation as seen in FIG.', '1b.', 'While these sonic measurements have not previously been used for well integrity applications and have some of the same limitations such as a lack of azimuthal resolution (monopole) or only two quadrant resolution (dipole), low axial resolution (of the order of 1 m), and sensitivity to multiple mechanisms over the probed region, they have the capability to probe beyond the first casing and annulus, and therefore bring the capacity for a diagnosis of the annuli in multiple casing configurations.', 'This is particularly true if the inner casing and annulus state are known or determined by another measurement such as the high resolution ultrasonic from the Isolation Scanner.; FIG.', '2 depicts a typical multiple casing configuration in an oil and gas well in which the acoustic borehole tool is placed at 120 of FIG.', '1.', 'A series of casings are deployed inside the wellbore in telescopic fashion.', 'The annulus behind each casing is partially or fully filled with cement to assure well integrity and zonal isolation of various formations layers.', 'In some situations, it may be necessary to evaluate the annular fill and bond in cement behind multiple overlapping casings with a tool deployed in the fluid filled innermost casing.', 'Examples of potential diagnoses of annulus A (behind first casing; i.e., between the first and second casings) and annulus B (behind second casing) are depicted for a dual casing scenario.; FIG.', '8 is a classification result (map) using SVM on unlabeled full frequency band monopole data for Scenario 1 over a depth of interest.', 'FIG.', '9 is a classification result (map) using SVM on unlabeled full frequency band monopole data for Scenario 2 over a depth of interest.', 'FIG.', '10 is a classification result (map) using SVM on unlabeled full frequency band dipole data for Scenario 1 over a depth of interest.', 'FIG.', '11 is a classification result (map) using SVM on unlabeled full frequency band dipole data for Scenario 2 over a depth of interest.; FIGS.', '12 and 13 show classification maps over the depth interval of interest.', 'More particularly, FIG.', '12 shows classification results using monopole bandpass filter 1 (MONO BPF1) (e.g., STC-1D) data (panel 1), monopole BPF2 data (panel 2), dipole BPF1 data (panel 3), monopole BPF2 data (panel 4), monopole BPF3 data (panel), all monopole bands (MONO BPF1-2) (panel 6), all dipole bands (DIP BPF1-3) (panel 7), and all monopole and dipole bands (panel 8), all for Scenario 1.', 'Similarly, FIG.', '13 shows classification results using monopole BPF1 data (panel 1), monopole BPF2 data (panel 2), dipole BPF1 data (panel 3), monopole BPF2 data (panel 4), monopole BPF3 data (panel), all monopole bands (MONO BPF1-2) (panel 6), all dipole bands (DIP BPF1-3) (panel 7), and all monopole and dipole bands (panel 8), all for Scenario 2.; FIGS.', '16a-16e show learned bottleneck features for monopole bandpass filter 1 (BPF1) (for STC-2D) data, monopole BPF2 data, dipole BPF1 data, dipole BPF2 data, and dipole BPF3 data respectively, with the x-axis being the pixel index of the bottleneck feature, and the y-axis representing the training set index.; FIGS.', '19-23 show examples of initial (original) and the reconstructed STC 2D images for the two different monopole bands and three different dipole bands generated by the convolutional auto-encoder of FIG.', '15.', 'Thus, FIG.', '19 shows the original and reconstructed images for label one of a first cube; FIG.', '20 shows the original and reconstructed images for label two of a second cube; FIG.', '21 shows the original and reconstructed images for label three of a third cube; FIG.', '22 shows the original and reconstructed images for label four of a fourth cube; and FIG.', '23 shows the original and reconstructed images for label five of a fifth cube.', 'It will be appreciated that for some purposes, the reconstructed images are reasonable representations of the original images.; FIGS.', '26a-26h depict support vectors corresponding to various multiband modalities for the five labels of interest for the monopole BPF1 data, the monopole BPF2 data, the dipole BPF1 data, the dipole BPF2 data, the dipole BPF3 data, the aggregate monopole BPF1-2 data, the aggregate dipole BPF1-3 data, and the aggregate of all monopole and dipole data.', 'Mel-Frequency Cepstral Coefficients (MFCC)']

US11927082

Non-metallic compliant sand control screen

Feb 17, 2020

Jushik Yun, Rasika Prabhu, Valerie Gisele Helene Lafitte, Julien Debard, Balkrishna Gadiyar, Mehmet Parlar, Camilo Eduardo Zuniga Jurgensen, Chidi Eugene Nwafor

SCHLUMBERGER TECHNOLOGY CORPORATION

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['A sand screen apparatus for use in a downhole operation for hydrocarbon recovery includes a non-metallic material and a mechanical retainer.', 'The non-metallic material has a compressed state and an expanded state, and includes a base polymer, and one or a plurality of smart fillers dispersed with a polymeric matrix of the non-metallic material.', 'The mechanical retainer compresses the non-metallic material in the compressed state.', 'The one or the plurality of smart fillers react with the base polymer in the expanded state after exposure to a wellbore condition.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATION', 'This application is a National Stage Entry of International Application No. PCT/US2020/018495, filed Feb. 17, 2020, which is based on and claims priority to U.S. Provisional Patent Application No. 62/808,132, filed Feb. 20, 2019, which is incorporated by reference in its entirety.', 'BACKGROUND\n \nIn many hydrocarbon wells, inflowing fluid passes through a sand screen which filters out particulates from the inflowing oil or gas.', 'The sand screen prevents sand from entering the wellbore and reduces damage that may occur by erosion.', 'Conventionally, sand screens are made with a metallic mesh material.', 'Once the sand screen is placed into the wellbore, gravel packs are pumped to fill the annulus between the screen and the formation.', 'In other instances, some metallic sand screens are expandable and are expanded downhole after placement in the wellbore.', 'The result is a reduction in the annulus between the screen and the formation.', 'The expandable screens in many instances have a limited expansion ratio and the ability of the expandable screen to conform to borehole irregularities may not be satisfactory.', 'Further, the ability of the expandable sand screen to resist borehole collapse may be reduced.', 'Conventional sand screens are rated to resist greater external pressure than expandable sand screens.', 'Expandable sand screens resist less external pressure because of plastic deformation experienced by their metallic components.', 'Recently, self-conformable polymer screens have been developed by using thermoplastic urethane (TPU) and implementing a shape memory concept.', 'The polymeric screen has an open cell structure, which has been compressed.', 'The polymeric screen is then placed into a wellbore and expanded by controlling the glass transition temperature of the polymeric material by utilizing an activation fluid, such as acetyl acetone, for example.', 'The activation fluid is difficult to handle at the well site because the flash point of the activation fluid is relatively low, and a special formulation of the fluid is required.', 'Once in the borehole, the polymeric TPU foam material softens and tries to return to its original expanded shape.', 'The expansion outer diameter was designed to be higher than the borehole internal diameter, resulting in the TPU foam conforming to the entire length of an even irregularly shaped, e.g., open hole, borehole, which can circumvent the need to pump gravel slurry in a gravel packing operation.', 'However, one of the disadvantages of the foam material used in these sand screens is the weak mechanical properties of these foams when expanded.', 'The application is limited by the pressure and temperature rating.', 'If an expanded foam fails during a downhole operation, well control may be lost.', 'Further, screen collapse under wellbore pressure may lead to a loss of permeability and a stuck completion string in the wellbore, which may be difficult to repair or change.', 'SUMMARY\n \nIn one or more embodiments of the present disclosure, a sand screen apparatus for use in a downhole operation for hydrocarbon recovery includes a non-metallic material having a compressed state and an expanded state, the non-metallic material including a base polymer, and one or a plurality of smart fillers dispersed within a polymeric matrix of the non-metallic material, and a mechanical retainer that compresses the non-metallic material in the compressed state.', 'In one or more embodiments of the present disclosure, the one or the plurality of smart fillers react with the base polymer in the expanded state after exposure to a wellbore condition.', 'A well completion method according to one or more embodiments of the present disclosure includes covering at least one base pipe with a non-metallic material comprising a base polymer and one or a plurality of smart fillers, compressing the non-metallic material with a mechanical retainer, running the base pipe to a location in a wellbore, expanding the non-metallic material, conforming the non-metallic material to a wall of the wellbore, stiffening the non-metallic material, filtering fluids through the non-metallic material to the base pipe, detaching the non-metallic material from the base pipe, and lifting the base pipe out of the wellbore.', 'A method of completing a wellbore in a subterranean formation according to one or more embodiments of the present disclosure includes positioning an expandable sand control apparatus in the wellbore and forming an annulus between the sand control apparatus and the wellbore, the sand control apparatus having a cellular open cell structure with a non-metallic material including a base polymer, and one or a plurality of smart fillers, the non-metallic material configured to expand and fill the annulus.', 'However, many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nCertain embodiments of the disclosure will hereafter be described with reference to the accompanying drawings, wherein like reference numerals denote like elements.', 'It should be understood, however, that the accompanying figures illustrate the various implementations described herein and are not meant to limit the scope of various technologies described herein, and:\n \nFIG.', '1\n is a sectional view of a sand screen positioned in a wellbore according to one or more embodiments of the present disclosure;\n \nFIGS.', '2\n(A) and \n2\n(B)\n show further details of the sand screen according to one or more embodiments of the present disclosure;\n \nFIG.', '3\n shows a schematic drawing of a chemical foaming process according to one or more embodiments of the present disclosure;\n \nFIG.', '4\n shows an example of an open cell foam according to one or more embodiments of the present disclosure;\n \nFIG.', '5\n shows an example of superabsorbent polymers according to one or more embodiments of the present disclosure;\n \nFIGS.', '6\n(A) and \n6\n(B)\n provide an example of elastomer foam morphology before and after brine swell;\n \nFIGS.', '7\n(A) and \n7\n(B)\n show an example of mechanical compress and release according to one or more embodiments of the present disclosure;\n \nFIG.', '7\n(C)\n shows a photograph of different degradable layers, which may be used as a mechanical retainer, according to one or more embodiments of the present disclosure;\n \nFIG.', '7\n(D)\n shows a photograph of different degradable layers after 48 hrs in KCl 3% brine at different temperatures;\n \nFIG.', '7\n(E)\n shows tensile properties of a degradable layer (mechanical retainer) after 48 hrs in KCl 3% brine at 200° F. according to one or more embodiments of the present disclosure;\n \nFIG.', '8\n shows an example of how a mechanical retainer (i.e., degradable layer or film) may be used according to one or more embodiments of the present disclosure.\n \nFIG.', '9\n shows an example of TPU chemical structures according to one or more embodiments of the present disclosure;\n \nFIG.', '10\n shows an example of a chemical structure of an ether-ester thermoplastic elastomer according to one or more embodiments of the present disclosure;\n \nFIG.', '11\n shows a schematic drawing of a polyamide-polyether thermoplastic elastomer structure according to one or more embodiments of the present disclosure;\n \nFIG.', '12\n shows an example of a cross-linked polyethylene (XLPE) foam according to one or more embodiments of the present disclosure;\n \nFIGS.', '13\n(A) and \n13\n(B)\n show a polyolefin foam morphology at 200 μm resolution and 100 μm resolution, respectively;\n \nFIG.', '14\n shows an example of a silicone foam process according to one or more embodiments of the present disclosure;\n \nFIG.', '15\n shows an example of a silicone foam according to one or more embodiments of the present disclosure;\n \nFIG.', '16\n shows an example of an epoxy foam according to one or more embodiments of the present disclosure;\n \nFIGS.', '17\n(A) and \n17\n(B)\n show an epoxy foam morphology at 500 μm resolution and 200 μm resolution, respectively; and\n \nFIG.', '18\n is an example of a polyimide open cell foam according to one or more embodiments of the present disclosure.', 'DETAILED DESCRIPTION', 'In the following description, numerous details are set forth to provide an understanding of some embodiments of the present disclosure.', 'However, it will be understood by those of ordinary skill in the art that the system and/or methodology may be practiced without these details and that numerous variations or modifications from the described embodiments may be possible.', 'In the specification and appended claims: the terms “up” and “down,” “upper” and “lower,” “upwardly” and “downwardly,” “upstream” and “downstream,” “uphole” and “downhole,” “above” and “below,” and other like terms indicating relative positions above or below a given point or element are used in this description to more clearly describe some embodiments of the disclosure.', 'The present disclosure generally relates to using a non-metallic material with smart fillers for sand control applications.', 'Using smart fillers allows the non-metallic materials to self-expand to conform to the irregular shape of the wellbore.', 'The non-metallic materials are easy to manufacture by compounding and injection molding.', 'Without the need for additional activation fluids, the non-metallic materials according to one or more embodiments of the present disclosure are much safer over conventional TPU materials.', 'The non-metallic materials according to one or more embodiments of the present disclosure also provide excellent thermal stability allowing them to be used at much higher temperatures, up to 150° C. for example, for long-term applications.', 'In contrast, conventional TPU materials are only operable up to 85° C.\n \nReferring now to \nFIG.', '1\n, a sectional view of a sand screen positioned in a wellbore according to one or more embodiments of the present disclosure is shown.', 'Specifically, the wellbore \n100\n includes an open bore hole \n102\n, a production tubing string \n104\n, which may be a base pipe according to one or more embodiments, and a sand screen \n106\n.', 'While wellbore \n100\n is illustrated as being a substantially vertical, uncased well, it should be recognized that the subject disclosure is equally applicable for use in cased wellbores as well as in horizontal and/or inclined wellbores.', 'The sand screen \n106\n includes a filter member \n108\n and a compliant material \n112\n.', 'The sand screen \n106\n is shown positioned in the wellbore \n100\n adjacent a producing formation \n114\n.', 'According to one or more embodiments of the present disclosure, the compliant material \n112\n may be the only filtration agent without the use of any filter member \n108\n.', 'The compliant material \n112\n may be a porous material and therefore acts as a filtration agent.', 'In one or more embodiments, the filter member \n108\n can be configured for structural support of the compliant material \n112\n.', 'If it becomes necessary to remove the tubing \n104\n and the filter member \n108\n for some reason, (e.g., work over the well to restore production), the tubing \n104\n and the filter member \n108\n may be pulled out of the wellbore \n100\n.', 'The compliant material \n112\n may be attached to the filter member \n108\n or the tubing \n104\n via an attachment \n110\n.', 'In some embodiments, the attachment \n110\n may include a material that may degrade with exposure to downhole temperatures, fluids or time, e.g., a glue, or a degradable layer or film.', 'In other embodiments, the compliant material \n112\n may be attached to the filter member \n108\n or the tubing \n104\n with an attachment \n110\n that is time-invariant.', 'In a non-limiting example, this may involve shear screws, which would shear at a given force and release the attachment \n110\n.', 'Degradation of the material may be important in situations when the run-in forces are greater than that available during fishing.', 'If the run-in forces are less than that available during fishing, degradation is not necessary.', 'In certain situations where the compliant material \n112\n is not detached from the filter member \n108\n or from the tubing \n104\n, there may be multiple “flexible screens” comprising the compliant material, which results in the axial pull being divided.', 'In these situations, a provision is made for a weak plane below each “flexible screen” so that the tubing below each “flexible screen” is parted, and each “flexible screen” may be removed sequentially.', 'Still referring to \nFIG.', '1\n, in a well completion method according to one or more embodiments of the present disclosure', ', at least one base pipe \n104\n may be covered with a compliant material \n112\n, which may be a non-metallic compliant material that includes a base polymer and one or more smart fillers, as further described below.', 'The compliant material \n112\n covering the base pipe \n104\n may be compressed with a mechanical retainer before running the base pipe \n104\n to a location in the wellbore \n100\n, as further described below.', 'Upon exposure to a condition in the wellbore \n100\n, the compliant material \n112\n covering the base pipe \n104\n may expand due to reaction of the one or more smart fillers, and release or degradation of the mechanical retainer, as further described below.', 'In one or more embodiments, the smart fillers stiffen the compliant material \n112\n during expansion.', 'As the compliant material \n112\n expands into and fills the annulus, the compliant material \n112\n conforms to a wall of the wellbore \n100\n.', 'Because the compliant material \n112\n is able to conform to the wellbore \n100\n wall in this way, the compliant material \n112\n is able to filter debris including sand from fluids from the producing formation \n114\n to the base pipe \n104\n.', 'After the downhole operation is complete, the compliant material \n112\n may be detached from the base pipe \n104\n, and the base pipe \n104\n may be lifted out of the wellbore \n100\n.', 'FIGS.', '2\n(A) and \n2\n(B)\n show further details of the non-metallic compliant screen, according to one or more embodiments of the present disclosure.', 'FIGS.', '2\n(A) and \n2\n(B)\n show a compliant screen \n211\n, which comprises a non-metallic compliant material \n209\n and a filter material or screen \n207\n, which may be constructed in a variety of configurations, e.g., a slotted liner. \nFIG.', '2\n(A)\n shows the compliant screen \n211\n in its initial, unexpanded state, and \nFIG.', '2\n(B)\n shows the compliant screen \n211\n in its expanded state.', 'The compliant screen \n211\n is initially compliant, and according to one or more embodiments, the non-metallic compliant material \n209\n of the compliant screen \n211\n includes a base polymer and one or more smart fillers that facilitate swelling and/or reinforcement of the non-metallic compliant material \n209\n upon reaction with the base polymer.', 'Referring now to \nFIG.', '3\n, a schematic drawing of a chemical foaming process using a structural foam molding machine is shown, in accordance with one or more embodiments of the present disclosure.', 'In the foaming process according to one or more embodiments of the present disclosure, a polymer open cell structure can be manufactured by utilizing various chemical foaming agents during a molding process.', 'Polymer materials according to one or more embodiments of the present disclosure may be prepared by being compounded with smart fillers, which may include swellable or reinforcing fillers, and/or foaming agents.', 'In this way, the polymer materials can be manufactured with a chemical foaming agent to create open cell structures, such as the open cell foam shown in \nFIG.', '4\n, for example.', 'Using this chemical foaming process, the non-metallic compliant material according to one or more embodiments of the present disclosure may assume a foam structure, which may be a microfoam structure.', 'Advantageously, the foam structure can allow production fluid to pass through, while blocking solid debris from the wellbore, such as sands.', 'Chemical foaming agents are chemical substances that decompose during heating, and the resulting gaseous decomposition products are dispersed through polymer melts.', 'To obtain a uniform cell structure, the gas is either injected or evolved by heat and must be thoroughly dispersed in the polymer melts.', 'Some of the essential factors influencing this process are the particle size of the foaming agent, the dispersive properties of the machine, the decomposition rate of the foaming agent, and the melt viscosity of the thermoplastic resin being processed.', 'In one or more embodiments of the present disclosure, CO\n2\n, N\n2\n, and hydrofluorocarbons (HFCs) may be used as the chemical foaming agents, for example.', 'As previously described, the non-metallic compliant material for the compliant screen may include a base polymer and one or more smart fillers.', 'According to one or more embodiments of the present disclosure, the base polymer may include at least one of polyurethane, thermoplastic polyurethane, thermoplastic elastomer, poly ether-ester block copolymer, polyamide polyether thermoplastic elastomer, polyolefin, cross-linked polyethylene, silicone rubber, nitrile butadiene rubber (NBR), hydrogenated nitrile butadiene rubber (HNBR), ethylene propylene diene monomer rubber (EPDM), any type of fluoroelastomer, epoxy, and polyimide, for example.', 'Also, according to one or more embodiments of the present disclosure, the one or more smart fillers may include at least one of a swellable filler and/or a reinforcing filler.', 'For example, the smart fillers may include at least one swellable filler such as superabsorbent polymers (SAP), ethylene propylene diene monomer rubber (EPDM), and hydrogenated nitrile butadiene rubber (HNBR), and/or at least one reinforcing filler such as Portland cement, aluminous cement, fly ash, slag cement, MgO, ZnO, Ca(OH)', '2\n, ZnCl\n2\n, MgCl\n2\n, CaCl\n2\n, CaCO\n3\n, Na\n2\nCO\n3\n, and K\n2\nCO\n3\n.', 'Regarding swellable smart fillers, this filler/polymer can increase in volume when deployed into well fluid or brine.', 'SAP, as shown in \nFIG.', '5\n for example, is a type of hydrophilic polymer (cross-linked hydrogel) having water-absorbing capacity from 100 g/g up to 2000 g/g, in which the absorbed water is scarcely removable even under pressure because the water molecules are held tightly in the network by hydrogen bonding.', 'Using a cross-linked polymer like SAP will facilitate the passage of water through the three-dimensional network of the structure, while retaining the polymer structure, which can force the structure to swell.', 'The SAPs that may be used in accordance with one or more embodiments of the present disclosure include cross-linked forms of polyacrylate (acrylic acid and acrylamide), polyvinyl alcohol, poly(ethylene oxide), starch-acrylate copolymer, carboxymethyl cellulose, and other hydrophilic swellable polymers.', 'As understood by those having skill in the art, the degree of swelling and the swelling rate of SAPs depend on the type of cross-linked polymer, the conditions of the water with respect to pH, salinity, temperature, and pressure, the duration of immersion in a solution, and the design of the samples.', 'Referring now to \nFIGS.', '6\n(A) and \n6\n(B)\n, an example of elastomer foam morphology before and after brine swell is provided.', 'In the example shown in \nFIGS.', '6\n(A) and \n6\n(B)\n, the elastomer foam includes smart fillers, such as those previously described, to facilitate swelling in brine.', 'The elastomer foam itself may also swell in the presence of brine, independent of any swelling contributed by the smart fillers.', 'As shown in \nFIGS.', '6\n(A) and \n6\n(B)\n, the morphology of the elastomer foam is relatively constant before and after swelling in brine.', 'Such consistent morphology before and after swelling suggests that the elastomer foam is a viable filter medium with advantageous permeability properties.', 'In addition to smart fillers, the non-metallic compliant material for the compliant screen may also include other “non-smart” fillers such as talc, mica, silica, carbon black, nanographene, carbon nanotubes, glass fibers, and carbon fillers for additional support.', 'The fillers according to one or more embodiments of the present disclosure may be surface treated to improve the bonding with the polymeric matrix of the non-metallic compliant material.', 'Self-reinforcing fillers such as cement may react with completion brine or water to improve strength of the non-metallic compliant material.', 'According to one or more embodiments of the present disclosure, the screen may include a mechanical retainer that compresses the non-metallic compliant material in a compressed state.', 'When the non-metallic compliant material is deployed downhole in the compressed state due to compression by the mechanical retainer, a wellbore condition downhole such as a temperature change or a lapse in time, for example, may cause the mechanical retainer to release from the non-metallic compliant material.', 'Release of the mechanical retainer will allow the non-metallic compliant material to transition from the compressed state to an expanded state.', 'In the expanded state, the non-metallic compliant material can expand to a larger shape as the smart fillers dispersed within a polymer matrix of the non-metallic compliant material react with downhole fluids to increase in size.', 'In one or more embodiments, the mechanical retainer may be a degradable polymeric wrapping tape that dissolves in water or other downhole fluids when exposed to the wellbore condition.', 'The mechanical retainer may also be thermally molded to the non-metallic compliant material.', 'Referring now to \nFIGS.', '7\n(A) and \n7\n(B)\n, an example of mechanical compress and release according to one or more embodiments of the present disclosure is shown.', 'As shown, the polymer foam or non-metallic compliant material is thermally molded and/or mechanically wrapped by degradable polymers, which compresses the polymer foam.', 'After exposure to a wellbore condition, the degradable polymers may degrade or otherwise release from the polymer foam or non-metallic compliant material, allowing the polymer foam or non-metallic compliant material to transition from the compressed state to the expanded state.', 'In the expanded state, the smart fillers, which may include swellable fillers and/or reinforcing fillers, react with the base polymer of the polymer foam or non-metallic compliant material.', 'In this way, the non-metallic compliant material can expand to a larger shape as the smart fillers dispersed within the polymer matrix of the non-metallic compliant material react with downhole fluids to increase in size.', 'In addition, the smart fillers may also increase the stiffness of the polymer matrix, thereby strengthening the non-metallic compliant material to better withstand downhole pressures.', 'Moreover, the non-metallic compliant material can expand to conform to an irregular shape of the wellbore, as shown in \nFIG.', '2\n(B)\n as previously described, for example.', 'Due to the smart fillers, the non-metallic compliant material experiences improved and sustained strength while in the expanded state.', 'The non-metallic compliant material also experiences a modulus increase from the compressed state to the expanded state.', 'In view of the above disclosure, \nFIGS.', '7\n(A)\n and \n7\n(B) show the progression of the polymer foam or non-metallic compliant material from the compressed state to the expanded state according to one or more embodiments of the present disclosure.', 'Referring now to \nFIG.', '7\n(C)\n, a photograph of different degradable layers, which may be used as a mechanical retainer, according to one or more embodiments of the present disclosure is shown.', 'As shown, the degradable layers may be sufficiently thin to resemble and behave like a degradable film.', 'FIG.', '7\n(D)\n shows a photograph of different degradable layers after 48 hrs in KCl 3% brine at different temperatures.', 'As shown in \nFIG.', '7\n(D)\n, the degradation rate of the different degradable layers increases with increased temperature.', 'As such, the degradation rate of the degradable layers according to one or more embodiments of the present disclosure may be controlled via temperature.', 'Referring now to \nFIG.', '7\n(E)\n, the tensile properties of a degradable layer (mechanical retainer) after 48 hrs in KCl 3% brine at 200° F. according to one or more embodiments of the present disclosure is shown.', 'As shown, the degradable layer, which may be a mechanical retainer according to one or more embodiments of the present disclosure, degrades, dissolves, and otherwise exhibits low mechanical properties (i.e., about 200 psi tensile stress and about 20% to 25% elongation after 48 hrs in KCl 3% brine at 200° F.) as compared against the controls, which show about 1200 psi tensile stress and exhibit an elongation percentage in a range of 300% to 400%.', 'Indeed, as shown, the degradable layer according to one or more embodiments of the present disclosure exhibits excellent degradability as compared against the controls.', 'Referring now to \nFIG.', '8\n, an example of how a mechanical retainer may be used according to one or more embodiments of the present disclosure is shown.', 'By using a chemical foaming process such as that described with respect to \nFIG. \n3\n, for example, polymeric materials may be transformed into cellular structures.', 'These cellular structure materials may be compressed into a smaller cylinder shape by using a mechanical degradable polymer tape wrapping process, as shown in \nFIG.', '8\n, for example.', 'As shown in \nFIG. \n8\n, the mechanical retainer \n802\n, which may be a degradable polymeric wrapping tape as previously described, may be mechanically wrapped around the cellular structures or non-metallic compliant material \n209\n, thereby compressing the non-metallic compliant material \n209\n before deployment in the wellbore.', 'In one or more embodiments, commercially available water-soluble tape may be used for the mechanical retainer \n802\n, for example.', 'Various examples of the non-metallic compliant material according to one or more embodiments of the present disclosure will now be described.', 'FIG.', '9\n provides examples of thermoplastic urethane (TPU) chemical structures according to one or more embodiments of the present disclosure.', 'For example, in the previously described chemical foaming process with reference to \nFIG.', '3\n, a polymer foam may be manufactured using TPU (such as one of the chemical structures shown in \nFIG.', '9\n) compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting TPU polymer foam may be an open cell foam, and may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure.', 'FIG.', '10\n provides another example of a chemical structure of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'Specifically, \nFIG.', '10\n shows a block copolymer of a thermoplastic polyester elastomer (TPE).', 'For example, in the previously described chemical foaming process with reference to \nFIG.', '3\n, a polymer foam may be manufactured using TPE (such as the block copolymer shown in \nFIG.', '10\n) compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting TPE polymer foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the TPE base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.', 'According to one or more embodiments of the present disclosure, commercially available Hytrel® may be used as the TPE base polymer of the non-metallic compliant material.\n \nFIG.', '11\n provides another example of a chemical structure of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'Specifically, \nFIG.', '11\n shows a polyamide-polyether (PA-PE) thermoplastic elastomer as the chemical structure.', 'For example, in the previously described chemical foaming process with reference to \nFIG.', '3\n, a polymer foam may be manufactured using TPE, PA-PE (such as the polymers shown in \nFIG.', '11\n) compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting TPE, PA-PE polymer foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the TPE, PA-PE base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.', 'FIG.', '12\n provides another example of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, \nFIG.', '12\n shows an example of a polyolefin, which may be a cross-linked polyethylene (XLPE) foam, according to one or more embodiments of the present disclosure.', 'Advantageously, cross-linking polyethylene can significantly improve the low-temperature impact strength, the abrasion resistance, and the environmental stress cracking resistance of the chemical structure.', 'However, cross-linking polyethylene may reduce the hardness and rigidity of the chemical structure to a degree.', 'Because XLPE is similar to elastomers, XLPE does not melt and is thermally resistant.', 'Further, the maximum shear modulus of the chemical structure increases with increasing cross-linking density (even at higher temperatures).', 'Indeed, XLPE has significantly enhanced properties compared to ordinary polyethylene.', 'For example, the cross-linking in XLPE enhances the temperature properties in the base polymer.', 'Adequate strength to 120-150° C. is maintained, and chemical stability is enhanced by resisting dissolution.', 'Low-temperature properties are improved.', 'Impact and tensile strength, scratch resistance, and resistance to brittle fracture are enhanced.', 'According to one or more embodiments of the present disclosure, the XLPE foam shown in \nFIG.', '12\n may be an open cell foam, which may be manufactured by using various chemical foaming agents during a molding process, as previously described.', 'For example, in the previously described chemical foaming process with reference to \nFIG.', '3\n, an open cell foam may be manufactured using XLPE compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting XLPE open cell foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'For example, \nFIGS.', '13\n(A) and \n13\n(B)\n show a polyolefin foam morphology at 200 μm resolution and 100 μm resolution, respectively.', 'As shown in \nFIGS.', '13\n(A) and \n13\n(B)\n, the polyolefin foam morphology includes an open cell structure.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the XLPE base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.', 'FIGS.', '14\n and \n15\n provide another example of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, \nFIG.', '14\n shows an example of a silicone foam process, and \nFIG.', '15\n shows examples of silicone foam.', 'As shown in \nFIG.', '14\n, mixing the constituent components of silicone foam together causes hydrogen gas to form.', 'The hydrogen gas causes the material to expand into a foam.', 'In one or more embodiments, the foam may be cured to improve its strength and ease of handling.', 'According to one or more embodiments of the present disclosure, the silicone foam shown in \nFIGS.', '14\n and \n15\n may be an open cell foam, which may be manufactured by using various chemical foaming agents during a molding process, as previously described.', 'For example, in the previously described chemical foaming process with reference to \nFIG.', '3\n, an open cell foam may be manufactured using silicone foam compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting silicone open cell foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the silicone foam base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.', 'FIG.', '16\n provides another example of a base polymer that may be used in a non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, \nFIG.', '16\n shows an example of an epoxy foam.', 'According to one or more embodiments of the present disclosure, the epoxy foam shown in \nFIG.', '16\n may be an open cell foam, which may be manufactured by using various chemical foaming agents during a molding process, as previously described.', 'For example, in the previously described chemical foaming process with reference to \nFIG.', '3\n, an open cell foam may be manufactured using epoxy foam compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'FIGS.', '17\n(A) and \n17\n(B)\n show an epoxy foam morphology at 500 μm resolution and 200 μm resolution, respectively.', 'As shown in \nFIGS.', '17\n(A) and \n17\n(B)\n, the epoxy foam morphology includes an open cell structure.', 'The resulting epoxy open cell foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the epoxy foam base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.', 'FIG.', '18\n provides another example of a base polymer that may be used in a non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, \nFIG.', '18\n shows an example of a polyimide open cell foam.', 'According to one or more embodiments of the present disclosure, the polyimide open cell foam shown in \nFIG.', '18\n may be manufactured by using various chemical foaming agents during a molding process, as previously described.', 'For example, in the previously described chemical foaming process with reference to \nFIG.', '3\n, an open cell foam may be manufactured using polyimide compounded with (or without) smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting polyimide open cell foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the polyimide base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.', 'The polyimide open cell foam of \nFIG.', '18\n, which may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments the present disclosure, can withstand high temperature applications up to 300° C. Further, the polyimide open cell foam is flexible and recovers sufficiently after mechanical compression by the degradable polymers has been released.', 'Moreover, the formulation of the polyimide open cell foam may be customized with smart fillers in order to enhance compliance and reinforcement.', 'Although a few embodiments of the disclosure have been described in detail above, those of ordinary skill in the art will readily appreciate that many modifications are possible without materially departing from the teachings of this disclosure.', 'Accordingly, such modifications are intended to be included within the scope of this disclosure as defined in the claims.']

['1.', 'A sand screen apparatus for use in a downhole operation for hydrocarbon recovery, comprising:\na non-metallic material having a compressed state and an expanded state, the non-metallic material comprising: a base polymer; and a plurality of smart fillers dispersed within a polymeric matrix of the non-metallic material, wherein a first smart filler of the plurality of smart fillers is configured to facilitate swelling of the non-metallic material in response to a wellbore condition, and wherein a second smart filler of the plurality of smart fillers is configured to facilitate stiffening of the non-metallic material in response to the wellbore condition; and\na mechanical retainer that compresses the non-metallic material in the compressed state.', '2.', 'The apparatus of claim 1, wherein the non-metallic material comprises a foam structure.', '3.', 'The apparatus of claim 1, wherein the non-metallic material comprises an open cell foam.', '4.', 'The apparatus of claim 1, wherein the mechanical retainer is a degradable polymeric wrapping tape.', '5.', 'The apparatus of claim 4, wherein the wellbore condition causes the degradable polymeric wrapping tape to dissolve.', '6.', 'The apparatus of claim 1, wherein the wellbore condition causes the mechanical retainer to release from the non-metallic material.', '7.', 'The apparatus of claim 6, wherein the non-metallic material conforms to a wellbore in the expanded state.', '8.', 'The apparatus of claim 1, wherein the base polymer comprises:\npolyurethane;\nthermoplastic polyurethane;\nthermoplastic elastomer;\npoly ether-ester block copolymer;\npolyamide polyether thermoplastic elastomer;\npolyolefin;\ncross-linked polyethylene;\nsilicone rubber;\nnitrile butadiene rubber (NBR);\nhydrogenated nitrile butadiene rubber (HNBR);\nethylene propylene diene monomer rubber (EPDM);\nfluoroelastomer;\nepoxy;\npolyimide; or\nany combination thereof.', '9.', 'The apparatus of claim 1, wherein the one or the plurality of smart fillers comprises:\nsuperabsorbent polymer;\nethylene propylene diene monomer rubber (EPDM);\nhydrogenated nitrile butadiene rubber (HNBR);\nPortland cement;\naluminous cement;\nfly ash, slag cement;\nMgO;\nZnO;\nCa(OH)2;\nZnCl2;\nMgCl2;\nCaCl2;\nCaCO3;\nNa2CO3;\nK2CO3; or\nany combination thereof.', '10.', 'The apparatus of claim 1, wherein the non-metallic material experiences a modulus increase from the compressed state to the expanded state.', '11.', 'The apparatus of claim 1, wherein the first smart filler is configured to undergo a first chemical reaction in response to the wellbore condition to facilitate the swelling.\n\n\n\n\n\n\n12.', 'The apparatus of claim 11, wherein the second smart filler is configured to undergo a second chemical reaction in response to the wellbore condition to facilitate to the stiffening.', '13.', 'The apparatus of claim 1, wherein:\nthe base polymer comprises: polyurethane; thermoplastic polyurethane; a thermoplastic elastomer; a poly ether-ester block copolymer; a polyamide polyether thermoplastic elastomer; polyolefin; cross-linked polyethylene; silicone rubber; nitrile butadiene rubber (NBR); hydrogenated nitrile butadiene rubber (HNBR); ethylene propylene diene monomer rubber (EPDM); a fluoroelastomer; epoxy; polyimide; or any combination thereof;\nthe first smart filler comprises: a superabsorbent polymer (SAP); ethylene propylene diene monomer rubber (EPDM); hydrogenated nitrile butadiene rubber (HNBR); or any combination thereof; and\nthe second smart filler comprises: Portland cement; aluminous cement; fly ash, slag cement; MgO; ZnO; Ca(OH)2; ZnCl2; MgCl2; CaCl2); CaCO3; Na2CO3; K2CO3; or any combination thereof.', '14.', 'A well completion method, comprising:\ncovering at least one base pipe with a non-metallic material, the non-metallic material comprising: a base polymer; and a plurality of smart fillers, wherein a first smart filler of the plurality of smart fillers is configured to facilitate swelling of the non-metallic material in response to a wellbore condition, and wherein a second smart filler of the plurality of smart fillers is configured to facilitate stiffening of the non-metallic material in response to the wellbore condition;\ncompressing the non-metallic material with a mechanical retainer;\nrunning the base pipe to a location in a wellbore;\nexpanding the non-metallic material;\nconforming the non-metallic material to a wall of the wellbore;\nstiffening the non-metallic material;\nfiltering fluids through the non-metallic material to the base pipe;\ndetaching the non-metallic material from the base pipe; and\nlifting the base pipe out of the wellbore.', '15.', 'The method of claim 14, wherein the mechanical retainer is a degradable polymeric wrapping tape.', '16.', 'The method of claim 15, wherein the expanding step comprises dissolving degradable polymeric wrapping tape.', '17.', 'The method of claim 14, wherein the expanding step comprises releasing the mechanical retainer.', '18.', 'A method of completing a wellbore in a subterranean formation, comprising:\npositioning an expandable sand control apparatus in the wellbore such that an annulus is formed between the expandable sand control apparatus and the wellbore, the expandable sand control apparatus comprising a non-metallic material having an open cell structure, the non-metallic material comprising: a base polymer; and a plurality of smart fillers, wherein a first smart filler of the plurality of smart fillers is configured to facilitate expansion of the non-metallic material to fill the annulus in response to a wellbore condition of the wellbore, and wherein a second smart filler of the plurality of smart fillers is configured to facilitate stiffening of the non-metallic material in response to the wellbore condition.', '19.', 'The method of claim 18, further comprising compressing the expandable sand control apparatus with a mechanical retainer before the positioning step.', '20.', 'The method of claim 19, wherein the mechanical retainer is a degradable polymeric wrapping tape.']

['FIG.', '1 is a sectional view of a sand screen positioned in a wellbore according to one or more embodiments of the present disclosure;; FIGS.', '2(A) and 2(B) show further details of the sand screen according to one or more embodiments of the present disclosure;; FIG.', '3 shows a schematic drawing of a chemical foaming process according to one or more embodiments of the present disclosure;; FIG.', '4 shows an example of an open cell foam according to one or more embodiments of the present disclosure;; FIG.', '5 shows an example of superabsorbent polymers according to one or more embodiments of the present disclosure;; FIGS.', '6(A) and 6(B) provide an example of elastomer foam morphology before and after brine swell;; FIGS. 7(A) and 7(B) show an example of mechanical compress and release according to one or more embodiments of the present disclosure;; FIG.', '7(C) shows a photograph of different degradable layers, which may be used as a mechanical retainer, according to one or more embodiments of the present disclosure;; FIG.', '7(D) shows a photograph of different degradable layers after 48 hrs in KCl 3% brine at different temperatures;; FIG. 7(E) shows tensile properties of a degradable layer (mechanical retainer) after 48 hrs in KCl 3% brine at 200° F.', 'according to one or more embodiments of the present disclosure;; FIG.', '8 shows an example of how a mechanical retainer (i.e., degradable layer or film) may be used according to one or more embodiments of the present disclosure.', '; FIG.', '9 shows an example of TPU chemical structures according to one or more embodiments of the present disclosure;; FIG.', '10 shows an example of a chemical structure of an ether-ester thermoplastic elastomer according to one or more embodiments of the present disclosure;; FIG.', '11 shows a schematic drawing of a polyamide-polyether thermoplastic elastomer structure according to one or more embodiments of the present disclosure;; FIG.', '12 shows an example of a cross-linked polyethylene (XLPE) foam according to one or more embodiments of the present disclosure;; FIGS. 13(A) and 13(B) show a polyolefin foam morphology at 200 μm resolution and 100 μm resolution, respectively;; FIG.', '14 shows an example of a silicone foam process according to one or more embodiments of the present disclosure;; FIG.', '15 shows an example of a silicone foam according to one or more embodiments of the present disclosure;; FIG.', '16 shows an example of an epoxy foam according to one or more embodiments of the present disclosure;; FIGS. 17(A) and 17(B) show an epoxy foam morphology at 500 μm resolution and 200 μm resolution, respectively; and; FIG.', '18 is an example of a polyimide open cell foam according to one or more embodiments of the present disclosure.; FIGS.', '2(A) and 2(B) show further details of the non-metallic compliant screen, according to one or more embodiments of the present disclosure.', 'FIGS.', '2(A) and 2(B) show a compliant screen 211, which comprises a non-metallic compliant material 209 and a filter material or screen 207, which may be constructed in a variety of configurations, e.g., a slotted liner.', 'FIG.', '2(A) shows the compliant screen 211 in its initial, unexpanded state, and FIG.', '2(B) shows the compliant screen 211 in its expanded state.', 'The compliant screen 211 is initially compliant, and according to one or more embodiments, the non-metallic compliant material 209 of the compliant screen 211 includes a base polymer and one or more smart fillers that facilitate swelling and/or reinforcement of the non-metallic compliant material 209 upon reaction with the base polymer.; FIG.', '10 provides another example of a chemical structure of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'Specifically, FIG.', '10 shows a block copolymer of a thermoplastic polyester elastomer (TPE).', 'For example, in the previously described chemical foaming process with reference to FIG. 3, a polymer foam may be manufactured using TPE (such as the block copolymer shown in FIG.', '10) compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting TPE polymer foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the TPE base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.', 'According to one or more embodiments of the present disclosure, commercially available Hytrel® may be used as the TPE base polymer of the non-metallic compliant material.; FIG.', '11 provides another example of a chemical structure of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'Specifically, FIG.', '11 shows a polyamide-polyether (PA-PE) thermoplastic elastomer as the chemical structure.', 'For example, in the previously described chemical foaming process with reference to FIG. 3, a polymer foam may be manufactured using TPE, PA-PE (such as the polymers shown in FIG.', '11) compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting TPE, PA-PE polymer foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the TPE, PA-PE base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.; FIG.', '12', 'provides another example of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, FIG.', '12 shows an example of a polyolefin, which may be a cross-linked polyethylene (XLPE) foam, according to one or more embodiments of the present disclosure.', 'Advantageously, cross-linking polyethylene can significantly improve the low-temperature impact strength, the abrasion resistance, and the environmental stress cracking resistance of the chemical structure.', 'However, cross-linking polyethylene may reduce the hardness and rigidity of the chemical structure to a degree.', 'Because XLPE is similar to elastomers, XLPE does not melt and is thermally resistant.', 'Further, the maximum shear modulus of the chemical structure increases with increasing cross-linking density (even at higher temperatures).', 'Indeed, XLPE has significantly enhanced properties compared to ordinary polyethylene.', 'For example, the cross-linking in XLPE enhances the temperature properties in the base polymer.', 'Adequate strength to 120-150° C. is maintained, and chemical stability is enhanced by resisting dissolution.', 'Low-temperature properties are improved.', 'Impact and tensile strength, scratch resistance, and resistance to brittle fracture are enhanced.; FIGS.', '14 and 15 provide another example of a base polymer that may be used in the non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, FIG.', '14 shows an example of a silicone foam process, and FIG.', '15 shows examples of silicone foam.', 'As shown in FIG.', '14, mixing the constituent components of silicone foam together causes hydrogen gas to form.', 'The hydrogen gas causes the material to expand into a foam.', 'In one or more embodiments, the foam may be cured to improve its strength and ease of handling.; FIG.', '16 provides another example of a base polymer that may be used in a non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, FIG.', '16 shows an example of an epoxy foam.', 'According to one or more embodiments of the present disclosure, the epoxy foam shown in FIG.', '16 may be an open cell foam, which may be manufactured by using various chemical foaming agents during a molding process, as previously described.', 'For example, in the previously described chemical foaming process with reference to FIG. 3, an open cell foam may be manufactured using epoxy foam compounded with smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'FIGS.', '17(A) and 17(B) show an epoxy foam morphology at 500 μm resolution and 200 μm resolution, respectively.', 'As shown in FIGS. 17(A) and 17(B), the epoxy foam morphology includes an open cell structure.', 'The resulting epoxy open cell foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments of the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the epoxy foam base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.; FIG.', '18 provides another example of a base polymer that may be used in a non-metallic compliant material according to one or more embodiments of the present disclosure.', 'For example, FIG.', '18 shows an example of a polyimide open cell foam.', 'According to one or more embodiments of the present disclosure, the polyimide open cell foam shown in FIG.', '18 may be manufactured by using various chemical foaming agents during a molding process, as previously described.', 'For example, in the previously described chemical foaming process with reference to FIG. 3, an open cell foam may be manufactured using polyimide compounded with (or without) smart fillers, which may include swellable or reinforcing fillers for the polymer material, and a chemical foaming agent as previously described.', 'The resulting polyimide open cell foam may be used as the non-metallic compliant material for the sand screen apparatus according to one or more embodiments the present disclosure, which may be mechanically compressed using degradable polymers before deployment downhole as previously described.', 'In a downhole operation, mechanical release of the degradable polymers and reaction of the smart fillers with the polyimide base polymer facilitate expansion of the non-metallic compliant material in accordance with one or more embodiments of the present disclosure, as previously described.']

US11668872

Cladding for an electro-optical device

Aug 21, 2019

Joseph Varkey, Maria Grisanti, David Kim, Qingdi Huang

SCHLUMBERGER TECHNOLOGY CORPORATION

Camesa Downhole Cable Experts, Fiber Optics Cables, (pp. 47, 48 and 49), downloaded Oct. 26, 2020, Link: https://www.camesawireline.com/Portals/0/Documents/2019_Cames_EMC_Catalog.pdf?ver=2019-06-11-101458-960.; Rochester Cables, Engineered Cable Solutions for Harsh Environments, (16 pages) downloaded Oct. 26, 2020, link: https://www.te.com/commerce/DocumentDelivery/DDEController?Action=srchrtrv&DocNm=5-1773453-7_harshenvironments&DocType=DS&DocLang=EN.; International Search Report and Written Opinion issued in the PCT Application PCT/US2020/047170, dated Nov. 30, 2020 (12 pages).; International Preliminary Report on Patentability issued in the PCT Application PCT/US2020/047170 dated Mar. 3, 2022, 9 pages.; Exam Report issued under Section 18(3) in United Kingdom Patent Application GB2202062.2 dated Oct. 27, 2022, 2 pages.

5082380; January 21, 1992; Sutehall; 5204926; April 20, 1993; Bottoms, Jr. et al.; 5222177; June 22, 1993; Chu; 5224190; June 29, 1993; Chu et al.; 6661957; December 9, 2003; Levenson et al.; 6748147; June 8, 2004; Quinn; 6859590; February 22, 2005; Zaccone et al.; 6943300; September 13, 2005; Ekeberg; 7860362; December 28, 2010; Varkey; 7912333; March 22, 2011; Varkey; 9423583; August 23, 2016; Register, III; 10087717; October 2, 2018; Varkey; 10522271; December 31, 2019; Varkey; 20060153508; July 13, 2006; Bowker et al.; 20070081773; April 12, 2007; Pizzorno; 20170343753; November 30, 2017; Bauco; 20210055475; February 25, 2021; Varkey

Foreign Citations not found.

['Sensors for imaging boreholes via the detection of electrical and optical properties may be subject to harsh conditions downhole, such as from pressure and temperature.', 'In addition, these sensors may be subject to impact, such as tension, elongation, and compression forces, along the wall of the borehole.', 'The harsh conditions downhole and impacts on the sensor can lead to premature wear and even breaking.', 'The present disclosure generally relates to an apparatus for measuring electrical and optical properties of the borehole and methods for manufacturing the apparatus.']

['Description\n\n\n\n\n\n\nBACKGROUND\n \nThis disclosure relates to detecting conditions of a borehole.', 'In particular, this disclosure relates to an apparatus for sensing a condition of a borehole based on electrical and optical measurements with structural components that improve the durability.', 'This section is intended to introduce the reader to various aspects of art that may be related to various aspects of the present techniques, which are described and/or claimed below.', 'This discussion is believed to be helpful in providing the reader with background information to facilitate a better understanding of the various aspects of the present disclosure.', 'Accordingly, it should be understood that these statements are to be read in this light, and not as admissions of prior art.', 'Producing hydrocarbons from a wellbore drilled into a geological formation is a remarkably complex endeavor.', 'In many cases, decisions involved in hydrocarbon exploration and production may be informed by measurements from downhole well-logging tools that are conveyed deep into the wellbore.', 'The measurements may be used to infer properties and characteristics of the geological formation surrounding the wellbore.', 'Thus, when a wellbore is investigated to determine the physical condition of a fluid within the wellbore, a gas within the wellbore, or the wellbore itself, it may be desirable to place a cable with associated measurement tools and/or sensors within the wellbore.', 'SUMMARY\n \nA summary of certain embodiments disclosed herein is set forth below.', 'It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure.', 'Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.', 'In one embodiment, the present techniques are directed to a cable that includes one or more optical fibers.', 'The cable also includes a grooved conductor that includes a recess that extends radially outward from a central portion of the grooved conductor to an end portion of the recess, wherein the one or more optical fibers are positioned within the recess, wherein an inner wall of the grooved conductor partially surrounds the one or more optical fibers.', 'Further, the cable includes a cladding disposed around the grooved conductor and over the end portion of the recess, wherein the one or more optical fibers are maintained inside the recess of the grooved conductor, wherein the cladding includes a welded connection along a first end and a second end of the cladding, and wherein the cladding provides increased resistance to mechanical stress and reduced likelihood of gas intrusion to the optical fibers in the grooved conductor of the cable.', 'In another embodiment, the present techniques are direct to a method of manufacturing an electrical-optical cable for a downhole device that includes providing a grooved conductor and one or more optical fibers, wherein the grooved conductor includes a recess.', 'The method also includes coupling one or more optical fibers to the grooved conductor by positioning the one or more optical fibers into the recess of the grooved conductor.', 'Further, the method includes surrounding an outer surface of the grooved conductor with a cladding.', 'Even further, the method includes connecting a first end of the cladding to a second end of the cladding and forming a seal along the connection.', 'In another embodiment, the present disclosure is directed to a method of manufacturing an electrical-optical cable for a downhole device that includes providing a grooved conductor and one or more optical fibers, wherein the grooved conductor includes a recess.', 'The method also includes coupling one or more optical fibers to the grooved conductor by positioning the one or more optical fibers into the recess of the grooved conductor.', 'Further, the method includes providing a silicone material to fill a portion within the recess that is not occupied by the one or more optical fibers.', 'Further still, the method includes surrounding an outer surface of the grooved conductor with a cladding.', 'Even further, the methods includes connecting a first end of the cladding to a second end of the cladding and forming a seal along the connection.', 'Various refinements of the features noted above may be undertaken in relation to various aspects of the present disclosure.', 'Further features may also be incorporated in these various aspects as well.', 'These refinements and additional features may exist individually or in any combination.', 'For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination.', 'The brief summary presented above is intended to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nVarious aspects of this disclosure may be better understood upon reading the following detailed description and upon reference to the drawings in which:\n \nFIG.', '1\n is a schematic diagram of a well-logging system that employs a logging winch system, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\nA\n is a schematic diagram of a cross section of a cable, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\nB\n is a schematic diagram of a cross section of a sensor portion of a cable, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\nC\n is a schematic diagram of a cross section of another cable, in accordance with an embodiment of the present disclosure;\n \nFIG.', '2\nD\n is a schematic diagram of a cross section of another cable, in accordance with an embodiment of the present disclosure;\n \nFIG.', '3\n is a schematic diagram of a cross section of a sensor portion of a cable, in accordance with an embodiment of the present disclosure;\n \nFIG.', '4\n is a schematic diagram of a manufacturing line for a cladded sensor wire, in accordance with an embodiment of the present disclosure;\n \nFIG.', '5\n is an illustration of a cross section of the components of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '4\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '6\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '4\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '7\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '4\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '8\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '4\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '9\n is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '4\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '10\n is an illustration of an example of a cladded sensor wire, in accordance with an embodiment of the present disclosure;\n \nFIG.', '11\n is an illustration of an example of a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure;\n \nFIG.', '12\n is an illustration of another example of a cladded sensor wire with examples of plugs and caps, in accordance with an embodiment of the present disclosure;\n \nFIG.', '13\n is an illustration of an example of a cladded sensor wire with a wedge-shaped plug, in accordance with an embodiment of the present disclosure;\n \nFIG.', '14\n is a schematic diagram of a manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure;\n \nFIG.', '15\n is an illustration of a cross section of the components of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '14\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '16\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '14\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '17\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '14\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '18\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '14\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '19\n is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '14\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '20\n is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '14\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '21\n is a schematic diagram of another manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure;\n \nFIG.', '22\n is an illustration of a cross section of the components of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '21\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '23\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '21\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '24\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '21\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '25\n is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of \nFIG.', '21\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '26\n is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '21\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '27\n is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of \nFIG.', '21\n, in accordance with an embodiment of the present disclosure;\n \nFIG.', '28\n is a schematic diagram of another manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure; and\n \nFIG.', '29\n is a schematic diagram of another manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure.', 'DETAILED DESCRIPTION', 'One or more specific embodiments of the present disclosure will be described below.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, to provide a concise description of these embodiments, all features of an actual implementation may not be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous implementation-specific decisions must be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one implementation to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would still be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'When introducing elements of various embodiments of the present disclosure, the articles “a,” “an,” and “the” are intended to mean that there are one or more of the elements.', 'The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that there may be additional elements other than the listed elements.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'Optical fibers are used in downhole, seismic and other cables to collect distributed temperature, pressure, strain, vibration, and other distributed data and data transfer.', 'Issues with the certain optical fibers are packed in a loose tube or are packed with stranded wires.', 'However, these techniques may not have a working load that is suitable for all downhole conditions.', 'The present disclosure is directed to techniques for improving the durability of optical fibers for downhole measurements.', 'The present techniques eliminate the risk of gas through the optical fibers, reduce the optical strain of the fibers to maximize the safe working load of the cable, increase coupling of the optical fibers and the other components of the cable to lower signal to noise ratio of the optical fibers, the power delivery of the cable, the telemetry performance.', 'Thus, the optical fibers may be used to convey a large number of possible optical signals.', 'In some examples, these signals are used to perform measurements, and so much of the discussion below will involve examples in which the optical-fiber-containing cables are used as sensor tools.', 'However, it should be understood that these systems and methods may apply to any suitable cables that employ optical fibers to carry any suitable signal.', 'One embodiment of the present disclosure relates to a method of manufacturing a cladded wire containing an optical fiber(s) and conductors, which is referred to below as a sensor cladded wire, but which may represent any suitable optical-fiber-containing cable that carries any suitable signal.', 'The sensor cladded wire includes optical fibers provided within a recess of a conducting wire portion and is surrounded by cladding and/or shield.', 'As referred to herein, a cross section of the conducting wire portion is a shield structure.', 'It should be appreciated by one of ordinary skill in the art that by having the optical fibers surrounded by the grooved conductor, which is a continuous, single unit of conducting material, may reduce the likelihood of damage to the optical fibers during transport or operation, for example.', 'Additionally, the fiber optics and grooved conductor are surrounded by cladding (e.g., cladded sensor wire).', 'In one embodiment, the components of the sensor cladded wire that are interior to the cladding are coated with silicone to further reduce the likelihood of gas intrusion to optical fibers.', 'In another embodiment, the sensor cladded wire includes a plug that may provide structural support for and improved mechanical durability of the optical fibers.', 'With this in mind, \nFIG.', '1\n illustrates a non-limiting example of a well-logging system \n10\n that may employ the formation texture and rock type identification systems and methods of this disclosure.', 'It should be appreciated by one of ordinary skill in the art that various other well-logging systems may be employed, such as a well-logging system used for hydraulic fracturing.', 'Further, the well-logging system \n10\n may be deployed by various suitable means.', 'The well-logging system \n10\n may be used to convey a downhole tool \n12\n through a geological formation \n14\n via a wellbore \n16\n (also sometimes referred to as a borehole).', 'The downhole tool \n12\n is conveyed on a cable \n18\n via a logging winch system \n20\n.', 'Although the logging winch system \n20\n is schematically shown in \nFIG.', '1\n as a mobile logging winch system carried by a truck, the logging winch system \n20\n may be substantially fixed (e.g., a long-term installation that is substantially permanent or modular).', 'Any suitable cable \n18\n for well logging may be used.', 'The cable \n18\n may be spooled and unspooled on a drum \n22\n and an auxiliary power source \n24\n may provide energy to the logging winch system \n20\n and/or the downhole tool \n12\n.', 'As discussed further below, the downhole tool \n12\n may include a number of sensors used to acquire data \n26\n about the wellbore \n16\n and/or geological formation \n14\n by taking measurements.', 'In other embodiments, the optical fibers in cable \n18\n may be used as distributed sensor throughout the whole cable length to acquire data \n26\n about the wellbore \n16\n and/or geological formation \n14\n by taking measurements.', 'The data \n26\n may be sent to a data processing system \n28\n, which may analyze the data \n26\n to identify characteristics of the wellbore \n16\n and/or the geological formation \n14\n.', 'The data processing system \n28\n may be any electronic data processing system that can be used to carry out the systems and methods of this disclosure.', 'For example, the data processing system \n28\n may include a processor \n30\n, which may execute instructions stored in memory \n32\n and/or storage \n34\n.', 'As such, the memory \n32\n and/or the storage \n34\n of the data processing system \n28\n may be any suitable article of manufacture that can store the instructions.', 'The memory \n32\n and/or the storage \n34\n may be ROM memory, random-access memory (RAM), flash memory, an optical storage medium, or a hard disk drive, to name a few examples.', 'A display \n36\n, which may be any suitable electronic display, may display the images generated by the processor \n30\n.', 'The data processing system \n28\n may be a local component of the logging winch system \n20\n, a remote device that analyzes data from other logging winch systems \n20\n, or partly local and partly remote.', 'In some embodiments, the data processing system \n28\n may be a mobile computing device (e.g., tablet, smartphone, or laptop) or a server remote from the logging winch system \n20\n.\n \nFIG.', '2\nA\n is a cross sectional view of one embodiment of the cable \n18\n.', 'The cable \n18\n may be continuous or sectioned, and may be 1 meter (m), 10 m, 100 m, 1000 m or more meters in length.', 'The cable \n18\n may house a cable core \n40\n, which may be circumferentially surrounded by one or more armor wire strength members \n42\n.', 'The armor wire strength members \n42\n may be served (e.g., coiled helically) around the cable core \n40\n, extend longitudinally along the length of the cable core \n40\n, or be disposed about the cable core \n40\n in any fashion suitable to surround the cable core \n40\n.', 'The armor wire strength members \n42\n may physically protect the cable core \n40\n and may provide additionally rigidity to the cable \n18\n.', 'In addition, the armor wire strength members \n42\n may support the weight of the cable \n18\n and alleviate strain on the cable core \n40\n.', 'In other embodiments, the cable \n18\n may be fully jacketed by means of reinforced jacket over the armor wire strength members \n42\n.', 'The cable core \n40\n may include one or more signal cables \n44\n.', 'The signal cables \n44\n may include internal wires \n46\n disposed within protective structures \n48\n.', 'The internal wires \n46\n may include copper wires \n50\n, optical-fiber-containing sensor wires \n52\n, or any other suitable wires desired within the cable \n18\n.', 'The optical-fiber-containing sensor wires \n52\n may include one or more optical fibers \n54\n disposed within grooved conductors \n56\n.', 'The one or more optical fibers \n54\n may serve as sensors (e.g., pressure sensor, temperature sensor, vibration sensor, strain sensor) which may sense internal conditions of the wellbore \n16\n (e.g., pressure, temperature) and relay data regarding the internal conditions to the data processing system \n28\n.', 'The internal wires \n46\n may additionally transmit instructional signals or electrical power to a component coupled to the end of the cable \n18\n (e.g., the downhole tool \n12\n).', 'The optical-fiber-containing sensor wires \n52\n may also be disposed within the armor wire strength member \n42\n.', 'FIG.', '2\nB\n is a cross sectional view of a marine cable \n55\n.', 'The marine cable \n55\n may include the cable core \n40\n.', 'The cable core \n40\n may include the one or more signal cables \n44\n.', 'The signal cables \n44\n may include the internal wires \n46\n disposed within the protective structures \n48\n.', 'The internal wires \n46\n may include the sensors (e.g., the one or more optical fibers \n54\n), copper wires \n50\n, or any other suitable wires desired within the cable \n18\n.', 'The internal wires \n46\n may also include the optical-fiber-containing sensor wires \n52\n.', 'The internal wires \n46\n may transmit instructional signals or electrical power to a component coupled to the end of the marine cable \n55\n (e.g., the downhole tool \n12\n).', 'The protective structures \n48\n may encase the internal wires \n46\n and physically protect the internal wires during operation of the cable \n18\n.', 'To achieve a better signal to noise ratio with regard to the parameters being monitored (e.g., temperature, pressure, seismic profiling, or others), the optical-fiber-containing sensor wires \n52\n may be located near the outside perimeter of the marine cable \n55\n.', 'The optical-fiber-containing sensor wires \n52\n may be disposed within a shielding layer \n57\n of the marine cable \n55\n.', 'The shielding layer \n57\n may additionally be encased by a protective outer layer \n59\n.', 'It should be appreciated by one of ordinary skill in the art that the optical-fiber-containing sensor wires \n52\n, or those with cladding (e.g., cladded sensors wires \n58\n), as discussed further below, may be used for the cables above as well as various other suitable types of cables.', 'For example, \nFIG.', '2\nC\n and \nFIG.', '2\nD\n illustrates a hepta cable \n51\n and coax jacket cables \n55\na, \n55\nb, \nrespectively, that include cladded sensor wires \n58\n.\n \nFIG.', '3\n illustrates a cross-sectional view of an embodiment of a cladded sensor wire \n58\n (e.g., cladded one-piece optical-fiber-containing sensor wire \n52\n or electrical-optical cable).', 'To facilitate discussion, the various embodiments of the cladded sensor wire \n58\n may be described with reference to an ‘x’ direction \n60\n, a ‘y’ direction \n62\n, and a ‘z’ direction \n64\n.', 'The cladded sensor wire \n58\n includes a grooved conductor \n56\n disposed about the one or more optical fibers \n54\n.', 'The grooved conductor \n56\n may include a conductor (e.g., copper) or any alloy suitable for the desired purpose.', 'The one or more optical fibers \n54\n may be disposed within a recess \n66\n of the grooved conductor \n56\n.', 'The one or more optical fibers \n54\n may be embedded symmetrically, or asymmetrically within the recess \n66\n.', 'The recess \n66\n may extend radially from the center of the grooved conductor \n56\n to an outer surface \n68\n of the grooved conductor \n56\n.', 'Although \nFIG.', '3\n shows an embodiment of the grooved conductor \n56\n with a generally circular or C-shape, the grooved conductor \n56\n may take any suitable shape, such as square, triangular, or oval.', 'As shown, there is a small gap within the recess \n66\n between the optical fibers \n54\n and the interior surface \n70\n of the grooved conductor.', 'The small gap may facilitate the placement of the optical fibers \n54\n within the recess \n66\n.', 'In some embodiments, the small gap (e.g., distance between the interior surface \n70\n of the grooved conductor \n56\n and the optical fibers \n54\n may be smaller and may maintain a coupling effect.', 'For example, the grooved conductor \n56\n and optical fibers \n54\n may be in physical contact with an interior surface \n70\n of the recess \n66\n.', 'The interior surface \n70\n may contact the one or more optical fibers \n54\n at diametrically opposite contact points \n72\n, such that the interior surface \n70\n may extend tangentially to the diametrically opposite contact points \n72\n.', 'The diametrically opposite contact points \n72\n may ensure that any external pressure applied to the grooved conductor \n56\n will apply a transverse (e.g., ‘y’ direction \n62\n) force to the one or more optical fibers \n54\n.', 'Ideally, the pressure may be applied to the grooved conductor \n56\n in a direction perpendicular to the interior surface \n70\n of the recess \n66\n (e.g., ‘y’ direction \n62\n).', 'Additionally or alternatively, pressure may be applied to the grooved conductor \n56\n in any combination of the ‘x’ direction \n60\n, ‘y’ direction \n62\n, and/or ‘z’ direction \n64\n.', 'As illustrated, the grooved conductor \n56\n is not completely circular.', 'In particular, when the cladding \n74\n surrounds the grooved conductor \n56\n, a recess \n61\n (e.g., void, or gap) is formed between the cladding \n74\n and grooved conductor \n56\n.', 'The recess \n61\n may be useful for pressure testing the cladded sensor wire \n58\n during assembly, as discussed further below.', 'Additionally, the recess \n61\n may reduce any mechanical stress that results from thermal expansion of the grooved conductor \n58\n.', 'The ends \n73\n and \n75\n of the cladding are connected (e.g., welded), forming a welded connection \n76\n.', 'As illustrated, the welded connection is radially offset from the opening of the recess \n66\n.', 'That is, the opening of the recess \n66\n and the welded connection \n76\n may not overlap.', 'As discussed herein, it may be advantageous to offset the welded connection from the opening of the recess \n66\n in assembly.\n \nFIG.', '4\n is a schematic diagram of a manufacturing line \n77\n that may be utilized to generate the cladded sensor wire \n58\n, as shown in \nFIG.', '3\n, in accordance with an embodiment of the present disclosure.', 'In general, the optical fibers \n54\n are placed inside the recess \n66\n of the grooved conductor \n56\n followed by providing a cladding \n74\n around the grooved conductor \n56\n that includes the one or more optical fibers \n54\n.', 'It should be appreciated that the manufacturing line \n77\n may be used for any number of optical fibers \n54\n.', 'At station \n78\n, optical fiber(s) \n54\n, the grooved conductor \n56\n, and the cladding \n74\n are provided in respective pay-offs \n80\na, \n80\nb, \nand \n80\nc \nrespectively.', 'In some embodiments, the pay-off \n80\na \nincludes multiple optical fibers \n54\n, or three pay-offs \n80\na \nare provided that each include an optical fiber \n54\n.', 'The grooved conductor \n56\n (e.g., a wire-like structure that is shaped to have the grooved conductor \n56\n cross section) is guided through the manufacturing line \n77\n to the station \n82\n which includes straighteners \n84\n, rollers \n88\n, and tension sensors \n86\n to maintain groove orientation, shaped conductor (e.g., grooved conductor \n56\n) form, and alignment for a subsequent positioning of the cladding \n74\n.', 'At station \n90\n, the optical fibers \n54\n are inserted into the recess \n66\n of the grooved conductor \n56\n and maintained until the cladding \n74\n is added.', 'It should be appreciated that the type of alignment rollers is dependent on the shape of the grooved conductor \n56\n and/or number of optical fibers \n54\n.', 'At station \n92\n, the cladding \n74\n is positioned around the grooved conductor \n56\n that includes the optical fiber(s) \n54\n, thus producing the cladded sensor wire \n58\n.', 'It should be appreciated that any suitable machines may be used for providing (e.g., positioning, forming) the cladding \n74\n around the grooved conductor \n56\n that includes the optical fiber(s) \n54\n, such as insertion rollers.', 'Positioning the cladding \n74\n includes rolling the cladding \n74\n such that the cladding \n74\n forms a circular tube that surrounds the grooved conductor \n56\n.', 'At station \n94\n, the ends \n73\n and \n75\n of the cladding \n74\n are welded together to produce a welded connection \n76\n.', 'As discussed above, with regards to \nFIG.', '3\n, the welded connection \n76\n may be offset from the opening in the recess \n66\n.', 'This may reduce the likelihood of damaging the optical fiber(s) \n54\n during manufacturing such as during welding connection \n76\n process.', 'Returning back to manufacturing line \n77\n, the cladding \n74\n with the welded connection \n76\n are drawn through a die to create a tight fit between the grooved conductor \n56\n (e.g., along the outer surface \n68\n of the grooved conductor \n56\n) and the cladding \n74\n, at station \n96\n.', 'Any void spaces between the cladding \n74\n and the grooved conductor \n56\n may be used to pressure test the cladding \n74\n and ensure that no pinholes or defects are present.', 'Then, the cladded sensor wire \n58\n may be inspected (i.e., carry out performance tests, leak tests such as eddy current, laser diameter, or other suitable techniques) at station \n98\n before passing through a station \n100\n (e.g., that may include a capstan unit) to produce a packaged cladded sensor wire at station \n102\n (e.g., rolled up in a pay-off).', 'FIGS.', '5\n-\n9\n show several points in time of the optical fibers \n54\n, the grooved conductor \n56\n, cladding \n74\n, and cladded sensor wire \n58\n during the stations \n78\n, \n90\n, \n92\n, \n94\n, and \n96\n of the manufacturing line \n77\n, as described for \nFIG.', '4\n.', 'For example, \nFIG.', '5\n is an illustration of a cross section of the optical fibers \n54\n, a cross section of the grooved conductor \n56\n, and a cross section of the cladding \n74\n, which are in respective pay-offs \n80\na, \n80\nb, \nand \n80\nc, \nin station \n78\n.', 'FIG.', '6\n shows three optical fibers \n54\n positioned in the recess \n66\n of the grooved conductor \n56\n, representing a point in time of station \n90\n of the manufacturing line \n77\n. \nFIG.', '7\n (left) shows the cladding \n74\n positioned around the grooved conductor \n56\n that includes the optical fibers \n54\n, representing a point in time of station \n92\n of the manufacturing line \n77\n.', 'The arrows \n104\n illustrated the cladding \n74\n disposed radially about the grooved conductor \n56\n.', 'FIG.', '7\n (right) shows the cladding \n74\n positioned around the grooved conductor \n56\n, representing a second point in time of station \n92\n of the manufacturing line #. \nFIG.', '8\n shows the cladding \n74\n connected along the ends \n75\n and \n73\n with a welded connection \n76\n, representing a point in time of station \n94\n of the manufacturing line \n77\n.', 'As illustrated, the outer surface \n68\n of the grooved conductor \n56\n and the inner surface \n105\n of the cladding \n74\n are separated by a first distance \n106\n.', 'FIG.', '9\n shows the cladding \n74\n connected along the ends \n73\n and \n75\n with a welded connection \n76\n, representing a point in time of station \n96\n of the manufacturing line \n77\n.', 'As illustrated, the outer surface \n68\n of the grooved conductor \n56\n and the inner surface \n105\n of the cladding \n74\n are separated by a second distance \n108\n that is smaller than the first distance \n106\n.', 'This is indicative of the tight fit created in station \n96\n.', 'FIGS.', '10\n-\n13\n show several embodiments of the cladded sensor wire \n58\n.', 'FIG.', '10\n shows a cladded sensor wire \n58\na \nthat includes two grooved conductors \n56\na \nand \n56\nb.', 'Each grooved conductor \n56\na \nand \n56\nb \npartially surround the optical fibers \n54\n.', 'As illustrated, the grooved conductors \n56\na \nand \n56\nb \neach are generally a semi-circle and each grooved conductor may include a respective recess \n66\n where the optical fiber \n54\n reside.', 'In some embodiments, each grooved conductor \n56\na \nand \n56\nb \ngenerally form different fractions of a circle (10%, 25%, 50%, and 75%).', 'For example, grooved conductor \n56\na \nmay form a quarter circle and grooved conductor \n56\nb \nmay form three-quarters of a circle.', 'FIGS.', '11\n-\n13\n shows different examples of cross sections of cladded sensor wires \n58\n that include plugs/caps \n110\n. \nFIG.', '11\n shows a cross section of a cladded sensor wire \n58\nb \nthat includes a grooved conductor \n56\n and plug \n110\n.', 'In some embodiments, a plug \n110\n may be inserted into the first end portion \n112\n of the recess \n66\n, forming an enclosed recess \n113\n within the grooved conductor \n56\n.', 'The plug \n110\n may be pressure fit into the grooved conductor \n56\n and/or bonded to the grooved conductor via an adhesive (e.g., welding, bonding glue).', 'The plug \n110\n may extend longitudinally (e.g., ‘z’ direction \n64\n) along the length of the grooved conductor \n56\n and form a hermetic seal between the one or more optical fibers \n54\n within the enclosed recess \n113\n and an external environment \n80\n.', 'The external environment \n80\n may contain fluids that can damage a coating of the one or more optical fibers \n54\n and result in optical losses within the one or more optical fibers \n54\n.', 'For example, the ingress of hydrogen into the enclosed recess \n113\n may result in a subsequent formation of hydroxide ions (OH—) that may absorb light at a number of important wavelengths, thereby decreasing the signal strength of the one or more optical fibers \n54\n.', 'In some embodiments, the cladded sensor wire \n58\n may be a pressure sensor.', 'For example, the plug \n110\n may additionally form an elongated pressure seal which may ensure that the pressure differential between the enclosed recess \n113\n and the external environment \n80\n is not equalized.', 'The space between the enclosed recess \n113\n and the one or more optical fibers \n54\n may include a buffer fluid.', 'In one embodiment, the buffer fluid may include a gas such as air; in another, a vacuum may be employed in place of the buffer fluid.', 'Employing air as the buffer fluid may reduce or eliminate variations in pressure readings caused by manometric effects (e.g., the sensor reading the weight of the buffer fluid rather than the external pressure).', 'The plug \n110\n may include any suitable material, such as copper, aluminum, or organic compounds.', 'Moreover, multiple optical fibers \n54\n can be inserted in the enclosed recess \n113\n (i.e., the recess \n66\n before the plug \n110\n is inserted) to provide different information.', 'This may be due to the different positions of the multiple optical fibers \n54\n in the recess \n66\n.', 'In addition, optical fibers \n54\n with symmetric internal structures that inserted in different orientations may experience different responses to external pressure.', 'In general, the grooved conductor \n56\n and the plug \n110\n may have various combinations of shapes.', 'That is, in some embodiments, the plug \n110\n may act as a cap to the grooved conductor \n56\n (e.g., resides on top of the grooved conductor \n56\n), while in other embodiments, a portion of the plug \n110\n may reside in the recess \n66\n of the grooved conductor \n56\n. \nFIG.', '11\n also shows a cross section of a cladded sensor wire \n58\nc \nwith optical fibers \n54\n that includes a grooved conductor \n56\n with a plug \n110\na \nthat forms the enclosed recess \n113\n.', 'The plug \n110\na \nis a strand of conductors \n114\n.', 'FIG.', '12\n shows a cross section of cladded sensor wires \n58\nd \nand \n58\ne \nthat each include optical fibers \n54\n.', 'The cladded sensor wire \n58\nd \nincludes a grooved conductor \n56\nc \nwith a plug \n110\nb \nthat forms the enclosed recess \n113\n.', 'As illustrated, the plug \n110\nb \nis a shaped such that it couples to (e.g., resides in) a portion \n116\n of the grooved conductor \n56\nc.', 'The cladded sensor wire \n58\ne \nincludes a grooved conductor \n56\nd \nwith a plug \n110\nc \nthat forms the enclosed recess \n113\n.', 'As illustrated, the plug \n110\nc \nis shaped such that it couples to a portion \n112\n of the grooved conductor \n56\nd. \nFIG.', '13\n shows a cross section of a cladded sensor wire \n58\nf \nwith optical fibers \n54\n that includes a grooved conductor \n56\ne \nwith a plug \n110\ne \nthat forms the enclosed recess \n113\n.', 'The plug \n110\ne \nis a wedge that is shaped to couple with the grooved conductor \n56\ne.', 'The various embodiments illustrated in \nFIGS.', '10\n-\n13\n may protect the optical fibers \n54\n during the welding (e.g., at station \n94\n).', 'Further, these techniques may provide greater collapse and shear resistance and potentially deliver more power as the cross sectional area of the conductor (e.g., grooved conductor \n56\n and plugs/caps \n110\n) is larger compare to conductors \n56\n without plug/caps \n110\n shown in \nFIG.', '8\n-\n9\n.', 'Additionally, the optical fibers \n54\n, plus \n110\n, and grooved conductors \n56\n of each of the cladded sensor wires \n58\n shown in \nFIG.', '10\n-\n13\n may assembled, positioned, and locked in place before the cladding \n74\n is added.\n \nFIG.', '14\n is a schematic diagram of a manufacturing line \n77\na \nthat may be utilized to generate the cladded sensor wires \n58\n, such as the cladded sensor wires shown in \nFIGS.', '10\n-\n13\n, in accordance with an embodiment of the present disclosure.', 'The disclosed techniques provide a process for simultaneous process of assembling for the cladded sensor wire \n58\n, which provides several advantages (e.g., improved power, reduced strain) as discussed herein.', 'In general, the optical fibers \n54\n are placed inside the recess \n66\n of the grooved conductor \n56\n followed by providing a cladding \n74\n around the grooved conductor \n56\n that includes the one or more optical fibers \n54\n.', 'It should be appreciated that the manufacturing line \n77\na \nmay be used for any number of optical fibers \n54\n.', 'At station \n78\na, \noptical fiber(s) \n54\n, the grooved conductor \n56\n, and the cladding \n74\n are provided in respective pay-offs \n80\na, \n80\nb, \nand \n80\nc \nrespectively.', 'Additionally, station \n78\na \nof the manufacturing line \n77\na \nincludes a payoff \n80\nd \nthat includes the plug \n110\n.', 'In some embodiments, the pay-off \n80\na \nincludes multiple optical fibers \n54\n, or three pay-offs \n80\na \nare provided that each include an optical fiber \n54\n.', 'The grooved conductor \n56\n (e.g., a wire-like structure that is shaped to have the grooved conductor \n56\n cross section) is guided through the manufacturing line \n77\na \nto the station \n82\nb \nwhich includes straighteners \n84\n, rollers \n88\n, and tension sensors \n86\n to maintain groove orientation, shaped conductor form, and alignment for a subsequent positioning of the cladding \n74\n.', 'The plug \n110\n is guided to a station \n82\na \nwhich includes straighteners \n84\n, rollers \n88\n, and tension sensors \n86\n.', 'It should be appreciated that the type of alignment rollers is dependent on the shape of the grooved conductor \n56\n and/or number of optical fibers \n54\n.', 'At station \n118\n the optical fibers are coated with silicone, or other suitable filler material such as various polymers or resin.', 'The silicone may fill void spaces in the recess, as discussed in more detail below, (e.g., spaces not occupied by the optical fibers \n54\n), which may further reduce the void spaces for the fluid to travel, which reduces likelihood of leaks, improves coupling between the components (e.g., optical fibers \n54\n and grooved conductor \n56\n), and provide support for the optical fibers \n54\n.', 'Then, at station \n90\na, \nthe optical fibers \n54\n, which are now coated with silicone, are inserted into the recess \n66\n of the grooved conductor \n56\n and plug \n110\n is inserted or placed on recess \n66\n (e.g., into end portion \n112\n or portion \n116\n) of the grooved conductor \n56\n and maintained until the cladding \n74\n is added.', 'At station \n92\n, the cladding \n74\n is positioned around the grooved conductor \n56\n that includes the optical fiber(s) \n54\n coated with a silicone layer, thus producing the cladded sensor wire \n58\n.', 'It should be appreciated that any suitable machines may be used for providing (e.g., positioning, forming) the cladding \n74\n around the grooved conductor \n56\n that includes the optical fiber(s) \n54\n, such as insertion rollers.', 'Then, the grooved conductor \n56\n, which includes the optical fibers(\n2\n) \n54\n coated with silicone, is immersed in a silicone application unit (e.g., station \n120\n) that may include application of silicone to outer spaces of the grooved conductor \n56\n and techniques for removing excess silicone material.', 'Additionally, station \n120\n may include a silicone curing step (e.g., through heat or ultraviolet (UV) radiation).', 'Further, the station \n120\n may include an external silicone application and/or curing step.', 'Continuing with the manufacturing line \n77\na, \nat station \n94\n, the ends \n73\n and \n75\n of the cladding \n74\n are welded together to produce a welded connection \n76\n.', 'Then, the cladding \n74\n with the welded connection \n76\n are drawn through a die to create a tight fit between the grooved conductor \n56\n (e.g., along the outer surface \n68\n of the grooved conductor \n56\n) and the cladding \n74\n, at station \n96\n.', 'Then, the cladded sensor wire \n58\n may be inspected at station \n98\n before passing through a station \n100\n (e.g., that may include a capstan unit) to produce a packaged cladded sensor wire at station \n102\n (e.g., rolled up in a pay-off).', 'FIGS.', '15\n-\n20\n show several points in time of the optical fibers \n54\n, the grooved conductor \n56\n, cladding \n74\n, and cladded sensor wire \n58\n during the stations \n78\na, \n90\na, \n120\n, \n92\n, \n94\n, and \n96\n of the manufacturing line \n77\na, \nas described for \nFIG.', '14\n.', 'For example, \nFIG.', '15\n is an illustration of a cross section of the optical fibers \n54\n, a cross section of the grooved conductor \n56\n, a cross section of the cladding \n74\n, and a cross section of the plug \n110\n, which are in respective pay-offs \n80\na, \n80\nb, \n80\nc, \nand \n80\nd, \nin station \n78\na. \nFIG.', '16\n shows three optical fibers \n54\n positioned in the recess \n66\n of the grooved conductor \n56\n and the plug \n110\n positioned in the end portion \n112\n, representing a point in time of station \n90\na \nof the manufacturing line \n77\na. \nFIG.', '17\n shows the cured silicone \n122\n that fills different voids in the grooved conductor \n56\n representing in time of station \n120\n. \nFIG.', '18\n (top) shows the cladding \n74\n positioned around the grooved conductor \n56\n that includes the optical fibers \n54\n and the cured silicone \n122\n, representing a point in time of station \n92\n of the manufacturing line \n77\na.', 'The arrows \n104\n illustrated the cladding \n74\n disposed radially about the grooved conductor \n56\n.', 'FIG.', '18\n (bottom) shows the cladding \n74\n positioned around the grooved conductor \n56\n, representing a second point in time of station \n92\n of the manufacturing line \n77\na. \nFIG.', '19\n shows the cladding \n74\n connected along the ends \n75\n and \n73\n with a welded connection \n76\n, representing a point in time of station \n94\n of the manufacturing line \n77\na. \nAs illustrated, the outer surface \n68\n of the grooved conductor \n56\n and the inner surface \n105\n of the cladding \n74\n are separated by a first distance \n106\n.', 'FIG.', '20\n shows the cladding \n74\n connected along the ends \n73\n and \n75\n of the cladding \n74\n with a welded connection \n76\n, representing a point in time of station \n96\n of the manufacturing line \n77\na. \nAs illustrated, the outer surface \n68\n of the grooved conductor \n56\n and the inner surface \n105\n of the cladding \n74\n are separated by a second distance \n108\n that is smaller than the first distance \n106\n.', 'This is indicative of the tight fit created in station \n96\n.\n \nFIG.', '21\n is a schematic diagram of a manufacturing line \n77\nb \nthat may be utilized to generate the cladded sensor wires \n58\n surrounded with conductors (e.g., \n126\n shown in \nFIGS.', '24\n-\n27\n), and the inner cladded sensor wires \n58\n may be any of the cladded sensor wires \n58\n shown in \nFIGS.', '10\n-\n15\n, in accordance with an embodiment of the present disclosure.', 'In general, the optical fibers \n54\n are placed inside the recess \n66\n of the grooved conductor \n56\n followed by providing a cladding \n74\n around the grooved conductor \n56\n that includes the one or more optical fibers \n54\n.', 'It should be appreciated that the manufacturing line \n77\nb \nmay be used for any number of optical fibers \n54\n.', 'At station \n78\na, \noptical fiber(s) \n54\n, the grooved conductor \n56\n, and the cladding \n74\n are provided in respective pay-offs \n80\na, \n80\nb, \nand \n80\nc \nrespectively.', 'Additionally, station \n78\na \nof the manufacturing line \n77\nb \nincludes a payoff \n80\nd \nthat includes the plug \n110\n.', 'In some embodiments, the pay-off \n80\na \nincludes multiple optical fibers \n54\n, or three pay-offs \n80\na \nare provided that each include an optical fiber \n54\n.', 'The grooved conductor \n56\n (e.g., a wire-like structure that is shaped to have the grooved conductor \n56\n cross section) is guided through the manufacturing line \n77\nb \nto the station \n82\nb \nwhich includes straighteners \n84\n, rollers \n88\n, and tension sensors \n86\n to maintain groove orientation, shaped conductor form, and alignment for a subsequent positioning of the cladding \n74\n.', 'The plug \n110\n is guided to a station \n82\na \nwhich includes straighteners \n84\n, rollers \n88\n, and tension sensors \n86\n.', 'At station \n90\na, \nthe optical fibers \n54\n are inserted into the recess \n66\n of the grooved conductor \n56\n.', 'Additionally, the plug \n110\n is inserted into the recess \n66\n (e.g., into end portion \n112\n or portion \n116\n) of the grooved conductor \n56\n.', 'It should be appreciated that the type of alignment rollers is dependent on the shape of the grooved conductor \n56\n, the plug \n110\n, and/or number of optical fibers \n54\n.', 'At station \n124\n, conductors may be formed (e.g., helically stranded) and positioned around the grooved conductor \n56\n and plug \n110\n, which may further reinforce and improve the electrical properties of the electrical portion (e.g., grooved conductor \n56\n) of the cladded sensor wire \n58\n.', 'At station \n92\nb, \nthe cladding \n74\n is positioned around the conductors (e.g., that were positioned around the grooved conductor \n56\n and the plug \n110\n in station \n124\n), thus producing the cladded sensor wire \n58\n.', 'It should be appreciated that any suitable machines may be used for providing (e.g., positioning, forming) the cladding \n74\n around the grooved conductor \n56\n that includes the optical fiber(s) \n54\n, such as insertion rollers.', 'At station \n94\n, the ends \n73\n and \n75\n of the cladding \n74\n are welded together to produce a welded connection \n76\n.', 'Then, the cladding \n74\n with the welded connection \n76\n are drawn through a die to create a tight fit between the grooved conductor \n56\n (e.g., along the outer surface \n68\n of the grooved conductor \n56\n) and the cladding \n74\n, at station \n96\n.', 'Then, the cladded sensor wire \n58\n may be inspected at station \n98\n before passing through a station \n100\n (e.g., that may include a capstan unit) to produce a packaged cladded sensor wire at station \n102\n (e.g., rolled up in a pay-off).', 'FIGS.', '22\n-\n27\n show several points in time of the optical fibers \n54\n, the grooved conductor \n56\n, cladding \n74\n, and cladded sensor wire \n58\n during the stations \n78\na, \n90\na, \n124\n, \n92\nb, \n94\n, and \n96\n of the manufacturing line \n77\nb, \nas described herein.', 'For example, \nFIG.', '22\n is an illustration of a cross section of the optical fibers \n54\n, a cross section of the grooved conductor \n56\n, a cross section of the cladding \n74\n, and a cross section of the plug \n110\n, which are in respective pay-offs \n80\na, \n80\nb, \n80\nc, \nand \n80\nd, \nin station \n78\na. \nFIG.', '23\n shows three optical fibers \n54\n positioned in the recess \n66\n of the grooved conductor \n56\n and the plug \n110\n positioned in the end portion \n112\n, representing a point in time of station \n90\na \nof the manufacturing line \n77\na. \nFIG.', '24\n shows conductors \n126\n positioned on the outer surface \n68\n of the grooved conductor \n56\n, representing a point in time of the station \n124\n of the manufacturing line \n77\nb. \nFIG.', '25\n (left) shows the cladding \n74\n positioned around the conductors \n126\n that surround the grooved conductor \n56\n and the plug \n110\n, representing a point in time of station \n92\nb \nof the manufacturing line \n77\nb.', 'The arrows \n104\n illustrate positioning of the cladding \n74\n disposed radially about the conductors \n126\n. \nFIG.', '25\n (right) shows the cladding \n74\n positioned around the grooved conductor \n56\n, representing a second point in time of station \n92\n of the manufacturing line \n77\nb. \nFIG.', '26\n shows the cladding \n74\n connected along the ends \n75\n and \n73\n with a welded connection \n76\n, representing a point in time of station \n94\n of the manufacturing line \n77\nb.', 'As illustrated, the outer surface \n127\n of each conductor \n126\n and the inner surface \n105\n of the cladding \n74\n are separated by a first distance \n106\na. \nFIG.', '27\n shows the cladding \n74\n connected along the ends \n73\n and \n75\n of the cladding \n74\n with a welded connection \n76\n, representing a point in time of station \n96\n of the manufacturing line \n77\nb.', 'As illustrated, the outer surface \n127\n of each conductor \n126\n and the inner surface \n105\n of the cladding \n74\n are separated by a second distance \n108\na \nthat is smaller than the first distance \n106\na.', 'This is indicative of the tight fit created in station \n96\n.', 'As discussed herein, a manufacturing line \n77\n for a cladded sensor wire \n58\n may include an inspection station (e.g., station \n98\n).', 'In some embodiments, creating a tight fit between the cladding \n74\n and the grooved conductor \n56\n may prevent a pressure test during the manufacturing line \n77\n.', 'As such, \nFIGS.', '28\n and \n29\n are directed to a two-step manufacturing line providing cladding \n74\n on the grooved conductor \n56\n.', 'For example, one step may include partially drawing down the cladding \n74\n on the grooved conductor \n56\n by making the distance \n106\n (e.g., as described above for \nFIG.', '8\n) suitable for a pressure test.', 'In certain embodiments, it may be advantageous to pressure test (e.g., within the recess \n61\n or \n66\n) before the cladding \n74\n is tightened or drawn around the cladded sensors wire \n58\n.', 'Such certain advantages may include a more efficient method to pressure test the structure and maintain coupling between the components of the structure, and reducing any void spaces. \nFIG.', '28\n is a schematic diagram of a manufacturing line \n77\nc \nthat may be utilized to generate the cladded sensor wires \n58\n, such as the cladded sensor wires discussed herein, in accordance with an embodiment of the present disclosure.', 'In general, the optical fibers \n54\n are placed inside the recess \n66\n of the grooved conductor \n56\n followed by providing a cladding \n74\n around the grooved conductor \n56\n that includes the one or more optical fibers \n54\n.', 'It should be appreciated that the manufacturing line \n77\nc \nmay be used for any number of optical fibers \n54\n.', 'At station \n78\na, \noptical fiber(s) \n54\n, the grooved conductor \n56\n, and the cladding \n74\n are provided in respective pay-offs \n80\na, \n80\nb, \nand \n80\nc \nrespectively.', 'Additionally, station \n78\na \nof the manufacturing line \n77\nc \nincludes a payoff \n80\nd \nthat includes the plug \n110\n.', 'In some embodiments, the pay-off \n80\na \nincludes multiple optical fibers \n54\n, or three pay-offs \n80\na \nare provided that each include an optical fiber \n54\n.', 'The grooved conductor \n56\n (e.g., a wire-like structure that is shaped to have the grooved conductor \n56\n cross section) is guided through the manufacturing line \n77\nc \nto the station \n82\nb \nwhich includes straighteners \n84\n, rollers \n88\n, and tension sensors \n86\n to maintain groove orientation, shaped conductor form, and alignment for a subsequent positioning of the cladding \n74\n.', 'The plug \n110\n is guided to a station \n82\na \nwhich includes straighteners \n84\n, rollers \n88\n, and tension sensors \n86\n.', 'At station \n90\na, \nthe optical fibers \n54\n are inserted into the recess \n66\n of the grooved conductor \n56\n.', 'Additionally, the plug \n110\n is inserted into the recess \n66\n (e.g., into end portion \n112\n or portion \n116\n) of the grooved conductor \n56\n.', 'It should be appreciated that the type of alignment rollers is dependent on the shape of the grooved conductor \n56\n, the plug \n110\n, and/or number of optical fibers \n54\n.', 'At station \n92\n, the cladding \n74\n is positioned around the conductors (e.g., that were positioned around the grooved conductor \n56\n and the plug \n110\n in station \n120\n), thus producing the cladded sensor wire \n58\n.', 'It should be appreciated that any suitable machines may be used for providing (e.g., positioning, forming) the cladding \n74\n around the grooved conductor \n56\n that includes the optical fiber(s) \n54\n, such as insertion rollers.', 'At station \n94\n, the ends \n73\n and \n75\n of the cladding \n74\n are welded together to produce a welded connection \n76\n.', 'Then, at station \n96\na, \nthe cladding \n74\n with the welded connection \n76\n are drawn partially through a die to leave a gap (e.g., suitable first distance \n106\n as shown in \nFIG.', '8\n) between the grooved conductor \n56\n (e.g., along the outer surface \n68\n of the grooved conductor \n56\n) and the cladding \n74\n.', 'Then, at station \n98\na, \nthe welded connection \n76\n may be inspected by suitable methods (e.g., eddy current, laser diameter), before the cladding is loaded onto a pay-off (e.g., at station \n102\na\n) that includes a cladded sensor wire \n58\n that is partially drawn.', 'In some embodiments, a pressure test may occur at or after station \n96\na.', 'For example, it may be advantageous to perform a pressure test, and if the measured pressure is within a threshold, either stop or continue with the additional steps of the manufacturing line \n77\nc, \nor at an inspection line \n128\n, described below.', 'FIG.', '29\n shows an inspection line \n128\n for the partially drawn cladded sensor wire \n58\n from manufacturing line \n77\nc.', 'The process begins with providing (e.g., with guided rollers) the partially drawn cladded sensor wire \n58\n to the station \n96\nb \nwhere the gap (e.g., distance \n106\n from \nFIG.', '8\n) is drawn to form a tight fit (e.g., distance \n108\n from \nFIG.', '8\n).', 'Then, the full drawn cladded sensor wire \n58\n is inspected at station \n96\nc \nto ensure the weld surface is free of pinholes.', 'Finally, the cladded sensor wire \n58\n is provided by the station \n100\nb \n(e.g., a capstan unit) to the take up unit at station \n102\n.', 'As such, the present disclosure is directed to a cladded sensor wire \n58\n.', 'The cladded sensor wire \n58\n includes one or more optical fibers \n54\n that are surrounded by a grooved conductor \n56\n.', 'The grooved conductor \n56\n may include various forms as described, for example, in \nFIGS.', '8\n-\n13\n.', 'The grooved conductor \n56\n is surrounded by a cladding \n74\n which improves reduces the effect of the harsh downhole conditions on the optical fibers \n54\n and/or grooved conductor The present techniques eliminate the risk of gas through the optical fibers, reduce the optical strain of the fibers to maximize the safe working load of the cable and increase coupling of the optical fibers and the other components of the cable for better optical measurements signal to noise ratio, the power delivery of the cable, the telemetry performance..', 'Another embodiment of the present disclosure relates to the manufacturing of the cladded sensor wire \n58\n.', 'In one embodiment, the components of the sensor cladded wire that are interior to the cladding are coated with silicone to reduce the likelihood of gas leaks.', 'In another embodiment, the sensor cladded wire includes a plug that may provide structural support for and improved mechanical durability of the optical fibers.', 'The specific embodiments described above have been shown by way of example, and it should be understood that these embodiments may be susceptible to various modifications and alternative forms.', 'It should be further understood that the claims are not intended to be limited to the particular forms disclosed, but rather to cover all modifications, equivalents, and alternatives falling within the spirit and scope of this disclosure.']

['1.', 'An electrical-optical device, comprising: wherein the at least two optical fibers are fixed in the position within the recess; and\nat least two optical fibers;\na grooved conductor that includes a recess that extends radially outward from a central portion of the grooved conductor to an end portion of the recess, wherein the at least two optical fibers are positioned within the recess, wherein one of the at least two optical fibers is adjacent the central portion of the grooved conductor and the other optical fiber is disposed between the optical fiber adjacent the central portion of the grooved conductor and the end portion of the recess;\na cladding disposed around the grooved conductor and over the end portion of the recess forming a tube, wherein the at least two optical fibers are maintained inside the recess of the grooved conductor, wherein the cladding includes a welded connection along a first end and a second end of the cladding, and wherein the cladding provides increased resistance to mechanical stress and reduced likelihood of gas intrusion to the at least two optical fibers and gas leakage to the electrical-optical device.', '2.', 'The electrical-optical device of claim 1, wherein the welded connection is radially offset from the end portion of the recess.', '3.', 'The electrical-optical device of claim 1, further comprising a plug that resides within the end portion of the recess to improve a collapse and shear resistance of the electrical-optical device.', '4.', 'The electrical-optical device of claim 3, wherein the grooved conductor and the plug are surrounded by a plurality of stranded wire.', '5.', 'The electrical-optical device of claim 1, further comprising a filler material that fills a portion of the recess that does not include the at least two optical fibers.', '6.', 'The electrical-optical device of claim 1, further comprising an additional grooved conductor that is coupled to the grooved conductor along an interface.', '7.', 'The electrical-optical device of claim 6, wherein the additional grooved conductor includes a second recess, wherein an inner surface of the additional grooved conductor partially surrounds the at least two optical fibers.', '8.', 'The electrical-optical device of claim 1, wherein the grooved conductor is a continuous, single unit composed of a conducting material.', '9.', 'The electrical-optical device of claim 8, wherein the conducting material is copper.', '10.', 'A method of manufacturing an electrical-optical cable for a downhole device, comprising:\nproviding a grooved conductor and at least two optical fibers, wherein the grooved conductor includes a recess that extends radially outward from a central portion of the grooved conductor to an end portion of the recess;\ncoupling at least one optical fiber of the at least two optical fibers to the grooved conductor by positioning the at least two optical fibers into the recess, wherein one of the at least two optical fibers is adjacent the central portion of the grooved conductor and the other optical fiber is disposed between the optical fiber adjacent the central portion of the grooved conductor and the end portion of the recess, wherein the at least two optical fibers are fixed in the position within the recess;\nsurrounding an outer surface of the grooved conductor with a cladding; and\nconnecting a first end of the cladding to a second end of the cladding and forming a seal along the connection.', '11.', 'The method of manufacturing of claim 10, wherein positioning a plug into an end portion of the recess of the grooved conductor after the at least two optical fibers are positioned within the recess of the grooved conductor.', '12.', 'The method of manufacturing of claim 10, wherein the seal formed along the connection of the first end and the second end of the cladding is radially offset from the recess.', '13.', 'The method of manufacturing of claim 10, further comprising positioning a plug into an end portion of the recess of the grooved conductor after coupling the at least two optical fibers.', '14.', 'The method of manufacturing of claim 13, further comprising surrounding the outer surface of the grooved conductor and the plug with a plurality of stranded wire.', '15.', 'The method of manufacturing of claim 10, wherein surrounding the outer surface of the grooved conductor with the cladding comprises forming a round tube of cladding around the grooved conductor.', '16.', 'The method of manufacturing of claim 15, further comprising creating a tight fit between the cladding and grooved conductor after forming a round tube of cladding around the grooved conductor.', '17.', 'The method of manufacturing of claim 10, further comprising filling one or more voids between the grooved conductor and the at least two optical fibers after coupling the at least two optical fibers to the grooved conductor.', '18.', 'A method of manufacturing an electrical-optical cable for a downhole device, comprising:\nproviding a grooved conductor and at least two optical fibers, wherein the grooved conductor includes a recess that extends radially outward from a central portion of the grooved conductor to an end portion of the recess, and wherein a cross section of the grooved conductor is not entirely circular;\ncoupling the at least two optical fibers to the grooved conductor by positioning the at least two optical fibers into the recess wherein one of the at least two optical fibers is adjacent the central portion of the grooved conductor and the other optical fiber is disposed between the optical fiber adjacent the central portion of the grooved conductor and the end portion of the recess, wherein the at least two optical fibers are fixed in the position within the recess;\nproviding a filler material to fill a portion within the recess that is not occupied by the at least two optical fibers;\nsurrounding an outer surface of the grooved conductor with a cladding;\nconnecting a first end of the cladding to a second end of the cladding and forming a seal along the connection.', '19.', 'The method of manufacturing of claim 18, further comprising partially drawing down the cladding around the grooved conductor;\nmeasuring a pressure within one or more void spaces between the cladding and the grooved conductor; and\nfurther drawing down the cladding around the grooved conductor when the pressure is within a threshold range.', '20.', 'The method of manufacturing of claim 18, further comprising filling one or more voids between the grooved conductor and the at least two optical fibers after coupling the at least two optical fibers to the grooved conductor.']

['FIG.', '1 is a schematic diagram of a well-logging system that employs a logging winch system, in accordance with an embodiment of the present disclosure;; FIG.', '2A is a schematic diagram of a cross section of a cable, in accordance with an embodiment of the present disclosure;; FIG.', '2B is a schematic diagram of a cross section of a sensor portion of a cable, in accordance with an embodiment of the present disclosure;; FIG.', '2C is a schematic diagram of a cross section of another cable, in accordance with an embodiment of the present disclosure;; FIG.', '2D is a schematic diagram of a cross section of another cable, in accordance with an embodiment of the present disclosure;; FIG.', '3 is a schematic diagram of a cross section of a sensor portion of a cable, in accordance with an embodiment of the present disclosure;; FIG.', '4 is a schematic diagram of a manufacturing line for a cladded sensor wire, in accordance with an embodiment of the present disclosure;; FIG.', '5 is an illustration of a cross section of the components of a cladded sensor wire from an instant in time in the manufacturing line of FIG.', '4, in accordance with an embodiment of the present disclosure;; FIG.', '6 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '4, in accordance with an embodiment of the present disclosure;; FIG. 7 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '4, in accordance with an embodiment of the present disclosure;; FIG. 8 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '4, in accordance with an embodiment of the present disclosure;; FIG. 9 is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of FIG. 4, in accordance with an embodiment of the present disclosure;; FIG.', '10 is an illustration of an example of a cladded sensor wire, in accordance with an embodiment of the present disclosure;; FIG.', '11 is an illustration of an example of a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure;; FIG.', '12 is an illustration of another example of a cladded sensor wire with examples of plugs and caps, in accordance with an embodiment of the present disclosure;; FIG.', '13 is an illustration of an example of a cladded sensor wire with a wedge-shaped plug, in accordance with an embodiment of the present disclosure;; FIG.', '14 is a schematic diagram of a manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure;; FIG.', '15 is an illustration of a cross section of the components of a cladded sensor wire from an instant in time in the manufacturing line of FIG.', '14, in accordance with an embodiment of the present disclosure;; FIG.', '16 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '14, in accordance with an embodiment of the present disclosure;; FIG.', '17 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '14, in accordance with an embodiment of the present disclosure;; FIG.', '18 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '14, in accordance with an embodiment of the present disclosure;; FIG.', '19 is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of FIG.', '14, in accordance with an embodiment of the present disclosure;; FIG.', '20 is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of FIG.', '14, in accordance with an embodiment of the present disclosure;; FIG.', '21 is a schematic diagram of another manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure;; FIG.', '22 is an illustration of a cross section of the components of a cladded sensor wire from an instant in time in the manufacturing line of FIG.', '21, in accordance with an embodiment of the present disclosure;', '; FIG.', '23 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '21, in accordance with an embodiment of the present disclosure;; FIG.', '24 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '21, in accordance with an embodiment of the present disclosure;; FIG.', '25 is an illustration of a cross section of a partially assembled cladded sensor wire from another instant in time in the manufacturing line of FIG.', '21, in accordance with an embodiment of the present disclosure;; FIG.', '26 is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of FIG.', '21, in accordance with an embodiment of the present disclosure;; FIG.', '27 is an illustration of a cross section of a cladded sensor wire from an instant in time in the manufacturing line of FIG.', '21, in accordance with an embodiment of the present disclosure;; FIG.', '28 is a schematic diagram of another manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure; and; FIG.', '29 is a schematic diagram of another manufacturing line for a cladded sensor wire with a plug, in accordance with an embodiment of the present disclosure.', '; FIG.', '2A is a cross sectional view of one embodiment of the cable 18.', 'The cable 18 may be continuous or sectioned, and may be 1 meter (m), 10 m, 100 m, 1000 m or more meters in length.', 'The cable 18 may house a cable core 40, which may be circumferentially surrounded by one or more armor wire strength members 42.', 'The armor wire strength members 42 may be served (e.g., coiled helically) around the cable core 40, extend longitudinally along the length of the cable core 40, or be disposed about the cable core 40 in any fashion suitable to surround the cable core 40.', 'The armor wire strength members 42 may physically protect the cable core 40 and may provide additionally rigidity to the cable 18.', 'In addition, the armor wire strength members 42 may support the weight of the cable 18 and alleviate strain on the cable core 40.', 'In other embodiments, the cable 18 may be fully jacketed by means of reinforced jacket over the armor wire strength members 42.; FIG.', '2B is a cross sectional view of a marine cable 55.', 'The marine cable 55 may include the cable core 40.', 'The cable core 40 may include the one or more signal cables 44.', 'The signal cables 44 may include the internal wires 46 disposed within the protective structures 48.', 'The internal wires 46 may include the sensors (e.g., the one or more optical fibers 54), copper wires 50, or any other suitable wires desired within the cable 18.', 'The internal wires 46 may also include the optical-fiber-containing sensor wires 52.', 'The internal wires 46 may transmit instructional signals or electrical power to a component coupled to the end of the marine cable 55 (e.g., the downhole tool 12).', 'The protective structures 48 may encase the internal wires 46 and physically protect the internal wires during operation of the cable 18.', 'To achieve a better signal to noise ratio with regard to the parameters being monitored (e.g., temperature, pressure, seismic profiling, or others), the optical-fiber-containing sensor wires 52 may be located near the outside perimeter of the marine cable 55.', 'The optical-fiber-containing sensor wires 52 may be disposed within a shielding layer 57 of the marine cable 55.', 'The shielding layer 57 may additionally be encased by a protective outer layer 59.', 'It should be appreciated by one of ordinary skill in the art that the optical-fiber-containing sensor wires 52, or those with cladding (e.g., cladded sensors wires 58), as discussed further below, may be used for the cables above as well as various other suitable types of cables.', 'For example, FIG.', '2C and FIG.', '2D illustrates a hepta cable 51 and coax jacket cables 55a, 55b, respectively, that include cladded sensor wires 58.; FIG.', '3 illustrates a cross-sectional view of an embodiment of a cladded sensor wire 58 (e.g., cladded one-piece optical-fiber-containing sensor wire 52 or electrical-optical cable).', 'To facilitate discussion, the various embodiments of the cladded sensor wire 58 may be described with reference to an ‘x’ direction 60, a ‘y’ direction 62, and a ‘z’ direction 64.', 'The cladded sensor wire 58 includes a grooved conductor 56 disposed about the one or more optical fibers 54.', 'The grooved conductor 56 may include a conductor (e.g., copper) or any alloy suitable for the desired purpose.', 'The one or more optical fibers 54 may be disposed within a recess 66 of the grooved conductor 56.', 'The one or more optical fibers 54 may be embedded symmetrically, or asymmetrically within the recess 66.', 'The recess 66 may extend radially from the center of the grooved conductor 56 to an outer surface 68 of the grooved conductor 56.', 'Although FIG. 3 shows an embodiment of the grooved conductor 56 with a generally circular or C-shape, the grooved conductor 56 may take any suitable shape, such as square, triangular, or oval.; FIG.', '4 is a schematic diagram of a manufacturing line 77 that may be utilized to generate the cladded sensor wire 58, as shown in FIG.', '3, in accordance with an embodiment of the present disclosure.', 'In general, the optical fibers 54 are placed inside the recess 66 of the grooved conductor 56 followed by providing a cladding 74 around the grooved conductor 56 that includes the one or more optical fibers 54.', 'It should be appreciated that the manufacturing line 77 may be used for any number of optical fibers 54.; FIGS.', '5-9 show several points in time of the optical fibers 54, the grooved conductor 56, cladding 74, and cladded sensor wire 58 during the stations 78, 90, 92, 94, and 96 of the manufacturing line 77, as described for FIG.', '4.', 'For example, FIG.', '5 is an illustration of a cross section of the optical fibers 54, a cross section of the grooved conductor 56, and a cross section of the cladding 74, which are in respective pay-offs 80a, 80b, and 80c, in station 78.', 'FIG.', '6 shows three optical fibers 54 positioned in the recess 66 of the grooved conductor 56, representing a point in time of station 90 of the manufacturing line 77.', 'FIG. 7 (left) shows the cladding 74 positioned around the grooved conductor 56 that includes the optical fibers 54, representing a point in time of station 92 of the manufacturing line 77.', 'The arrows 104 illustrated the cladding 74 disposed radially about the grooved conductor 56.', 'FIG.', '7 (right) shows the cladding 74 positioned around the grooved conductor 56, representing a second point in time of station 92 of the manufacturing line #.', 'FIG.', '8 shows the cladding 74 connected along the ends 75 and 73 with a welded connection 76, representing a point in time of station 94 of the manufacturing line 77.', 'As illustrated, the outer surface 68 of the grooved conductor 56 and the inner surface 105 of the cladding 74 are separated by a first distance 106.', 'FIG.', '9 shows the cladding 74 connected along the ends 73 and 75 with a welded connection 76, representing a point in time of station 96 of the manufacturing line 77.', 'As illustrated, the outer surface 68 of the grooved conductor 56 and the inner surface 105 of the cladding 74 are separated by a second distance 108 that is smaller than the first distance 106.', 'This is indicative of the tight fit created in station 96.; FIGS.', '10-13 show several embodiments of the cladded sensor wire 58.', 'FIG.', '10 shows a cladded sensor wire 58a that includes two grooved conductors 56a and 56b.', 'Each grooved conductor 56a and 56b partially surround the optical fibers 54.', 'As illustrated, the grooved conductors 56a and 56b each are generally a semi-circle and each grooved conductor may include a respective recess 66 where the optical fiber 54 reside.', 'In some embodiments, each grooved conductor 56a and 56b generally form different fractions of a circle (10%, 25%, 50%, and 75%).', 'For example, grooved conductor 56a may form a quarter circle and grooved conductor 56b may form three-quarters of a circle.; FIGS.', '11-13 shows different examples of cross sections of cladded sensor wires 58 that include plugs/caps 110.', 'FIG.', '11 shows a cross section of a cladded sensor wire 58b that includes a grooved conductor 56 and plug 110.', 'In some embodiments, a plug 110 may be inserted into the first end portion 112 of the recess 66, forming an enclosed recess 113 within the grooved conductor 56.', 'The plug 110 may be pressure fit into the grooved conductor 56 and/or bonded to the grooved conductor via an adhesive (e.g., welding, bonding glue).', 'The plug 110 may extend longitudinally (e.g., ‘z’ direction 64) along the length of the grooved conductor 56 and form a hermetic seal between the one or more optical fibers 54 within the enclosed recess 113 and an external environment 80.', 'The external environment 80 may contain fluids that can damage a coating of the one or more optical fibers 54 and result in optical losses within the one or more optical fibers 54.', 'For example, the ingress of hydrogen into the enclosed recess 113 may result in a subsequent formation of hydroxide ions (OH—) that may absorb light at a number of important wavelengths, thereby decreasing the signal strength of the one or more optical fibers 54.; FIG.', '14 is a schematic diagram of a manufacturing line 77a that may be utilized to generate the cladded sensor wires 58, such as the cladded sensor wires shown in FIGS.', '10-13, in accordance with an embodiment of the present disclosure.', 'The disclosed techniques provide a process for simultaneous process of assembling for the cladded sensor wire 58, which provides several advantages (e.g., improved power, reduced strain) as discussed herein.', 'In general, the optical fibers 54 are placed inside the recess 66 of the grooved conductor 56 followed by providing a cladding 74 around the grooved conductor 56 that includes the one or more optical fibers 54.', 'It should be appreciated that the manufacturing line 77a may be used for any number of optical fibers 54.; FIGS.', '15-20 show several points in time of the optical fibers 54, the grooved conductor 56, cladding 74, and cladded sensor wire 58 during the stations 78a, 90a, 120, 92, 94, and 96 of the manufacturing line 77a, as described for FIG.', '14.', 'For example, FIG.', '15 is an illustration of a cross section of the optical fibers 54, a cross section of the grooved conductor 56, a cross section of the cladding 74, and a cross section of the plug 110, which are in respective pay-offs 80a, 80b, 80c, and 80d, in station 78a.', 'FIG.', '16 shows three optical fibers 54 positioned in the recess 66 of the grooved conductor 56 and the plug 110 positioned in the end portion 112, representing a point in time of station 90a of the manufacturing line 77a.', 'FIG.', '17 shows the cured silicone 122 that fills different voids in the grooved conductor 56 representing in time of station 120.', 'FIG.', '18 (top) shows the cladding 74 positioned around the grooved conductor 56 that includes the optical fibers 54 and the cured silicone 122, representing a point in time of station 92 of the manufacturing line 77a.', 'The arrows 104 illustrated the cladding 74 disposed radially about the grooved conductor 56.', 'FIG.', '18 (bottom) shows the cladding 74 positioned around the grooved conductor 56, representing a second point in time of station 92 of the manufacturing line 77a.', 'FIG.', '19 shows the cladding 74 connected along the ends 75 and 73 with a welded connection 76, representing a point in time of station 94 of the manufacturing line 77a.', 'As illustrated, the outer surface 68 of the grooved conductor 56 and the inner surface 105 of the cladding 74 are separated by a first distance 106.', 'FIG.', '20 shows the cladding 74 connected along the ends 73 and 75 of the cladding 74 with a welded connection 76, representing a point in time of station 96 of the manufacturing line 77a.', 'As illustrated, the outer surface 68 of the grooved conductor 56 and the inner surface 105 of the cladding 74 are separated by a second distance 108 that is smaller than the first distance 106.', 'This is indicative of the tight fit created in station 96.; FIG.', '21 is a schematic diagram of a manufacturing line 77b that may be utilized to generate the cladded sensor wires 58 surrounded with conductors (e.g., 126 shown in FIGS.', '24-27), and the inner cladded sensor wires 58 may be any of the cladded sensor wires 58 shown in FIGS.', '10-15, in accordance with an embodiment of the present disclosure.', 'In general, the optical fibers 54 are placed inside the recess 66 of the grooved conductor 56 followed by providing a cladding 74 around the grooved conductor 56 that includes the one or more optical fibers 54.', 'It should be appreciated that the manufacturing line 77b may be used for any number of optical fibers 54.; FIGS.', '22-27 show several points in time of the optical fibers 54, the grooved conductor 56, cladding 74, and cladded sensor wire 58 during the stations 78a, 90a, 124, 92b, 94, and 96 of the manufacturing line 77b, as described herein.', 'For example, FIG.', '22 is an illustration of a cross section of the optical fibers 54, a cross section of the grooved conductor 56, a cross section of the cladding 74, and a cross section of the plug 110, which are in respective pay-offs 80a, 80b, 80c, and 80d, in station 78a.', 'FIG.', '23 shows three optical fibers 54 positioned in the recess 66 of the grooved conductor 56 and the plug 110 positioned in the end portion 112, representing a point in time of station 90a of the manufacturing line 77a.', 'FIG.', '24 shows conductors 126 positioned on the outer surface 68 of the grooved conductor 56, representing a point in time of the station 124 of the manufacturing line 77b.', 'FIG.', '25 (left) shows the cladding 74 positioned around the conductors 126 that surround the grooved conductor 56 and the plug 110, representing a point in time of station 92b of the manufacturing line 77b.', 'The arrows 104 illustrate positioning of the cladding 74 disposed radially about the conductors 126.', 'FIG.', '25 (right) shows the cladding 74 positioned around the grooved conductor 56, representing a second point in time of station 92 of the manufacturing line 77b.', 'FIG.', '26 shows the cladding 74 connected along the ends 75 and 73 with a welded connection 76, representing a point in time of station 94 of the manufacturing line 77b.', 'As illustrated, the outer surface 127 of each conductor 126 and the inner surface 105 of the cladding 74 are separated by a first distance 106a.', 'FIG.', '27 shows the cladding 74 connected along the ends 73 and 75 of the cladding 74 with a welded connection 76, representing a point in time of station 96 of the manufacturing line 77b.', 'As illustrated, the outer surface 127 of each conductor 126 and the inner surface 105 of the cladding 74 are separated by a second distance 108a that is smaller than the first distance 106a.', 'This is indicative of the tight fit created in station 96.; FIG.', '29 shows an inspection line 128 for the partially drawn cladded sensor wire 58 from manufacturing line 77c.', 'The process begins with providing (e.g., with guided rollers) the partially drawn cladded sensor wire 58 to the station 96b where the gap (e.g., distance 106 from FIG.', '8) is drawn to form a tight fit (e.g., distance 108 from FIG.', '8).', 'Then, the full drawn cladded sensor wire 58 is inspected at station 96c to ensure the weld surface is free of pinholes.', 'Finally, the cladded sensor wire 58 is provided by the station 100b (e.g., a capstan unit) to the take up unit at station 102.']

US11916507

Motor angular position control

Mar 3, 2020

Jian Wu, Ramakrishna Madhireddy, Nathaniel Wicks

SCHLUMBERGER TECHNOLOGY CORPORATION

NPL References not found.

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['A motor controller to control rotational speed of an output shaft of an electric motor.', 'The motor controller includes a proportional controller and a time-optimal controller.', 'The proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and a switching point, inclusively.', 'The time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point.', 'Also introduced herein are aspects pertaining to determining the switching point in a manner that minimizes overshooting the target rotational position while maximizing expediency at which the target rotational position is reached.']

['Description\n\n\n\n\n\n\nBACKGROUND OF THE DISCLOSURE\n \nSome motor position control applications mandate that overshooting of target angular positions be kept to a minimum, if not entirely prevented.', 'For example, when a top drive is utilized to rotate a drill string to steer toolface, operations may mandate that the target angular position is reached exactly with no overshoot.', 'In another example, when a top drive is utilized to oscillate a drill string between specified angular position targets, operations may mandate that the targets are not overshot, so that the toolface is not unintentionally changed.', 'In these examples (among others within the scope of the present disclosure), operational procedures may include an intended accuracy of the stop positions of the motor shaft, such that the stop position error falls within specified, generally small, position dead bands.', 'However, operational efficiency and other factors are affected by the expediency and smoothness at which the target angular positions are reached.', 'Moreover, the above aspects may also be affected by system-specified limits on motor acceleration, deceleration, and/or velocity.', 'SUMMARY OF THE DISCLOSURE', 'This summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify indispensable features of the claimed subject matter, nor is it intended for use as an aid in limiting the scope of the claimed subject matter.', 'The present disclosure introduces a method including causing operation of a motor controller operable to control rotational speed of an output shaft of an electric motor.', 'The motor controller includes a proportional controller and a time-optimal controller.', 'The proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and a switching point, inclusively.', 'The time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point.', 'The present disclosure also introduces a method including determining a switching point to be used by a motor controller that is operable to control rotational speed of an output shaft of an electric motor.', 'The motor controller includes a proportional controller and a time-optimal controller.', 'The proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and the switching point, inclusively.', 'The time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point.', 'Determining the switching point includes determining which one of N curves corresponds to a predetermined system communications delay, N being a positive integer, and each of the N curves relating a counter delay factor β to candidate switching points.', 'Determining the switching point also includes selecting the switching point based on a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one for the determined one of the N curves.', 'The present disclosure also introduces an apparatus including an electric motor that comprises an output shaft and a motor controller operable to control rotational speed of the output shaft.', 'The motor controller includes a proportional controller that controls the rotational speed when a present rotational position of the shaft is between a target rotational position and a switching point, inclusively.', 'The motor controller also includes a time-optimal controller that controls the rotational speed when the present rotational position is not between the target rotational position and the switching point.', 'The present disclosure also introduces an apparatus including a processing system that includes a processor and a memory storing code executable by the processor to determine a switching point to be used by a motor controller that is operable to control rotational speed of an output shaft of an electric motor.', 'The motor controller includes a proportional controller and a time-optimal controller.', 'The proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and the switching point, inclusively.', 'The time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point.', 'The processing system determines the switching point by determining which one of N curves corresponds to a predetermined system communications delay, N being a positive integer, and each of the N curves relating a counter delay factor β to candidate switching points, and selecting the switching point based on a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one for the determined one of the N curves.', 'These and additional aspects of the present disclosure are set forth in the description that follows, and/or may be learned by a person having ordinary skill in the art by reading the material herein and/or practicing the principles described herein.', 'At least some aspects of the present disclosure may be achieved via means recited in the attached claims.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'The present disclosure is understood from the following detailed description when read with the accompanying figures.', 'It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale.', 'In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.', 'FIG.', '1\n is a flow-chart diagram of at least a portion of an example implementation of a method according to one or more aspects of the present disclosure.', 'FIGS.', '2\n-\n5\n are graphs depicting an example simulation according to one or more aspects of the present disclosure.\n \nFIG.', '6\n is a graph depicting one or more aspects of the present disclosure.', 'FIGS.', '7\n-\n18\n are graphs depicting an example experimental results according to one or more aspects of the present disclosure.\n \nFIG.', '19\n is a schematic view of at least a portion of an example implementation of well construction apparatus according to one or more aspects of the present disclosure.\n \nFIG.', '20\n is a schematic view of at least a portion of an example implementation of processing apparatus according to one or more aspects of the present disclosure.', 'DETAILED DESCRIPTION', 'It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments.', 'Specific examples of components and arrangements are described below to simplify the present disclosure.', 'These are, of course, merely examples and are not intended to be limiting.', 'In addition, the present disclosure may repeat reference numerals and/or letters in the various examples.', 'This repetition is for simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.', 'Moreover, the description of a first feature in contact with a second feature in the description that follows may include implementations in which the first and second features are in direct contact, and may also include implementations in which additional features may interpose the first and second features, such that the first and second features may not be in direct contact.', 'The present disclosure introduces aspects pertaining to controlling the angular position of a motor output shaft in a manner that minimizes or eliminates overshooting target angular positions.', 'Such aspects may be utilized to achieve desiderated accuracies of the motor stop positions while maximizing motor speed and smoothness, yet still within system-specified limits on motor acceleration, deceleration, and/or velocity.', 'The motor control is accomplished via a switching position control scheme in which motor control is switched between a proportional (e.g., linearly proportional) controller and a time-optimal controller.', 'That is, up to a given point near the target position, the proportional controller generates decreasing velocity and/or acceleration (i.e., deceleration) commands as the target position is approached.', 'Beyond that given point, the time-optimal controller generates position-based velocity commands employing maximum system-allowed acceleration and deceleration rates.', 'Thus, the time-optimal controller permits running the motor at the maximum velocity that the system permits as long as possible before decelerating using the maximum deceleration rate.', 'Gain values for the controllers are determined using given deceleration rates and switching points/positions in such a way that velocity commands from the proportional controller and the time-optimal controller are equal at the moment control is switched between the controllers, thus permitting a smooth transition when switching between the controllers.', 'The point at which the motor control is switched from the proportional controller to the time-optimal controller is referred to herein as the switching point or switching position.', 'The switching point determines the value of the linear proportional position gain.', 'A small gain leads to a smooth motion toward the target but may cause excessive time to reach the target.', 'Moreover, the switching position control scheme introduced herein utilizes the proportional control phase to manage system delay, which can be ever-present.', 'The proportional control gain may permit a smooth and exponentially decreasing velocity profile where, near the target, the final values may be so small that the impacts of delay may be counteracted.', 'For the sake of simplicity, the angular position of the motor shaft may be referred to herein as the motor position (in units of cycles or revolutions (revs)), the angular velocity of the motor shaft may be referred to as the motor speed (ω, in units of revs per second (rps) or revs per minute (rpm)), the angular acceleration/deceleration of the motor shaft may be referred to as the motor acceleration/deceleration (a, in units of revs per second per second (rev/s\n2\n) or rpm/second), and the angular displacement of the motor shaft may be referred to as the motor displacement (Δθ, in units of cycles or revs).', 'In addition, the following description is initially presented in a context that assumes that angular positions and velocities are both positive in a forward rotating direction.', 'Reverse directions are subsequently addressed further below.', 'The motor speed at the switching point may be determined as set forth below in Equation (1).', 'ω\n0\n=κθ\n0\n\u2003\u2003(1) \n where ω\n0 \nis the motor speed at the switching point, κ is the motor position control proportional gain (in units of 1/s, where s is time in seconds), and θ\n0 \nis the motor position at the switching point that is related to the target position.', 'The motor position θ\n0 \nmay be considered a position error between the switching position and the target position.', 'For forward rotation, the motor position θ\n0 \nis a positive number.', 'For the sake of simplicity and without loss of generality in the following description, the target position is considered to be 0, and the position error θ (or θ\nn\n) may be used as position that represents the motor position or angular displacement relative to the target position at 0, whereby θ would be positive numbers and decreasing during forward rotation of the motor.', 'The displacement made by wo may be determined as set forth below in Equation (2).', 'Δθ\n1\n=κθ\n0\nt\ns\n\u2003\u2003(2) \n where Δθ\n1 \nis the motor displacement at a first time and t\ns \nis the time interval of the time period elapsed at the first time.', 'The new motor position θ\n1 \nmay then be determined as set forth below in Equation (3).', 'θ\n1\n=θ\n0\n−Δθ\n1\n=θ\n0\n(1−κ\nt\ns\n)\u2003\u2003(3)', 'As described above, prior to the switching point, the same deceleration rate for position control α\nd \n(a negative value) would apply.', 'Therefore, the speed ω\n1 \nat the first time after the switching point may be determined in two ways, as set forth below in Equations (4) and (5).', 'ω\n1\n=ω\n0\n+α\nd\nt\ns\n=κθ\n0\n+α\nd\nt\ns\n\u2003\u2003(4) \n ω\n1\n=κθ\n1\n=κθ\n0\n−κ\n2\nθ\n0\nt\ns\n\u2003\u2003(5) \n \nEquations (4) and (5) may then be utilized to obtain Equations (6) and (7) set forth below.', 'a\n \nd\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n=\n \n \n \n-\n \n \nκ\n \n2\n \n \n \n\u2062\n \n \nθ\n \n0\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n \n \n \n \n(\n \n6\n \n)', 'κ\n \n=\n \n \n \n \n-\n \n \nα\n \nd\n \n \n \n \nθ\n \n0\n \n \n \n \n \n \n \n \n(\n \n7\n \n)', 'The motor speed at the switching point may then be determined by combining Equations (1) and (7), as set forth below in Equation (8).', 'ω\n0\n=κθ\n0\n=√{square root over (−α\nd\nθ\n0\n)}\u2003\u2003(8) \n \nFor the speed generated in the time-optimal control phase, the motion leads to decelerating to ω\n0 \nat θ\n0 \nfor a given θ\n0 \nand α\nd\n.', 'For example, regarding a constantly decelerating rotation, starting at ω\ni \nand finishing at ω\nf \nand going through an angular displacement of Δθ, the motion may be described as set forth below in Equations (9) and (10).', 'ω\n \nf\n \n \n=\n \n \n \nω\n \ni\n \n \n+\n \n \n \nα\n \nd\n \n \n\u2062\n \nt\n \n \n \n \n \n \n \n(\n \n9\n \n)\n \n \n \n \n \n \n \n \n \n \n \n \n \nΔθ\n \n=\n \n \n \n \nω\n \ni\n \n \n\u2062\n \nt\n \n \n+\n \n \n \n1\n \n2\n \n \n\u2062\n \n \nα\n \nd\n \n \n\u2062\n \n \nt\n \n2\n \n \n \n \n \n \n \n \n(\n \n10\n \n)\n \n \n \n \n \n \n \n \nEquation (9) can be rearranged as set forth below in Equation (11).', 't\n \n=\n \n \n \n \nω\n \nf\n \n \n-\n \n \nω\n \ni\n \n \n \n \nα\n \nd\n \n \n \n \n \n \n \n(\n \n11\n \n)\n \n \n \n \n \n \n \n \nEquation (12) set forth below can then be obtained based on Equations (10) and (11).', 'ω\nf\n2\n=ω\ni\n2\n+2α\nd\nΔθ\u2003\u2003(12)', 'This motion takes place prior to the switching point.', 'Thus, if given the current position (error) at θ and the switching point at θ\n0\n, then Δθ may be as set forth below in Equation (13).', 'Δθ=θ−θ\n0\n\u2003\u2003(13) \n \nAccordingly, taking ω\n0 \nas ω\nf \nand combining Equations (8), (12) and (13), the speed to at the current position θ may be determined as set forth below in Equation (14).', 'ω=√{square root over (|−α\nd\nθ\n0\n−2α\nd\n(θ−θ\n0\n))}\u2003\u2003(14)', 'The velocity command can be generalized for rotation in both directions.', 'When position error (position) is positive, the motor rotates in the forward direction, and when negative, the motor rotates in the reverse direction.', 'Thus, Equation (14) can be generalized as set forth below in Equation (15).', 'ω\n \n=\n \n \n \nθ\n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \nθ\n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n\u2062\n \n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \n \nα\n \nd\n \n \n\u2062\n \n \nθ\n \n0\n \n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n+\n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \n2\n \n\u2062\n \n \n \nα\n \nd\n \n \n(\n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \nθ\n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n-\n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \nθ\n \n0\n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n)\n \n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n \n \n \n \n \n \n(\n \n15\n \n)\n \n \n \n \n \n \n \n Thus, speed in the proportional control phase may be as set forth below in Equation (16).', 'ω\n \n=\n \n \nθ\n \n\u2062\n \n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \nα\n \nd\n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \nθ\n \n0\n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n \n \n \n \n \n \n(\n \n16\n \n)\n \n \n \n \n \n \n \n \nIn either of the proportional and time-optimal control phases, the velocity command generated as set forth above in Equation (15) or (16) satisfies the acceleration and deceleration rate limits defined by the application and the general motor rate limits, where the acceleration and deceleration rate limits defined by the application are no larger than the general motor rate limits.', 'At the same time, the speed does not exceed the designed speed limits.', 'If the absolute value of the current position (error) is smaller than the absolute value of the given switching position, the proportional controller works alone.\n \nFIG.', '1\n is a schematic view of at least a portion of an example implementation of the switching control scheme described above.', 'A current motor position measurement \n10\n is subtracted from a target position \n14\n by a subtractor \n18\n.', 'The current motor position measurement \n10\n may be obtained from a position encoder and/or other measurement sensor disposed on or otherwise associated with the motor \n50\n being controlled.', 'The target position \n14\n may be obtained from a human-machine interface (HMI) and/or other portion of a processing system (or device) implementing the motor controller operable to control the motor \n50\n via the switching control scheme introduced herein.', 'The subtractor \n18\n may be implemented by hardware and/or software of the processing system, and the output may be referred to as the position error.', 'The absolute value \n20\n of the position error is then compared to the absolute value of the switching position \n22\n, such as by a comparator \n26\n, to determine whether the motor \n50\n will be controlled by a proportional controller \n30\n or a time-optimal controller \n34\n as described above.', 'The switching position \n22\n may be obtained from the HMI and/or determined by the processing system, such as according to one or more aspects described below.', 'The comparator \n26\n may be implemented by hardware and/or software of the processing system.', 'If the absolute value \n20\n of the position error output by the subtractor \n18\n is determined by the comparator \n26\n to be less than or equal to the switching position \n22\n, then velocity commands output by the proportional controller \n30\n control the motor \n50\n, otherwise velocity commands output by the time-optimal controller \n34\n control the motor \n50\n.', 'The switching between the proportional controller \n30\n and the time-optimal controller \n34\n is schematically depicted in \nFIG.', '1\n by a switch \n38\n.', 'The velocity commands output by the proportional controller \n30\n and the time-optimal controller \n34\n may be altered prior to being applied to the motor \n50\n.', 'For example, a speed limiter \n42\n may decrease or otherwise alter the velocity commands to ensure that the velocity commands do not exceed a maximum operating speed of the motor \n50\n, such as may be specified by the manufacturer of the motor \n50\n and/or requirements of the system comprising the motor \n50\n.', 'Similarly, a rate limiter \n46\n may alter the velocity commands to ensure that the velocity commands do not violate maximum acceleration/deceleration limits of the motor \n50\n.\n \nFIGS.', '2\n-\n5\n are graphs depicting aspects of an example simulation related to the control method shown in \nFIG.', '1\n.', 'In the example simulation, the motor initially rotates at a maximum speed (i.e., as shown in \nFIG.', '3\n, 300 rpm) and is at position of 10 revs away from a target position (i.e., as shown in \nFIG.', '4\n, position error is 10 revs).', 'The switching position (shown by the “x” symbol) \n54\n is set at 1.0 rev and the deceleration rate is −100 rpm/s or −1.667 rev/s\n2\n.', 'Before the switching position \n54\n, the speed is 300 rpm (maximum speed) until about 0.5 sec, when the velocity determined utilizing Equation (15) becomes lower than the maximum speed.', 'The speed then decreases with maximum deceleration rate.', 'Thus, it achieves the time-optimal performance.', 'After the switching point \n54\n, the speed and deceleration rate simultaneously and exponentially lower to zero at about 5.5 seconds.', 'The speed profile (\nFIG.', '3\n) shows smooth continuation during the process, and the target position (\nFIG.', '4\n) is reached without overshoot.', 'This example depicts an ideal case assuming there is no communication delay, with the speed present value (Pv) closely tracking the speed setpoint (Sp).', 'The present disclosure also introduces a systematic approach to determining the switching point position.', 'That is, dynamic control systems encounter communication delays.', 'Motor control systems are no exception, even though the delays have been significantly lowered to milli-sec levels with current advanced industrial communication device and protocols.', 'Thus, to achieve zero or minimal position error, impacts from system delay may be counteracted via aspects introduced herein.', 'For example, when the current motor position nears the target position, a zero-speed command would ideally be issued by the motor controller(s).', 'However, due to communication delay, the motor is still being commanded by a previous non-zero speed command, resulting in overshooting the target position.', 'An approach to managing this is to utilize a (larger) switching point to counter the effect of the communication delay.', 'However, an excessively large switching point slows reaching the target, thus lowering efficiency and effectiveness of the switching motor control scheme introduced herein.', 'Thus, the following description presents a systematic approach to determining a switching point that minimizes or eliminates overshot while maximizing the expediency at which the target position at zero is reached.', 'The exponential relationship between the speeds in adjacent time periods in the proportional control phase may be determined based on Equations (17)-(19) set forth below.', 'ω\n0\n=κθ\n0\n\u2003\u2003(17) \n ω\n1\n=κθ\n1\n=κ(θ\n0\n−κθ\n0\nt\ns\n)=κθ\n0\n(1−κ\nt\ns\n)', '(18) \n ω\n2\n=κθ\n2\n=κ(θ\n1\n−κθ\n1\nt\ns\n)=κ((θ\n0\n−κθ\n0\nt\ns\n)−κθ\n0\n(1−κ\nt\ns\n)\nt\ns\n)', '=κθ\n0\n(1−κ\nt\ns\n)\n2\n\u2003\u2003(19) \n \nIt can be observed from Equations (17)-(19) that a speed ω\nn \nin each of n time periods is slowed to a percentage (i.e., 1−κt\ns\n) of the speed ω\nn-1 \nin the previous time period, as expressed in Equation (20) set forth below.', 'ω\nn\n=(1−\nt\ns\n)ω\nn-1\n\u2003\u2003(20)', 'The impact of delay on κ can then be determined.', 'The delay impacts the speed at which the switching point (as derived in Equation (8) or (16)) will be reached after the prespecified switching point position.', 'Thus, the delay leads to a shorter switching position and, therefore, a larger proportional gain κ.', 'The determination of the switching point may assume that the delay is known as N (a positive integer) sampling time periods (t\ns\n), and that the speeds prior to reaching the switching speed follow the deceleration of α\nd \nwhile the actual calculated switching point Δθ* is larger than zero.', 'This leads to Equations (21) and (22) set forth below.', 'ω\n \n \n \n-\n \nN\n \n \n+\n \n1\n \n \n \n=\n \n \n \nω\n \n0\n \n \n+\n \n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \nα\n \nd\n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n\u2062\n \n \n(\n \n \nN\n \n-\n \n1\n \n \n)\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n \n \n \n \n \n(\n \n21\n \n)\n \n \n \n \n \n \n \n \n \n \n \nΔ\n \n\u2062\n \n \nθ\n \n*\n \n \n \n=\n \n \n \n1\n \n \n2\n \n\u2062\n \n \n \n❘\n \n"\\[LeftBracketingBar]"\n \n \n \nα\n \nd\n \n \n \n❘\n \n"\\[RightBracketingBar]"\n \n \n \n \n \n\u2062\n \n \n(\n \n \n \nω\n \n \n \n-\n \nN\n \n \n+\n \n1\n \n \n2\n \n \n-\n \n \nω\n \n0\n \n2\n \n \n \n)\n \n \n \n \n \n \n \nActual proportional gain κ* can then be estimated based on the same switching speed (delayed), as set forth below in Equation (23).', 'κ\n \n*\n \n \n=\n \n \n \nκ\n \n\u2062\n \n \nθ\n \n0\n \n \n \n \n \nθ\n \n0\n \n \n-\n \n \nΔθ\n \n*\n \n \n \n \n \n \n \n \n(\n \n23\n \n)\n \n \n \n \n \n \n \n \nAfter the actual proportional gain is estimated, the switching point can be systematically determined, given that the deceleration rate and system delays are known.', 'For example, at the n\nth \ntime period, the actual motor position is ε, a position error within which the speed would be set to zero.', 'Based on Equations (20) and (23), the speeds between n and n-N time periods can be established as set forth below in Equation (24).', 'ω\n \nn\n \n \n=\n \n \n \nκ\n \n*\n \n \n\u2062\n \nε\n \n \n \n,\n \n \n \nω\n \n \nn\n \n-\n \n1\n \n \n \n=\n \n \n \nω\n \nn\n \n \n \n(\n \n \n1\n \n-\n \n \n \nκ\n \n*\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n \n)\n \n \n \n \n,\n \n…\n \n \n \n,\n \n \n \nω\n \n \nn\n \n-\n \nN\n \n \n \n=\n \n \n \nω\n \nn\n \n \n \n \n(\n \n \n1\n \n-\n \n \n \nκ\n \n*\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n \n)\n \n \nN\n \n \n \n \n \n \n \n \n(\n \n24\n \n)\n \n \n \n \n \n \n \n \nTo eliminate overshoot, the sum of displacement caused by each of the speeds from Equation (24) excluding ω\nn \nis less than ε, as set forth below in Equation (25).', 'κ\n \n*\n \n \n\u2062\n \n \nε\n \n\u2061\n \n(\n \n \n \n1\n \n \n(\n \n \n1\n \n-\n \n \n \nκ\n \n*\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n \n)\n \n \n \n+\n \n \n…\n \n\u2062\n \n \n1\n \n \n \n(\n \n \n1\n \n-\n \n \n \nκ\n \n*\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n \n)\n \n \nN\n \n \n \n \n \n)\n \n \n\u2062\n \n \nt\n \ns\n \n \n \n 1, but the overshoot will be less than |ε| for the case at data point \n58\n where β<1.', 'In practice, the system communication delay may be predetermined, such as from empirical data, actual measurements, and/or other means.', 'For example, in the examples described below in relation to \nFIGS.', '7\n-\n15\n, the delay may be known to be about 160 msec, and the sampling time period t\ns \nmay be about 20 msec.', 'Thus, the curve \n62\n for N=8 (160 msec/20 msec) in \nFIG.', '6\n may be utilized to select the switching point θ\n0\n.', 'The switching point θ\n0 \nmay be selected as the smallest value of 0 for which β<1 on the N=8 curve \n62\n, or 0.813 revolutions from the target rotational position.', 'However, the resolution of rotational positioning may not be sufficiently accurate to permit such precision, such as in implementations in which the resolution may be 0.05 revolutions.', 'Accordingly, the selected switching point may be rounded up to the next resolution-permitted increment, or 0.85 revolutions in this example.', 'Moreover, the selected switching point may be enlarged by one or two (or more) additional increments, such as to 0.90 or 0.95 revolutions in this example, to provide additional margin that may account for unknown system delays and/or other factors.', 'However, excessive enlargement of the selected switching point can decrease the speed at which the target rotation position can be reached.', 'In a motor experiment conducted to confirm the above, a 0.25 horsepower (hp) alternating current (AC) motor with 1,800 rpm of base speed and 0.75 pound-feet (lb-ft) of rated torque was controlled by a dedicated programmable logic controller (PLC) and a variable-frequency drive (VFD).', 'Position measurement was obtained via a 1,024 pulses-per-revolution encoder.', 'The PLC scan time was set to 20 msec and the delay was estimated at about 160 msec.', 'The motor was limited to light loads during the testing.', 'The deceleration rate was set at −5.0 rev/s\n2 \n(or −300 rpm/s).', 'The position control resolution or dead band e was set at 0.005 revolutions.', 'The target position that is angular displacement from the initial motor shaft angular position was 20.0 revolutions.', 'FIG.', '6\n, introduced above, shows the corresponding counter delay factor curves based on different delay cycles and a deceleration rate of −5.0 rev/s\n2\n.\n \nFIG.', '7\n presents the motor speed ω', 'Sp \n202\n and Pv \n204\n, \nFIG.', '8\n presents the motor angular displacement Δθ Sp \n206\n and Pv \n208\n, and \nFIG.', '9\n presents the position error θ', 'Pv \n210\n. \nFIG.', '10\n is an enlarged view of a portion of \nFIG.', '7\n focused on the time period (4.5-6.5 seconds) when the target was approached and reached.', 'FIGS.', '7\n-\n12\n are for the case of the switching point θ\n0 \nbeing 0.75 revolutions (corresponding to data point \n62\n in \nFIG.', '6\n).', 'FIGS.', '13\n-\n18\n are similar to \nFIGS.', '7\n-\n12\n but for the case of the switching position being 1.0 revolutions (corresponding to data point \n58\n in \nFIG.', '6\n), including the motor speed ω', 'Sp \n212\n and Pv \n214\n, the motor angular displacement Δθ Sp \n216\n and Pv \n218\n, and the position error θ Pv \n220\n.', 'As shown in \nFIG. \n11\n, the motor position error θ', 'Pv \n208\n overshot the motor position θ Sp \n206\n by about 0.05 revolutions.', 'However, as shown in \nFIG.', '17\n, the motor position error θ Pv \n218\n reached the motor position θ Sp \n216\n within the desired band and no overshoot.', 'These experimental results demonstrate the motor angular position control scheme introduced herein, as well as the effectiveness of the scheme in determining the switching position.', 'In implementations utilizing an automatic speed regulator (ASR) for controlling motor speed, high control gains may aid in ensuring that the speed Pv closely tracks the speed Sp.', 'However, the motor load may be large, and often varies.', 'Accordingly, the inertial delay attributable to the motor load may be taken into account as a part of overall system delay, and the reference value where the counter delay factor is just below 1.0 can be used as the lower limit to determine the switching position.', 'Therefore, a value larger than the reference value of the switching point may be utilized.', 'FIG.', '19\n is a schematic view of at least a portion of an example implementation of a well construction system \n300\n according to one or more aspects of the present disclosure.', 'The well construction system \n300\n represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'The well construction system \n300\n may be or comprise a well construction rig (i.e., a drilling rig).', 'Although the well construction system \n300\n is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.', 'The well construction system \n300\n is depicted in relation to a wellbore \n302\n formed by rotary and/or directional drilling from a wellsite surface \n304\n and extending into a subterranean formation \n306\n.', 'The well construction system \n300\n comprises various well construction equipment (i.e., wellsite equipment), including surface equipment \n310\n located at the wellsite surface \n304\n and a drill string \n320\n suspended within the wellbore \n302\n.', 'The surface equipment \n310\n may include a mast, a derrick, and/or other support structure \n312\n disposed over a rig floor \n314\n.', 'The drill string \n320\n may be suspended within the wellbore \n302\n from the support structure \n312\n.', 'The support structure \n312\n and the rig floor \n314\n are collectively supported over the wellbore \n302\n by legs and/or other support structures (not shown).', 'The drill string \n320\n may comprise a bottom-hole assembly (BHA) \n324\n and means \n322\n for conveying the BHA \n324\n within the wellbore \n302\n.', 'The conveyance means \n322\n may comprise a plurality of interconnected tubulars, such as drill pipe, heavy-weight drill pipe (HWDP), wired drill pipe (WDP), tough logging condition (TLC) pipe, and drill collars, among other examples.', 'A downhole end of the BHA \n324\n may include or be coupled to a drill bit \n326\n.', 'Rotation of the drill bit \n326\n and the weight of the drill string \n320\n collectively operate to form the wellbore \n302\n.', 'The drill bit \n326\n may be rotated from the wellsite surface \n304\n and/or via a downhole mud motor \n384\n (i.e., drilling fluid motor) connected with the drill bit \n326\n.', 'The BHA \n324\n may also include various downhole devices and/or tools \n380\n, \n382\n.', 'The support structure \n312\n may support a driver, such as a top drive \n316\n, operable to connect (perhaps indirectly) with an upper end of the drill string \n320\n, and to impart rotary motion \n317\n and vertical motion \n335\n to the drill string \n320\n, including the drill bit \n326\n.', 'The top drive \n316\n and the connected drill string \n320\n may be suspended from the support structure \n312\n via a hoisting system or equipment, which may include a traveling block \n313\n, a crown block \n315\n, and a drawworks \n318\n storing a support cable or line \n323\n.', 'The crown block \n315\n may be connected to or otherwise supported by the support structure \n312\n, and the traveling block \n313\n may be coupled with the top drive \n316\n.', 'The drawworks \n318\n may be mounted on or otherwise supported by the rig floor \n314\n.', 'The crown block \n315\n and traveling block \n313\n comprise pulleys or sheaves around which the support line \n323\n is reeved to operatively connect the crown block \n315\n, the traveling block \n313\n, and the drawworks \n318\n.', 'The drawworks \n318\n may thus selectively impart tension to the support line \n323\n to lift and lower the top drive \n316\n, resulting in the vertical motion \n335\n.', 'The drawworks \n318\n comprises a drum \n386\n and an electric motor \n387\n operable to drive the drum \n386\n to rotate and reel in the support line \n323\n, causing the traveling block \n313\n and the top drive \n316\n to move upward.', 'The drawworks \n318\n is also operable to reel out the support line \n323\n via a controlled rotation of the drum \n386\n, causing the traveling block \n313\n and the top drive \n316\n to move downward.', 'The top drive \n316\n comprises a drive shaft \n325\n operatively connected with an electric motor \n388\n, such as via a gear box or transmission (not shown).', 'The drive shaft \n325\n may be selectively coupled with the upper end of the drill string \n320\n.', 'The electric motor \n388\n may be selectively operated to rotate the drive shaft \n325\n and, thus, the drill string \n320\n.', 'Hence, during drilling operations, the top drive \n316\n, in conjunction with operation of the drawworks \n318\n, may advance the drill string \n320\n into the formation \n306\n to form the wellbore \n302\n.', 'The drill string \n320\n may be conveyed within the wellbore \n302\n through various fluid control devices disposed at the wellsite surface \n304\n on top of the wellbore \n302\n and perhaps below the rig floor \n314\n.', 'The fluid control devices may be operable to control fluid within the wellbore \n302\n.', 'For example, the fluid control devices may include a blowout preventer (BOP) stack \n330\n for maintaining well pressure control, such as may comprise a series of pressure barriers (e.g., rams).', 'The surface equipment \n310\n of the well construction system \n300\n may also comprise a control center \n390\n from which various portions of the well construction system \n300\n, such as the top drive \n316\n and the drawworks \n318\n, among other examples, may be monitored and controlled.', 'The control center \n390\n may be located on the rig floor \n314\n or another location of the well construction system \n300\n.', 'The control center \n390\n may comprise a facility \n391\n (e.g., a room, a cabin, a trailer, etc.) containing a control workstation \n397\n, which may be operated by rig personnel \n395\n (e.g., a driller or another human rig operator) to monitor and control various well construction equipment or portions of the well construction system \n300\n.', 'The control workstation \n397\n may comprise or be communicatively connected with a central controller \n392\n (e.g., a processing device, a computer, etc.), such as may be operable to receive, process, and output information to monitor operations of and provide control to one or more portions of the well construction system \n300\n.', 'For example, the central controller \n392\n may be communicatively connected with the top drive \n316\n, the drawworks \n318\n, and/or other surface and/or downhole equipment described herein, and may be operable to receive signals from and transmit signals to such equipment to perform various operations described herein, such as to control the rotational position and speed as described above.', 'The central controller \n392\n may store executable computer program code, instructions, and/or operational parameters or setpoints, including for implementing one or more aspects of methods and operations described herein.', 'The central controller \n392\n may be located within and/or outside of the facility \n391\n.', 'The control workstation \n397\n may be operable for entering or otherwise communicating control data (e.g., commands, signals, information, etc.) to the central controller \n392\n and other equipment controller by the rig personnel \n395\n, and for displaying or otherwise communicating information from the central controller \n392\n to the rig personnel \n395\n.', 'The control workstation \n397\n may comprise a plurality of human-machine interface (HMI) devices, including one or more input devices \n394\n (e.g., a keyboard, a mouse, a joystick, a touchscreen, etc.) and one or more output devices \n396\n (e.g., a video monitor, a touchscreen, a printer, audio speakers, etc.).', 'Communication between the central controller \n392\n, the input and output devices \n394\n, \n396\n, and the various well construction equipment may be via wired and/or wireless communication means.', 'However, for clarity and ease of understanding, such communication means are not depicted, and a person having ordinary skill in the art will appreciate that such communication means are within the scope of the present disclosure.', 'Well construction systems within the scope of the present disclosure may include more or fewer components than as described above and depicted in \nFIG. \n19\n.', 'Additionally, various equipment and/or subsystems of the well construction system \n300\n shown in \nFIG.', '19\n may include more or fewer components than as described above and depicted in \nFIG. \n19\n.', 'For example, various engines, motors, hydraulics, actuators, valves, and/or other components not explicitly described herein may be included in the well construction system \n300\n, and are within the scope of the present disclosure.', 'FIG.', '20\n is a schematic view of at least a portion of an example implementation of a processing system \n400\n according to one or more aspects of the present disclosure.', 'The processing system \n400\n may execute code (for example, machine-readable instructions) to implement at least a portion of one or more of the methods and/or processes described herein.', 'The processing system \n400\n may be or comprise, for example, one or more processors, controllers, special-purpose computing devices, servers, personal computers, personal digital assistant (PDA) devices, smartphones, internet appliances, and/or other types of computing devices.', 'The entirety of the processing system \n400\n may be implemented within downhole apparatus described above.', 'One or more components or functions of the processing system \n400\n may also or instead be implemented in wellsite surface equipment, perhaps including the surface equipment \n310\n, \n390\n, \n392\n depicted in \nFIG.', '19\n and/or other surface equipment.', 'The processing system \n400\n may comprise a processor \n412\n, such as a general-purpose programmable processor, among other examples.', 'The processor \n412\n may comprise a local memory \n414\n and may execute program code \n432\n present in the local memory \n414\n and/or another memory device.', 'The processor \n412\n may execute code (for example, machine-readable instructions or programs) to implement the methods and/or processes described herein.', 'The code stored in the local memory \n414\n may include program instructions or computer program code that, when executed by an associated processor, cause a controller and/or control system implemented in surface equipment and/or a downhole tool to perform tasks as described herein.', 'The processor \n412\n may be, comprise, or be implemented by one or more processors of various types operable in the local application environment, and may include one or more general-purpose processors, special-purpose processors, microprocessors, DSPs, FPGAs, application-specific integrated circuits (ASICs), processors based on a multi-core processor architecture, and/or other processors.', 'The processor \n412\n may be in communication with a main memory \n417\n, such as via a bus \n422\n and/or other communication means.', 'The main memory \n417\n may comprise a volatile memory \n418\n and a non-volatile memory \n420\n.', 'The volatile memory \n418\n may be, comprise, or be implemented by random access memory (RAM), static RAM (SRAM), dynamic RAM (DRAM), synchronous DRAM (SDRAM), RAMBUS DRAM (RDRAM), and/or other types of RAM devices.', 'The non-volatile memory \n420\n may be, comprise, or be implemented by read-only memory, flash memory, and/or other types of memory devices.', 'One or more memory controllers (not shown) may control access to the volatile memory \n418\n and/or the non-volatile memory \n420\n.', 'The processing system \n400\n may also comprise an interface circuit \n424\n.', 'The interface circuit \n424\n may be, comprise, or be implemented by various types of standard interfaces, such as an Ethernet interface, a universal serial bus (USB), a third-generation input/output (3GIO) interface, a wireless interface, and/or a cellular interface, among other examples.', 'The interface circuit \n424\n may also comprise a graphics driver card.', 'The interface circuit \n424\n may also comprise a communication device, such as a modem or network interface card, to facilitate exchange of data with external computing devices via a network, such as via Ethernet connection, digital subscriber line (DSL), telephone line, coaxial cable, cellular telephone system, and/or satellite, among other examples.', 'One or more input devices \n426\n may be connected to the interface circuit \n424\n.', 'One or more of the input devices \n426\n may permit a user to enter data and/or commands for utilization by the processor \n412\n.', 'Each input device \n426\n may be, comprise, or be implemented by a keyboard, a mouse, a touchscreen, a trackpad, a trackball, an image/code scanner, and/or a voice recognition system, among other examples.', 'One or more output devices \n428\n may also be connected to the interface circuit \n424\n.', 'One or more of the output devices \n428\n may be, comprise, or be implemented by a display device, such as a liquid crystal display (LCD), a light-emitting diode (LED) display, and/or a cathode ray tube (CRT) display, among other examples.', 'One or more of the output devices \n428\n may also or instead be, comprise, or be implemented by a printer, a speaker, and/or other examples.', 'The processing system \n400\n may also comprise a mass storage device \n430\n for storing machine-readable instructions and data.', 'The mass storage device \n430\n may be connected to the interface circuit \n424\n, such as via the bus \n422\n.', 'The mass storage device \n430\n may be or comprise a floppy disk drive, a hard disk drive, a compact disk (CD) drive, and/or digital versatile disk (DVD) drive, among other examples.', 'The program code \n432\n may be stored in the mass storage device \n430\n, the volatile memory \n418\n, the non-volatile memory \n420\n, the local memory \n414\n, and/or on a removable storage medium \n434\n, such as a CD or DVD.', 'The mass storage device \n430\n, the volatile memory \n418\n, the non-volatile memory \n420\n, the local memory \n414\n, and/or the removable storage medium \n434\n may each be a tangible, non-transitory storage medium.', 'The modules and/or other components of the processing system \n400\n may be implemented in accordance with hardware (such as in one or more integrated circuit chips, such as an ASIC), or may be implemented as software or firmware for execution by a processor.', 'In the case of firmware or software, the implementation can be provided as a computer program product including a computer readable medium or storage structure containing computer program code (i.e., software or firmware) for execution by the processor.', 'In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces a method comprising causing operation of a motor controller operable to control rotational speed of an output shaft of an electric motor, wherein: the motor controller comprises a proportional controller and a time-optimal controller; the proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and a switching point, inclusively; and the time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point.', 'The proportional controller may control the rotational speed via linear feedback such that the rotational speed may be adjusted in proportion to differences between the target rotational position and the present rotational position.', 'The time-optimal controller may control the rotational speed based on maximum system-allowed speed and acceleration/deceleration rates.', 'The proportional and time-optimal controllers may utilize corresponding gain values that are determined based on the switching point and predetermined acceleration and/or deceleration rates.', 'The motor controller may comprise a processor and a memory storing code executable by the processor, and causing the motor controller operation may cause the processor to determine the gain values.', 'The proportional and time-optimal controllers may utilize corresponding gain values that are determined based on the switching point and predetermined acceleration and/or deceleration rates such that speed commands from the proportional and time-optimal controllers are equal when control is switched between the proportional and time-optimal controllers.', 'The switching point may be determined via operation of a processor and a memory storing code executable by the processor.', 'The processor may be a first processor, the memory may be a first memory, and the code may be first code; the motor controller may comprise a second processor and a second memory storing second code executable by the second processor, in which case the motor controller may not comprise the first processor or the first memory; and causing the motor controller operation may include inputting the switching point determined by the first processor.', 'In such implementations, among others within the scope of the present disclosure, the switching point may be predetermined prior to commencement of the method.', 'Alternatively, the motor controller may comprise the processor and memory, and causing the motor controller operation may cause the processor to determine the switching point.', 'Operation of the processor may determine the switching point in a manner that minimizes overshooting the target rotational position while maximizing expediency at which the target rotational position is reached.', 'Operation of the processor may determine the switching point in a manner that accounts for system communication delays.', 'Operation of the processor may determine the switching point by: determining which one of N curves corresponds to a predetermined system communications delay, wherein Nis a positive integer, and wherein each of the N curves relates a counter delay factor β to candidate switching points; and selecting the switching point as a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one for the determined one of the N curves.', 'Operation of the processor may determine the switching point by: determining which one of N curves corresponds to a predetermined system communications delay, wherein Nis a positive integer, and wherein each of the N curves relates a counter delay factor β to candidate switching points; determining a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one; and selecting the switching point as a rotational position that is larger than the determined smallest one of the candidate switching points.', 'The selected switching point may be a result of rounding up the determined smallest one of the candidate switching points to a multiple of a rotational positioning precision of the shaft.', 'The selected switching point may be greater than the determined smallest one of the candidate switching points by an amount that includes a margin to account for unknown factors.', 'The present disclosure also introduces a method comprising determining a switching point to be used by a motor controller that is operable to control rotational speed of an output shaft of an electric motor, wherein: (A) the motor controller comprises a proportional controller and a time-optimal controller; (B) the proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and the switching point, inclusively; (C) the time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point; and (D) determining the switching point comprises: (i) determining which one of N curves corresponds to a predetermined system communications delay, wherein N is a positive integer, and wherein each of the N curves relates a counter delay factor β to candidate switching points; and (ii) selecting the switching point based on a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one for the determined one of the N curves.', 'Selecting the switching point may comprise: determining the smallest one of the candidate switching points that results in a value of the counter delay factor being less than one; and selecting the switching point as a rotational position that is larger than the determined smallest one of the candidate switching points.', 'The selected switching point may be a result of rounding up the determined smallest one of the candidate switching points to a multiple of a rotational positioning precision of the shaft.', 'The selected switching point may be greater than the determined smallest one of the candidate switching points by an amount that includes a margin to account for unknown factors.', 'The present disclosure also introduces an apparatus comprising an electric motor that comprises an output shaft and a motor controller operable to control rotational speed of the output shaft, wherein the motor controller comprises: a proportional controller that controls the rotational speed when a present rotational position of the shaft is between a target rotational position and a switching point, inclusively; and a time-optimal controller that controls the rotational speed when the present rotational position is not between the target rotational position and the switching point.', 'The proportional controller may control the rotational speed via linear feedback such that the rotational speed is adjusted in proportion to differences between the target rotational position and the present rotational position.', 'The time-optimal controller may control the rotational speed based on maximum system-allowed speed and acceleration/deceleration rates.', 'The proportional and time-optimal controllers may utilize corresponding gain values that are determined based on the switching point and predetermined acceleration and/or deceleration rates.', 'The motor controller may comprise a processor and a memory storing code executable by the processor, and causing the motor controller operation may cause the processor to determine the gain values.', 'The proportional and time-optimal controllers may utilize corresponding gain values that are determined based on the switching point and predetermined acceleration and/or deceleration rates such that speed commands from the proportional and time-optimal controllers are equal when control is switched between the proportional and time-optimal controllers.', 'The switching point may be determined via operation of a processor and a memory storing code executable by the processor.', 'The processor may be a first processor, the memory may be a first memory, and the code may be first code; the motor controller may comprise a second processor and a second memory storing second code executable by the second processor, and the motor controller may not comprise the first processor or the first memory; and causing the motor controller operation may include inputting the switching point determined by the first processor.', 'Alternatively, the motor controller may comprise the processor and memory, and causing the motor controller operation may cause the processor to determine the switching point.', 'The present disclosure also introduces an apparatus comprising a processing system that comprises a processor and a memory storing code executable by the processor to determine a switching point to be used by a motor controller that is operable to control rotational speed of an output shaft of an electric motor, wherein: (A) the motor controller comprises a proportional controller and a time-optimal controller; (B) the proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and the switching point, inclusively; (C) the time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point; and (D) the processing system determines the switching point by: (i) determining which one of N curves corresponds to a predetermined system communications delay, wherein Nis a positive integer, and wherein each of the N curves relates a counter delay factor β to candidate switching points; and (ii) selecting the switching point based on a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one for the determined one of the N curves.', 'Selecting the switching point may comprise: determining the smallest one of the candidate switching points that results in a value of the counter delay factor being less than one; and selecting the switching point as a rotational position that is larger than the determined smallest one of the candidate switching points.', 'The selected switching point may be a result of rounding up the determined smallest one of the candidate switching points to a multiple of a rotational positioning precision of the shaft.', 'The selected switching point may be greater than the determined smallest one of the candidate switching points by an amount that includes a margin to account for unknown factors.', 'The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure.', 'A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same functions and/or achieving the same benefits of the embodiments introduced herein.', 'A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the spirit and scope of the present disclosure.', 'The Abstract at the end of this disclosure is provided to comply with 37 C.F.R. § 1.72(b) to permit the reader to quickly ascertain the nature of the technical disclosure.', 'It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.']

['1.', 'A method comprising:\ncausing operation of a motor controller operable to control rotational speed of an output shaft of an electric motor, wherein: the motor controller comprises a proportional controller and a time-optimal controller; the proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and a switching point, inclusively; and the time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point, wherein the switching point is determined via operation of a processor and a memory storing code executable by the processor, and wherein operation of the processor determines the switching point by: determining which one of N curves corresponds to a predetermined system communications delay, wherein N is a positive integer, and wherein each of the N curves relates a counter delay factor β to candidate switching points; determining a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one; and selecting the switching point as a rotational position that is larger than the determined smallest one of the candidate switching points.', '2.', 'The method of claim 1 wherein the proportional controller controls the rotational speed via linear feedback such that the rotational speed is adjusted in proportion to differences between the target rotational position and the present rotational position.', '3.', 'The method of claim 1 wherein the time-optimal controller controls the rotational speed based on maximum system-allowed speed and acceleration/deceleration rates.', '4.', 'The method of claim 1 wherein the proportional and time-optimal controllers utilize corresponding gain values that are determined based on the switching point and predetermined acceleration and/or deceleration rates.', '5.', 'The method of claim 4 wherein the motor controller comprises the processor and the memory storing code executable by the processor, and wherein causing the motor controller operation causes the processor to determine the gain values.', '6.', 'The method of claim 1 wherein the proportional and time-optimal controllers utilize corresponding gain values that are determined based on the switching point and predetermined acceleration and/or deceleration rates such that speed commands from the proportional and time-optimal controllers are equal when control is switched between the proportional and time-optimal controllers.', '7.', 'The method of claim 1 wherein:\nthe processor is a first processor, the memory is a first memory, and the code is first code;\nthe motor controller comprises a second processor and a second memory storing second code executable by the second processor;\nthe motor controller does not comprise the first processor or the first memory; and\ncausing the motor controller operation includes inputting the switching point determined by the first processor.', '8.', 'The method of claim 7 wherein the switching point is predetermined prior to commencement of the method.', '9.', 'The method of claim 1 wherein the motor controller comprises the processor and the memory, and wherein causing the motor controller operation causes the processor to determine the switching point.', '10.', 'The method of claim 1 wherein operation of the processor determines the switching point in a manner that minimizes overshooting the target rotational position while maximizing expediency at which the target rotational position is reached.', '11.', 'The method of claim 1 wherein operation of the processor determines the switching point in a manner that accounts for system communication delays.', '12.', 'The method of claim 1 wherein the selected switching point is a result of rounding up the determined smallest one of the candidate switching points to a multiple of a rotational positioning precision of the shaft.', '13.', 'The method of claim 1 wherein the selected switching point is greater than the determined smallest one of the candidate switching points by an amount that includes a margin to account for unknown factors.', '14.', 'A method comprising:\ncausing operation of a motor controller operable to control rotational speed of an output shaft of an electric motor, wherein: the motor controller comprises a proportional controller and a time-optimal controller; the proportional controller controls the rotational speed when a present rotational position of the shaft is between a target rotational position and a switching point, inclusively; and the time-optimal controller controls the rotational speed when the present rotational position is not between the target rotational position and the switching point,\nwherein the switching point is determined via operation of a processor and a memory storing code executable by the processor, and\nwherein operation of the processor determines the switching point by: determining which one of N curves corresponds to a predetermined system communications delay, wherein N is a positive integer, and wherein each of the N curves relates a counter delay factor R to candidate switching points; and selecting the switching point as a smallest one of the candidate switching points that results in a value of the counter delay factor being less than one for the determined one of the N curves.', '15.', 'The method of claim 14 wherein:\nthe processor is a first processor, the memory is a first memory, and the code is first code;\nthe motor controller comprises a second processor and a second memory storing second code executable by the second processor;\nthe motor controller does not comprise the first processor or the first memory; and\ncausing the motor controller operation includes inputting the switching point determined by the first processor.', '16.', 'The method of claim 15 wherein the switching point is predetermined prior to commencement of the method.', '17.', 'The method of claim 14 wherein the motor controller comprises the processor and the memory, and wherein causing the motor controller operation causes the processor to determine the switching point.', '18.', 'The method of claim 14 wherein operation of the processor determines the switching point in a manner that minimizes overshooting the target rotational position while maximizing expediency at which the target rotational position is reached.', '19.', 'The method of claim 14 wherein operation of the processor determines the switching point in a manner that accounts for system communication delays.', '20.', 'The method of claim 14 wherein the proportional controller controls the rotational speed via linear feedback such that the rotational speed is adjusted in proportion to differences between the target rotational position and the present rotational position.']

['FIG.', '1 is a flow-chart diagram of at least a portion of an example implementation of a method according to one or more aspects of the present disclosure.; FIGS.', '2-5 are graphs depicting an example simulation according to one or more aspects of the present disclosure.;', 'FIG. 6 is a graph depicting one or more aspects of the present disclosure.; FIGS.', '7-18 are graphs depicting an example experimental results according to one or more aspects of the present disclosure.;', 'FIG. 19 is a schematic view of at least a portion of an example implementation of well construction apparatus according to one or more aspects of the present disclosure.; FIG.', '20 is a schematic view of at least a portion of an example implementation of processing apparatus according to one or more aspects of the present disclosure.', '; FIG. 1 is a schematic view of at least a portion of an example implementation of the switching control scheme described above.', 'A current motor position measurement 10 is subtracted from a target position 14 by a subtractor 18.', 'The current motor position measurement 10 may be obtained from a position encoder and/or other measurement sensor disposed on or otherwise associated with the motor 50 being controlled.', 'The target position 14 may be obtained from a human-machine interface (HMI) and/or other portion of a processing system (or device) implementing the motor controller operable to control the motor 50 via the switching control scheme introduced herein.', 'The subtractor 18 may be implemented by hardware and/or software of the processing system, and the output may be referred to as the position error.; FIGS.', '2-5 are graphs depicting aspects of an example simulation related to the control method shown in FIG.', '1.', 'In the example simulation, the motor initially rotates at a maximum speed (i.e., as shown in FIG.', '3, 300 rpm) and is at position of 10 revs away from a target position (i.e., as shown in FIG.', '4', ', position error is 10 revs).', 'The switching position (shown by the “x” symbol) 54 is set at 1.0 rev and the deceleration rate is −100 rpm/s or −1.667 rev/s2.', 'Before the switching position 54, the speed is 300 rpm (maximum speed) until about 0.5 sec, when the velocity determined utilizing Equation (15) becomes lower than the maximum speed.', 'The speed then decreases with maximum deceleration rate.', 'Thus, it achieves the time-optimal performance.', 'After the switching point 54, the speed and deceleration rate simultaneously and exponentially lower to zero at about 5.5 seconds.', 'The speed profile (FIG. 3) shows smooth continuation during the process, and the target position (FIG. 4) is reached without overshoot.', 'This example depicts an ideal case assuming there is no communication delay, with the speed present value (Pv) closely tracking the speed setpoint (Sp).; FIG.', '7 presents the motor speed ω', 'Sp 202 and Pv 204, FIG.', '8 presents the motor angular displacement Δθ Sp 206 and Pv 208, and FIG.', '9 presents the position error θ', 'Pv 210. FIG.', '10 is an enlarged view of a portion of FIG.', '7 focused on the time period (4.5-6.5 seconds) when the target was approached and reached.', 'FIGS.', '7-12 are for the case of the switching point θ0 being 0.75 revolutions (corresponding to data point 62 in FIG.', '6).', 'FIGS.', '13-18 are similar to FIGS.', '7-12 but for the case of the switching position being 1.0 revolutions (corresponding to data point 58 in FIG. 6), including the motor speed ω', 'Sp 212 and Pv 214, the motor angular displacement Δθ Sp 216 and Pv 218, and the position error θ', 'Pv 220.', 'As shown in FIG.', '11, the motor position error θ', 'Pv 208 overshot the motor position θ', 'Sp 206 by about 0.05 revolutions.', 'However, as shown in FIG.', '17, the motor position error θ', 'Pv 218 reached the motor position θ Sp 216 within the desired band and no overshoot.', 'These experimental results demonstrate the motor angular position control scheme introduced herein, as well as the effectiveness of the scheme in determining the switching position.; FIG.', '19 is a schematic view of at least a portion of an example implementation of a well construction system 300 according to one or more aspects of the present disclosure.', 'The well construction system 300 represents an example environment in which one or more aspects of the present disclosure described below may be implemented.', 'The well construction system 300 may be or comprise a well construction rig (i.e., a drilling rig).', 'Although the well construction system 300 is depicted as an onshore implementation, the aspects described below are also applicable to offshore implementations.; FIG.', '20 is a schematic view of at least a portion of an example implementation of a processing system 400 according to one or more aspects of the present disclosure.', 'The processing system 400 may execute code (for example, machine-readable instructions) to implement at least a portion of one or more of the methods and/or processes described herein.', 'The processing system 400 may be or comprise, for example, one or more processors, controllers, special-purpose computing devices, servers, personal computers, personal digital assistant (PDA) devices, smartphones, internet appliances, and/or other types of computing devices.', 'The entirety of the processing system 400 may be implemented within downhole apparatus described above.', 'One or more components or functions of the processing system 400 may also or instead be implemented in wellsite surface equipment, perhaps including the surface equipment 310, 390, 392 depicted in FIG.', '19 and/or other surface equipment.']

US11796710

Determination of formation water salinity using downhole low frequency electromagnetic measurements and permittivity dispersions based thereon

Jul 28, 2020

Ping Zhang, Shouxiang Ma, Wael Abdallah, Chengbing Liu

No Companies Listed

Clinch, S. et al., “Determining Formation Water Salinity in the Hydrocarbon Leg using Cores and Logs”, Petrophysics, 2011, 52(2), pp. 108-123.; Ma, S. M. et al., “Resolving the Mixed Salinity Challenges with a Methodology Developed from Pulsed Neutron Capture Gamma Ray Spectral Measurements”, SPE 170608, 2014 SPE Annual Technical Conference and Exhibition, Amsterdam, The Netherlands, 12 pages.; Seleznev, N., et al., Coherent interpretation of wideband electromagnetic measurements in the millihertz to gigahertz frequency range, SPWLA 58th Annual Logging Symposium, Jun. 17-21, 2017, 23 pages.; Seleznev, N. et al., “Coherent Interpretation of Wideband Electromagnetic measurements in th emillihertz to Gigahertz Frequency Range”, Petrophysics, 2018, 59(3), pp. 334-353.; Tian, L. et al., “A neutron-Induced Gamma-Ray Spectroscopy Logging Method for Determining Formation Water Salinity”, SPWLA 60th Annual Logging Symposium, The Woodlands, TX, USA, 2019, 11 pages.

7501829; March 10, 2009; Davydychev et al.; 10208582; February 19, 2019; Ma et al.; 10247849; April 2, 2019; Pfutzner et al.; 20180120468; May 3, 2018; Seleznev; 20200245044; July 30, 2020; Menssen

Foreign Citations not found.

['Methods and systems are provided for characterizing formation water salinity of subsurface formation using multifrequency permittivity data over a range of frequencies below 1 MHz.', 'The multifrequency permittivity data is processed to determine salinity of formation water contained in the subsurface formation.', 'Other useful formation properties (such as formation water saturation) can be determined based on the formation water salinity.']

['Description\n\n\n\n\n\n\nFIELD\n \nThe present disclosure relates to methods and systems that can determine formation water salinity and other useful formation properties (such as formation water saturation) based on the formation water salinity.', 'BACKGROUND\n \nIn oilfield applications, geological knowledge of subsurface formation rock is useful for resources exploration, field development and production planning.', 'In shaly sand formations, the influence of clays contained in the formation rock can be determined by excess conductivity contribution.', 'Quantifying shales has typically been limited to correlations with logs such as gamma ray (GR), sonic, or differences in the neutron and density logs.', 'These correlations are based on fundamentally different physics than the controls on conductivity.', 'This limits their applicability to the specific field where they are developed.', 'There has been considerable interest in applying dielectric measurements to determine oil saturation in shaly sands.', 'Such oil saturation can be used to assess reservoir quality and the amount of hydrocarbons in-place in shaly sands.', 'Formation conductivity and permittivity depend on formation water salinity as well as other formation properties such as water saturation, types and/or volumes of clay minerals and porosity.', 'Having an in-depth understanding of these parameters is necessary to interpret dielectric measurements to determine oil saturation in shaly sands.', 'Different methods have been used to measure salinity of the formation water found within formation rock.', 'In one example, downhole fluid sampling methods can be used to obtain a sample of formation water.', 'The sample can be analyzed by laboratory methods to measure the salinity of the formation water sample.', 'The downhole fluid sampling requires that the formation water be mobile, i.e., in the transition zone or water leg.', 'In another example, it has been suggested that downhole NMR measurements can be used to understand changes to formation water salinity.', 'See, for example, Clinch, S.; Shafer, S.; Wei, W.; Lasswell, P., “Determining Formation Water Salinity in the Hydrocarbon Leg using Cores and Logs,” PETROPHYSICS, 52(2), 108-123, 2011.', 'In yet another example, pulsed neutron gamma spectral methods can be used to measure the salinity of formation water.', 'See, for example, i) Ma., S. M.; Pfutzner, H.; AL-Hajiri, A. A.; et al., “Resolving the mixed salinity challenges with a methodology developed from pulsed neutron capture gamma ray spectral measurements”, SPE 170608, Annual Technical Conference and Exhibition Society of Petroleum Engineers, 2014; ii) Ma, S. M., et al., “Formation water salinity from borehole measurements,” U.S. Pat.', 'No. 10,208,582, 19 Feb. 2019; iii) Pfutzner, H., et al., “Method for measuring formation water salinity from within a borehole,” U.S. Pat.', 'No. 10,247,849, 2 Apr. 2019; and iv) Tian, L.; Zhang, F.; Zhang, Q.; Chen, Q; Wang, X.; Qui, F. “A neutron-induced Gamma-Ray Spectroscopy Logging Method for Determining Formation Water Salinity,” SPWLA 60th Annual Logging Symposium, The Woodlands, Tex., USA, Jun. 15-19, 2019.', 'In still another example, higher frequency (20 MHz to 1 GHz) dielectric data can be obtained and processed to measure the salinity of formation water.', 'See, for example, Seleznev, N., Hou, C., Freed, D., Habashy, T., Feng, L. Fellah, K. and Xu, G., “Coherent interpretation of wideband electromagnetic measurements in the millihertz to gigahertz frequency range,” SPWLA 58th Annual Logging Symposium, 2017.', 'This method is not accurate if formation water salinity is low and high.', 'Furthermore, if the measurement of the higher frequency (20 MHz to 1 GHz) dielectric data is shallow, it may not be representative of formation water salinity.', 'All of these methods can also be time consuming and costly.', 'SUMMARY\n \nThis summary is provided to introduce a selection of concepts that are further described below in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'In accordance with the subject disclosure, methods and systems are provided for measuring multifrequency permittivity data of a subsurface formation from downhole electromagnetic measurements at multiple frequencies below 1 MHz.', 'The multifrequency permittivity data is processed to estimate salinity of the formation water of the subsurface formation.', 'Other useful formation properties (such as formation water saturation) can be determined based on the estimate of salinity of the formation water.', 'The downhole low frequency electromagnetic measurements are nondestructive, and the results indicate that the methods and systems are highly sensitive to the existence of clays.', 'In embodiments, the methods and systems can process the multifrequency permittivity data by calculating derivatives of the multifrequency permittivity data and using such derivatives to determine a slope representing change in permittivity relative to change in frequency.', 'The slope can be used as an input to a first calibration equation that relates the slope to a calibration parameter.', 'A value for the calibration parameter can be determined by solving the first calibration equation given the slope as input.', 'The value of the calibration parameter can be used as input to a second calibration equation that relates the calibration parameter to salinity of the formation water of the subsurface formation.', 'A value for the salinity of the formation water can be determined by solving the second calibration equation given the calibration parameter as input.', 'In embodiments, the multifrequency permittivity data and the underlying downhole electromagnetic measurements can involve a set of frequencies less than 1 MHz.', 'In embodiments, the set of frequencies less than 1 MHz can possibly include frequencies between 1 MHz and 1 KHz and/or frequencies between 1 KHz and 100 Hz and/or frequencies between 100 Hz and 10 Hz.', 'In embodiments, the first calibration equation relates the slope and at least one additional parameter to the calibration parameter.', 'For example, the at least one additional parameter can represent clay volume and possibly frequency.', 'In embodiments, the first calibration equation can have the form\n \n \n \n \n \n \n \nV\n \nclay\n \n \n=\n \n \na\n \n\u2062\n \n \n \nd\n \n\u2062\n \nɛ\n \n \ndf\n \n \n\u2062\n \n \nf\n \nb\n \n \n \n \n,\n \n \n \n \n where V\nclay \nis clay volume, \n \n \n \n \n \n \nd\n \n\u2062\n \nɛ\n \n \ndf\n \n \n \n \n is the slope representing change in permittivity relative to change in frequency, f is frequency, and a and b are calibration parameters, where a is the calibration parameter determined by solving the first calibration equation.', 'In embodiments, the second calibration equation can have the form Sal=C\n1\n×a\n2\n+C\n2\n×a+C\n3\n, where C\n1\n, C\n2 \nand C\n3 \nare calibration constants, a is the calibration parameter determined by solving the first calibration equation and input to the second calibration equation, and Sal is a value of formation water salinity determined by solving the second calibration equation.', 'In embodiments, the second calibration equation can be selected from a set of calibration equations corresponding to different formation temperatures, where the selection is based on measured formation temperature of the subsurface formation.', 'In embodiments, either one or both of the first and second calibration equations can be selected from calibration equations corresponding to different clay volume and type, where the selection is based on a determination of clay volume and type of the subsurface formation.', 'In embodiments, the clay volume can include single clay types such as kaolinite, smectite, illite, chlorite, and possibly combinations thereof.', 'In embodiment, the measurement of the multifrequency permittivity data and the processing of such data can be performed by a processor.', 'The operations of the method or system or parts thereof can also be controlled by a processor.', 'BRIEF DESCRIPTION OF THE DRAWINGS\n \nThe subject disclosure is further described in the detailed description which follows, in reference to the noted plurality of drawings by way of non-limiting examples of the subject disclosure, in which like reference numerals represent similar parts throughout the several views of the drawings, and wherein:\n \nFIGS.', '1\nA, \n1\nB and \n1\nC\n depict plots of relative permittivity computed as a function of frequency (in Hz) for a shaly sand formation rock containing 10% illite under different water volumes (including 4%, 20% and 36%) and different formation water salinities of 30 ppk (\nFIG.', '1\nA\n), 60 ppk (\nFIG.', '1\nB\n) and 150 ppk (\nFIG.', '1\nC\n);\n \nFIGS.', '2\nA, \n2\nB and \n2\nC\n depict plots of relative permittivity computed as a function of frequency (in Hz) for a shaly sand formation rock containing different clay volumes (including 1%, 5%, 10%, 20% and 30%) with a water volume of 24% and different formation water salinities of 30 ppk (\nFIG.', '2\nA\n), 60 ppk (\nFIG.', '2\nB\n) and 150 ppk (\nFIG.', '2\nC\n).', 'FIGS.', '2\nA, \n2\nB and \n2\nC\n also include horizontal dashed lines depicting relative permittivity computed as a function of frequency (in Hz) for a clay-free shaly sand formation rock (0% clay) with a water volume of 24% and different formation water salinities of 30 ppk (\nFIG.', '2\nA\n), 60 ppk (\nFIG.', '2\nB\n) and 150 ppk (\nFIG.', '2\nC\n);\n \nFIGS.', '3\nA, \n3\nB and \n3\nC\n depict plots of the derivatives of the relative permittivity as a function of frequency (in Hz) of \nFIGS.', '2\nA, \n2\nB and \n2\nC\n for the shaly sand formation rock containing different clay volumes (including 1%, 5%, 10%, 20% and 30%) with a water volume of 24% and different formation water salinities of 30 ppk (\nFIG.', '3\nA\n), 60 ppk (\nFIG.', '3\nB\n) and 150 ppk (\nFIG.', '3\nC\n);\n \nFIG.', '4\n depicts correlation curves between the calibration parameter a of the calibration equation (1) as described herein to formation water salinity (in ppk) for four different formation temperatures of 100° F., 200° F., 300° F., and 400° F.;\n \nFIG.', '5\n is a flowchart illustrating a methodology for measuring multifrequency permittivity data of a subsurface formation from downhole electromagnetic measurements.', 'The multifrequency permittivity data is processed to estimate salinity of the formation water of the subsurface formation.', 'Other useful formation properties (such as formation water saturation) can be determined based on the estimate of salinity of the formation water; and\n \nFIG.', '6\n is a block diagram of a computer processing system, which can be used to embody parts of the methodology for quantification of formation water salinity and other useful formation properties based thereon.', 'DETAILED DESCRIPTION', 'The particulars shown herein are by way of example and for purposes of illustrative discussion of the embodiments of the subject disclosure only and are presented in the cause of providing what is believed to be the most useful and readily understood description of the principles and conceptual aspects of the subject disclosure.', 'In this regard, no attempt is made to show structural details in more detail than is necessary for the fundamental understanding of the subject disclosure, the description taken with the drawings making apparent to those skilled in the art how the several forms of the subject disclosure may be embodied in practice.', 'Furthermore, like reference numbers and designations in the various drawings indicate like elements.', 'Hydrocarbon-bearing subsurface formation rock such as shaly sands can contain different types of clays and different amounts of such clay types.', 'Each clay type has its own different characteristics, which can be translated to what is called cation exchange capacity (CEC) in common petrophysical applications.', 'Clays are hydrous aluminum silicate minerals that are platy in structure and can form by the alteration of silicate minerals like feldspar and amphibole.', 'Clays are commonly lumped or grouped into a number of clay types, including but not limited to smectite, kaolinite, chlorite, illite.', 'Some clays have a tendency to swell when exposed to water, creating a potential drilling hazard when clay-bearing formation rock is exposed to water-based fluids during drilling, possibly reducing the permeability of the reservoir rock.', 'Clays can also reduce the permeability of reservoir rock when clay-bearing formation rock is exposed to water-based stimulation fluids.', 'The structural differences amongst the clay types (smectite, kaolinite, chlorite, illite) can determine the surface area exposed to reservoir fluids or drilling fluids or stimulating fluids.', 'Clays can be found in pore spaces, as part of the matrix or as grain-cementing material.', 'Authigenic clays, which grow in the pores from minerals in the connate water, can be pore-filling or pore-lining.', 'These clays have considerable surface area exposed in the pore and can be reactive, while detrital clays that are part of the matrix are usually less reactive.', 'Additionally, clays can be cementing, or grain-binding, materials that react with water or acid to disaggregate the formation if they are not protected by quartz overgrowths.', 'The most common clays that create clay problems in hydrocarbon reservoirs are kaolinite, smectite, illite and chlorite.', 'Interfacial polarization can be observed in formation rock containing clays (such as shaly sands) and in other porous media containing clays.', 'When the surface of a nonconductive mineral, such as clay minerals and silica grains, are exposed to electrolytes, it acquires charges due to ionic adsorption, protonation/deprotonation of the hydroxyl groups, and dissociation of other potentially active surface groups.', 'In the presence of an external electromagnetic (EM) field, these surface charges form electric dipoles and cause interfacial polarization (IP) effects.', 'The strength of the IP effects is regulated by permittivity of the formation rock or other porous media.', 'At lower frequencies (below 1 MHz), the permittivity of porous media shows strong dispersions due to existence of clays, and such dispersions mostly depend on formation water salinity and clay volumes.', 'The present disclosure provides a methodology or framework that uses low frequency (below 1 MHz) downhole electromagnetic measurements of a subsurface formation to determine multifrequency permittivity (referred to herein as a “permittivity dispersion”) of the subsurface formation over a range of low frequencies (below 1 MHz).', 'The permittivity dispersion of the subsurface formation is processed to determine or quantify salinity of formation water contained in the subsurface formation.', 'Other useful formation properties (such as formation water saturation) can be determined based on the formation water salinity.', 'In a shaly sands environment, formation permittivity depends mainly on the following parameters: formation water volume (which is dependent on formation porosity and water saturation); formation water salinity; clay types and clay volumes for the formation rock; and grain size and shapes for the formation rock.', 'A mathematic model can be used to calculate formation permittivity based on the above listed parameters.', 'The model calculates formation complex conductivity by analyzing the EM response of a representative volume comprising a single, isolated electrically conductive inclusion (such as clay grains) surrounded by the host material (such as water).', 'The effective medium theory was applied to formulate the model.', 'The outputs of the mathematical model include formation conductivity and formation permittivity, which are parts of the complex formation conductivity (σ) given as: \n σ=σ\nR\n+iωε\n0\nε\nr\n\u2003\u2003Eqn.', '(1) \n where σ\nR \nis the in-phase component of the complex formation conductivity; and ωε\n0\nε\nr \nis the quadrature component of the complex formation conductivity with w representing frequency, ε\n0 \nrepresenting permittivity of vacuum (8.854×10\n−12\n) and ε\nr \nrepresenting relative permittivity.', 'For a porous media containing clay minerals, ε\nr \ndepends on water volume, water salinity, clay volumes and grain size and shape.', 'Both σ\nR \nand ε\nr \ncan be calculated from the mathematical model.', 'FIGS.', '1\nA, \n1\nB and \n1\nC\n show calculations of relative permittivity ε\nr \nas a function of frequency ω (in Hz) for a shaly sand matrix under different water volumes of 4%, 20% and 36%.', 'The shaly sand matrix of the three examples includes 90% sandstone and 10% illite assuming spherical grains.', 'Three different water salinities are used in the calculations.', 'Specifically, the calculations of \nFIG.', '1\nA\n employ a water salinity of 30 parts per thousand (ppk), the calculations of \nFIG.', '1\nB\n employ a water salinity of 60 parts per thousand (ppk), and the calculations of \nFIG.', '1\nC\n employ a water salinity of 150 parts per thousand (ppk).', 'Based on the plots, the characteristics of the relative permittivity ε\nr \nas a function of frequency ω (in Hz) can be summarized as follows: strong dispersions in relative permittivity below 10 kHz; the dispersions in relative permittivity do not depend on water volume; the relative permittivity decreases with the increased water salinity; and above 100 kHz, there is no dispersion and the relative permittivity depends on water volume.', 'Clearly, the permittivity dispersions at the low frequency range do not depend on water volume.', 'On the other hand, the same permittivity dispersion curves strongly depend on clay volume, as depicted in \nFIGS.', '2\nA, \n2\nB and \n2\nC\n.', 'Specifically, the curves of \nFIGS.', '2\nA, \n2\nB and \n2\nC\n show relative permittivity ε\nr \nas a function of frequency ω (in Hz) for different clay volumes of 1%, 5%, 10%, 20%, and 30% respectively.', 'For comparison, the relative permittivity ε\nr \nas a function of frequency ω (in Hz) for clean sandstone (0% clay volume) is also plotted as a horizontal dashed line in \nFIGS.', '2\nA, \n2\nB and \n2\nC\n.', 'The permittivity dispersion curves of \nFIGS.', '2\nA, \n2\nB and \n2\nC\n are derived from variations in water salinity of 30 parts per thousand (ppk), 60 parts per thousand (ppk) and 150 parts per thousand (ppk), respectively, which is similar to the curves of \nFIGS.', '1\nA, \n1\nB and \n1\nC\n.', 'Furthermore, all of the permittivity dispersion curves of \nFIGS. \n2\nA, \n2\nB and \n2\nC\n are derived from a water volume (product of water saturation and porosity) of 24%.', 'It can be observed that while the clean sandstone has no dispersion, the shaly sands show strong dispersion effects.', 'Even with 1% clay volume', ', the dispersion curve shows a large difference from the clean sands, indicating that it is very sensitive to clay volume.', 'In addition, the amplitude of the dispersion depends on water salinity.', 'The higher the water salinity, the lower the amplitude of dispersion.', 'The permittivity dispersion curves from the different clay volumes have different slopes, which can be used for quantifying clay volumes.', 'FIGS.', '3\nA, \n3\nB and \n3\nC\n show the derivatives of relative permittivity ε\nr \nas a function of frequency for the corresponding curves in \nFIGS.', '2\nA, \n2\nB and \n2\nC\n.', 'As expected, each clay volume has a unique, but different derivative.', 'Carefully examining all the derivative curves of \nFIGS. \n3\nA, \n3\nB and \n3\nC\n, an empirical formula can be defined as:\n \n \n \n \n \n \n \n \n \n \nV\n \nclay\n \n \n=\n \n \na\n \n\u2062\n \n \n \nd\n \n\u2062\n \nɛ\n \n \ndf\n \n \n\u2062\n \n \nf\n \nb\n \n \n \n \n,\n \n \n \n \n \nEqn\n \n.', '\u2062\n \n \n(\n \n2\n \n)\n \n \n \n \n \n \n \n \n where V\nclay \nis clay volume, \n \n \n \n \n \n \nd\n \n\u2062\n \nɛ\n \n \ndf\n \n \n \n \n is the slope of the curve representing change in relative permittivity ε\nr \nas a function of change in frequency, f is frequency, and a and b are calibration parameters.', 'Formation pressure and formation temperature are two additional factors that can be considered when calculating relative permittivity and its derivative.', 'Through simulations it was determined that formation pressure has little effect on relative permittivity and can be eliminated from further considerations.', 'Formation temperature, however, can impact water conductivity, charge density at the surface of clay grains and, therefore, affect relative permittivity and its derivatives.', 'The temperature effects can be simulated and corrected as will be demonstrated below.', 'Based on model simulations, it was found that the calibration parameter b of Eqn.', '(2) can be defined as a constant value (preferably 2.45).', 'Furthermore, the calibration parameter a of Eqn.', '(2) can be defined by a correlation with formation water salinity for a known temperature as depicted in \nFIG.', '4\n.', 'The non-linear dependence between the calibration parameter a and formation water salinity allows for calculation of formation water salinity (Sal) from the knowledge of the value of the calibration parameter a of Eqn.', '(2) according to the following: \n \nSal=C\n1\n×a\n2\n+C\n2\n×a+C\n3\n\u2003\u2003Eqn.', '(3) \n where C\n1\n, C\n2 \nand C\n3 \nare calibration constants.', 'In embodiments, the formation water salinity (Sal) can be expressed in a dimensionless unit such as parts per kilo or thousand (ppk), parts per million (ppm), fractional percentage, or another suitable unit.', 'The formation water salinity (Sal) represents the relative amount of salt dissolved in the formation water.', 'In embodiments, the calibration parameter a of Eqn.', '(2) can be dependent on both clay type and clay volume.', 'Thus, in application, knowledge of clay type and clay volume from other logs or other historical data can be used in Eqn.', '(2) to determine the calibration parameter a, which is then used as part of Eqn.', '(3) to determine salinity of the formation water.', 'As an application, multifrequency permittivity data of a subsurface formation can be measured from downhole electromagnetic measurements at frequencies below 1 MHz of the formation of the interest.', 'Derivatives can be calculated from the measured multifrequency permittivity data.', 'Clay type and clay volume V\nclay \ncan be determined from analysis of rock cores, drill cuttings and/or logs (such as element spectroscope surveys).', 'The calibration parameter b can be assumed to be a constant for the clay volume and type.', 'Derivatives can be calculated from the measured multifrequency permittivity data and used to determine the slope\n \n \n \n \n \n \n \nd\n \n\u2062\n \nɛ\n \n \ndf\n \n \n.', 'Eqn.', '(2) can be used to solve for the calibration parameter a.', 'Then, with temperature of subsurface formation determined by logging or other measurements, the appropriate calibration of Eqn.', '(3) corresponding to the formation temperature and clay volume and type can be used to calculate a value of salinity (Sal) of formation water for the subsurface formation.', 'The following observations can be based on \nFIGS.', '1\nA-\n1\nC, \n2\nA-\n2\nC, \n3\nA-\n3\nC and \n4\n: \n \n \n \n(a) the permittivity dispersion curves for shaly sands at low frequencies below 1 MHz do not depend on water volume.', 'This makes the permittivity dispersion curve an ideal clay detector for all saturation conditions, pay zones or otherwise;\n \n(b) the permittivity dispersion curves for shaly sands strongly depend on clay type and volume.', 'Even with 1% clay volume', ', the permittivity dispersion curves show a huge difference from the one with clean sand;\n \n(c) the derivatives of the dispersion curves have a well-defined correlation with clay type and clay volume.', 'The correlation can be modeled by an empirical formula shown in Eqn.', '(2);\n \n(d) there are two calibration parameters a and b.', 'In embodiments, the calibration parameter b can be a constant value (e.g. 2.45) while the calibration parameter a has a well-defined correlation with water salinity; and\n \n(e) formation water salinity can be estimated based on calculation of the calibration parameter a and formation temperature using Eqn.', '(3).', 'To use the permittivity measurements for practical applications, the permittivity dispersion data of the subsurface formation can be measured from downhole electromagnetic measurements at multiple frequencies below 1 MHz.', 'The derivatives of the permittivity dispersion data can be used to estimate salinity of the formation water.', 'Other useful formation properties (such as formation water saturation) can be determined based on the estimate of salinity of the formation water.', 'FIG.', '5\n depicts a workflow that uses downhole electromagnetic measurements at frequencies below 1 MHz of a subsurface formation of interest to determine multifrequency permittivity data (or permittivity dispersion data) for the formation of interest over a range of low frequencies (below 1 MHz).', 'The multifrequency permittivity data of the subsurface formation of interest is processed to determine or quantify salinity of formation water contained in the subsurface formation of interest.', 'Other useful formation properties (such as formation water saturation) can be determined based on the formation water salinity.', 'In block \n501\n, porosity measurements of the formation of interest are obtained.', 'In embodiments, the porosity measurements can be performed by one or more downhole tools (such as a gamma-ray density tool, neutron density tool, or NMR tool) that are located in a desired depth location in a borehole that traverses the formation of interest and/or possibly by laboratory analysis of one or more core samples collected from the formation of interest.', 'In block \n503\n, multifrequency electromagnetic measurements of the formation of interest are obtained.', 'In embodiments, the electromagnetic measurements can be performed by a downhole EM logging tool (which can part of a wireline logging tool, a logging-while-drilling logging tool, a measurement-while-drilling logging tool, or a tripping-while-drilling logging tool).', 'The electromagnetic measurements can be dispersed at low frequencies (below 1 MHz).', 'In block \n503\n, the downhole EM logging tool can be located in a desired depth location in a borehole that traverses the formation of interest and operated to measure complex conductivity data representing conductivity of the formation of interest at the multiple low frequencies less than 1 MHz.', 'In embodiments, the multiple low frequencies less than 1 MHz can possibly include frequencies between 1 MHz and 1 KHz and/or frequencies between 1 KHz and 100 Hz and/or frequencies between 100 Hz and 10 Hz.', 'For each one of the multiple low frequencies of the experiment, the frequency of the applied time varying external electromagnetic field produced by the transmitter antenna of the downhole EM logging tool can be controlled to correspond to the particular low frequency, and the electromagnetic response of the formation of interest can be measured by the downhole EM logging tool for that particular low frequency.', 'In block \n505\n, rock core sample(s) or cuttings of other log measurements are obtained for the formation of interest.', 'In block \n507\n, the rock core(s) or cuttings or other log measurements of \n505\n are analyzed to determine clay type and clay volume for the formation of interest.', 'In block \n509\n, temperature measurements are obtained to determine formation temperature for the formation of interest.', 'In embodiments, the temperature measurements can involve measuring borehole temperature or the temperature of core samples or fluid samples collected from the formation of interest.', 'In block \n511\n, rock electrical properties are obtained for the formation of interest.', 'In embodiments, formation resistivity is obtained using electromagnetic tool such as array induction tool (AIT) of Schlumberger.', 'In block \n513\n, operations perform an inversion of the electromagnetic measurements of block \n503\n for each frequency within a set of frequencies below 1 MHz to derive relative permittivity of the formation of interest at the multiple frequencies.', 'For example, an induction logging tool as set forth in U.S. Pat.', 'No. 7,501,829 can be used to obtain the multifrequency electromagnetic measurements of block \n503\n.', 'By recording and processing the receiver voltage signal sensed by the receiver coils of the induction logging tool for each frequency within the set of frequencies below 1 MHz, measurements of complex conductivity of the formation of interest can be obtained for three different radial depths (shallow/medium, deep) into the formation for each one of the multiple frequencies.', 'The relative permittivity of the formation of interest at the respective depth locations (shallow, medium, deeper) and corresponding frequency can be extracted from the quadrature component of the complex conductivity measurements obtained by the induction logging tool.', 'In block \n515\n, operations compute derivatives of the relative permittivity of the formation of interest as a function of frequency at the multiple frequencies as derived in block \n513\n.', 'In block \n517\n, operations use the derivatives of the relative permittivity of the formation of interest as a function of frequency as computed in block \n515\n to solve for the calibration parameter a of Eqn.', '(2).', 'In embodiments, the clay volume as determined in block \n505\n and the calibration parameter b (which is assumed to be a constant) are used as inputs to Eqn.', '(2).', 'Furthermore, the derivatives calculated from the measured multifrequency permittivity data can also be used to determine a slope\n \n \n \n \n \n \nd\n \n\u2062\n \nɛ\n \n \ndf\n \n \n \n \n for input to Eqn.', '(2).', 'In block \n519\n, operations use the parameter a solved for in block \n517\n and the formation temperature of block \n509\n to determine formation water salinity (Sal) of the formation of interest.', 'In embodiments, with temperature of formation of interest determined in block \n509\n, the appropriate calibration equation of the form of Eqn.', '(3) corresponding to the formation temperature can be used to calculate a value of salinity (Sal) of formation water for the formation of interest.', 'In embodiments, the parameter a solved for in block \n517\n can be used as input to the appropriate calibration equation of the form of Eqn.', '(3) that corresponds to the formation temperature.', 'Data representing the formation water salinity (Sal) of the formation of interest can be stored in electronic memory or output therefrom as needed (such as block \n521\n).', 'In block \n521\n, operations use the formation water salinity of block \n519\n and the formation temperature of block \n509\n to determine formation water resistivity of the formation of interest.', 'This can be accomplished using published charts such as The Schlumberger log interpretation chartbook.', 'Data representing the formation water resistivity of the formation of interest can be stored in electronic memory or output therefrom as needed (such as block \n525\n).', 'In block \n523\n, operations use the multifrequency electromagnetic measurements of block \n503\n to derive formation resistivity of the formation of interest.', 'This can be accomplished using a multifrequency dielectric scanner, such as the array dielectric tool (ADT), of Schlumberger.', 'Data representing the formation resistivity of the formation of interest can be stored in electronic memory or output therefrom as needed (such as block \n525\n).', 'In block \n525\n, operations use the formation water resistivity of block \n521\n and the formation resistivity of block \n523\n and the rock electrical properties of block \n511\n and the formation porosity measurements of block \n501\n to determine water saturation of the formation of interest.', 'Such operations can use the well-known Archie equation or the modified Archie equation such as Dual-water or Waxman-Smith models, which calculates oil saturation and water saturation based on the total formation porosity.', 'Data representing the formation water saturation of the formation of interest can be stored in electronic memory or output therefrom as needed.', 'In embodiments, the operations of the workflow of \nFIG.', '5\n can be performed over different depth intervals within a borehole that traverses the subsurface formation of interest in order to determine or quantify salinity of formation water over the depth intervals of the formation of interest.', 'Other useful formation properties (such as formation water saturation) water over the depth intervals of the formation of interest can be determined based on the formation water salinity over the depth intervals of the formation of interest.', 'FIG.', '6\n illustrates an example device \n2500\n, with a processor \n2502\n and memory \n2504\n that can be configured to implement various embodiments of the methods and workflows as discussed in this disclosure.', 'Memory \n2504\n can also host one or more databases and can include one or more forms of volatile data storage media such as random-access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).', 'Device \n2500\n is one example of a computing device or programmable device and is not intended to suggest any limitation as to scope of use or functionality of device \n2500\n and/or its possible architectures.', 'For example, device \n2500\n can comprise one or more computing devices, programmable logic controllers (PLCs), etc.', 'Further, device \n2500\n should not be interpreted as having any dependency relating to one or a combination of components illustrated in device \n2500\n.', 'For example, device \n2500\n may include one or more of computers, such as a laptop computer, a desktop computer, a mainframe computer, etc., or any combination or accumulation thereof.', 'Device \n2500\n can also include a bus \n2508\n configured to allow various components and devices, such as processors \n2502\n, memory \n2504\n, and local data storage \n2510\n, among other components, to communicate with each other.', 'Bus \n2508\n can include one or more of any of several types of bus structures, including a memory bus or memory controller, a peripheral bus, an accelerated graphics port, and a processor or local bus using any of a variety of bus architectures.', 'Bus \n2508\n can also include wired and/or wireless buses.', 'Local data storage \n2510\n can include fixed media (e.g., RAM, ROM, a fixed hard drive, etc.) as well as removable media (e.g., a flash memory drive, a removable hard drive, optical disks, magnetic disks, and so forth).', 'One or more input/output (I/O) device(s) \n2512\n may also communicate via a user interface (UI) controller \n2514\n, which may connect with I/O device(s) \n2512\n either directly or through bus \n2508\n.', 'In one possible implementation, a network interface \n2516\n may communicate outside of device \n2500\n via a connected network.', 'A media drive/interface \n2518\n can accept removable tangible media \n2520\n, such as flash drives, optical disks, removable hard drives, software products, etc.', 'In one possible implementation, logic, computing instructions, and/or software programs comprising elements of module \n2506\n may reside on removable media \n2520\n readable by media drive/interface \n2518\n.', 'In one possible embodiment, input/output device(s) \n2512\n can allow a user (such as a human annotator) to enter commands and information to device \n2500\n and allow information to be presented to the user and/or other components or devices.', 'Examples of input device(s) \n2512\n include, for example, sensors, a keyboard, a cursor control device (e.g., a mouse), a microphone, a scanner, and any other input devices known in the art.', 'Examples of output devices include a display device (e.g., a monitor or projector), speakers, a printer, a network card, and so on.', 'Various processes of present disclosure may be described herein in the general context of software or program modules, or the techniques and modules may be implemented in pure computing hardware.', 'Software generally includes routines, programs, objects, components, data structures, and so forth that perform particular tasks or implement particular abstract data types.', 'An implementation of these modules and techniques may be stored on or transmitted across some form of tangible computer-readable media.', 'Computer-readable media can be any available data storage medium or media that is tangible and can be accessed by a computing device.', 'Computer readable media may thus comprise computer storage media.', '“Computer storage media” designates tangible media, and includes volatile and non-volatile, removable and non-removable tangible media implemented for storage of information such as computer readable instructions, data structures, program modules, or other data.', 'Computer storage media include, but are not limited to, RAM, ROM, EEPROM, flash memory or other memory technology, CD-ROM, digital versatile disks (DVD) or other optical storage, magnetic cassettes, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other tangible medium which can be used to store the desired information, and which can be accessed by a computer.', 'Some of the methods and processes described above, can be performed by a processor.', 'The term “processor” should not be construed to limit the embodiments disclosed herein to any particular device type or system.', 'The processor may include a computer system.', 'The computer system may also include a computer processor (e.g., a microprocessor, microcontroller, digital signal processor, or general-purpose computer) for executing any of the methods and processes described above.', 'Some of the methods and processes described above, can be implemented as computer program logic for use with the computer processor.', 'The computer program logic may be embodied in various forms, including a source code form or a computer executable form.', 'Source code may include a series of computer program instructions in a variety of programming languages (e.g., an object code, an assembly language, or a high-level language such as C, C++, or JAVA).', 'Such computer instructions can be stored in a non-transitory computer readable medium (e.g., memory) and executed by the computer processor.', 'The computer instructions may be distributed in any form as a removable storage medium with accompanying printed or electronic documentation (e.g., shrink wrapped software), preloaded with a computer system (e.g., on system ROM or fixed disk), or distributed from a server or electronic bulletin board over a communication system (e.g., the Internet or World Wide Web).', 'Alternatively, or additionally, the processor may include discrete electronic components coupled to a printed circuit board, integrated circuitry (e.g., Application Specific Integrated Circuits (ASIC)), and/or programmable logic devices (e.g., a Field Programmable Gate Arrays (FPGA)).', 'Any of the methods and processes described above can be implemented using such logic devices.', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.', 'The specification and drawings are, accordingly, to be regarded in an illustrative rather than a restrictive sense.', 'It will, however, be evident that various modifications and changes may be made thereunto without departing from the broader spirit and scope of the invention as set forth in the claims.', 'Other variations are within the spirit of the present disclosure.', 'Thus, while the disclosed techniques are susceptible to various modifications and alternative constructions, certain illustrated embodiments thereof are shown in the drawings and have been described above in detail.', 'It should be understood, however, that there is no intention to limit the invention to the specific form or forms disclosed, but on the contrary, the intention is to cover all modifications, alternative constructions and equivalents falling within the spirit and scope of the invention, as defined in the appended claims.', 'The use of the terms “a” and “an” and “the” and similar referents in the context of describing the disclosed embodiments (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context.', 'The terms “comprising,” “having,” “including” and “containing” are to be construed as open-ended terms (i.e., meaning “including, but not limited to,”) unless otherwise noted.', 'The term “connected,” when unmodified and referring to physical connections, is to be construed as partly or wholly contained within, attached to or joined together, even if there is something intervening.', 'Recitation of ranges of values herein are merely intended to serve as a shorthand method of referring individually to each separate value falling within the range, unless otherwise indicated herein and each separate value is incorporated into the specification as if it were individually recited herein.', 'The use of the term “set” (e.g., “a set of items”) or “subset” unless otherwise noted or contradicted by context, is to be construed as a nonempty collection comprising one or more members.', 'Further, unless otherwise noted or contradicted by context, the term “subset” of a corresponding set does not necessarily denote a proper subset of the corresponding set, but the subset and the corresponding set may be equal.', 'Operations of processes described herein can be performed in any suitable order unless otherwise indicated herein or otherwise clearly contradicted by context.', 'Processes described herein (or variations and/or combinations thereof) may be performed under the control of one or more computer systems configured with executable instructions and may be implemented as code (e.g., executable instructions, one or more computer programs or one or more applications) executing collectively on one or more processors, by hardware or combinations thereof.', 'The code may be stored on a computer-readable storage medium, for example, in the form of a computer program comprising a plurality of instructions executable by one or more processors.', 'The computer-readable storage medium may be non-transitory.', 'All references, including publications, patent applications and patents, cited herein are hereby incorporated by reference to the same extent as if each reference were individually and specifically indicated to be incorporated by reference and were set forth in its entirety herein.', 'There have been described and illustrated herein several embodiments of methods and systems for measuring permittivity dispersion data of a subsurface formation from downhole electromagnetic measurements at multiple frequencies below 1 MHz and estimating salinity of the formation water of the subsurface formation.', 'Other useful formation properties (such as formation water saturation) can be determined based on the estimate of salinity of the formation water.', 'It will therefore be appreciated by those skilled in the art that yet other modifications could be made to the provided invention without deviating from its spirit and scope as claimed.', 'Although only a few example embodiments have been described in detail above, those skilled in the art will readily appreciate that many modifications are possible in the example embodiments without materially departing from this invention.', 'Accordingly, all such modifications are intended to be included within the scope of this disclosure as defined in the following claims.', 'In the claims, means-plus-function clauses are intended to cover the structures described herein as performing the recited function and not only structural equivalents, but also equivalent structures.', 'Thus, although a nail and a screw may not be structural equivalents in that a nail employs a cylindrical surface to secure wooden parts together, whereas a screw employs a helical surface, in the environment of fastening wooden parts, a nail and a screw may be equivalent structures.', 'It is the express intention of the applicant not to invoke 35 U.S.C. § 112, paragraph 6 for any limitations of any of the claims herein, except for those in which the claim expressly uses the words ‘means for’ together with an associated function.']

['1.', 'A method for characterizing a subsurface formation, comprising:\ni) configuring and operating a downhole logging tool to conduct downhole electromagnetic measurements on the subsurface formation over a range of frequencies, and obtaining with the downhole logging tool the electromagnetic measurements, wherein the downhole electromagnetic measurements are used to determine and store multifrequency permittivity data that characterizes permittivity of the subsurface formation over a set of frequencies less than 1 MHz;\nii) processing the multifrequency permittivity data to determine salinity of formation water of the subsurface formation, wherein the processing of ii) involves:\ncalculating derivatives of the multifrequency permittivity data;\nusing such derivatives to determine a slope representing change in permittivity relative to change in frequency;\nusing the slope as an input to a first calibration equation that relates the slope to a calibration parameter, wherein a value for the calibration parameter is determined by solving the first calibration equation given the slope as input; and\nusing the value of the calibration parameter as input to a second calibration equation that relates the calibration parameter to salinity of the formation water of the subsurface formation, wherein a value for the salinity of the formation water is determined by solving the second calibration equation given the calibration parameter as input; and\n(iii) using the salinity of formation water of the subsurface formation to determine at least one of a field development plan for the subsurface formation and a production plan for the subsurface formation.', '2.', 'A method according to claim 1, further comprising:\nstoring or outputting data that represents the salinity of the formation water of the subsurface formation.', '3.', 'A method according to claim 1, wherein:\nthe set of frequencies includes frequencies between 1 MHz and 1 KHz; and/or\nthe set of frequencies includes frequencies between 1 KHz and 100 Hz; and/or\nthe set of frequencies includes frequencies between 100 Hz and 10 Hz.\n\n\n\n\n\n\n4.', 'A method according to claim 1, further comprising:\ndetermining at least one additional formation property based on the salinity of the formation water of the subsurface formation.', '5.', 'A method according to claim 4, wherein:\nthe at least one additional formation property comprises formation water saturation.', '6.', 'A method according to claim 1, wherein:\nthe first calibration equation relates the slope and at least one additional parameter to the calibration parameter.', '7.', 'A method according to claim 1, wherein:\nthe at least one additional parameter represents at least one of clay volume and frequency.', '8.', 'A method according to claim 1, wherein: V clay = a \u2062 d', '\u2062 ɛ df \u2062', 'f b, where Vclay is clay volume, d', '\u2062', 'ɛ df is the slope representing change in permittivity relative to change in frequency, f is frequency, a and b are calibration parameters, where a is the calibration parameter determined by solving the first calibration equation.', 'the first calibration equation has the form\n\n\n\n\n\n\n9.', 'A method according to claim 1, wherein:\nthe second calibration equation has the form Sal=C1×a2+C2×a+C3, where C1, C2 and C3 are calibration constants, a is the calibration parameter determined by solving the first calibration equation and input to the second calibration equation, and Sal is a value of salinity of formation water determined by solving the second calibration equation.\n\n\n\n\n\n\n10.', 'A method according to claim 1, wherein:\nthe second calibration equation is selected from a set of calibration equations corresponding to different formation temperatures, where the selection is based on measured formation temperature of the subsurface formation.', '11.', 'A method according to claim 1, wherein:\nat least one of the first and second calibration equations are selected from calibration equations corresponding to different clay volume and clay type, where the selection is based on a determination of clay volume and clay type of the subsurface formation.', '12.', 'A method according to claim 11, wherein:\nthe clay types include kaolinite, smectite, illite, chlorite, and possibly combinations thereof.', '13.', 'A method according to claim 1, wherein:\nthe processing of ii) is performed by a processor.', '14.', 'A method according to claim 1, wherein the salinity of formation water of the subsurface formation is used to determine the field development plan for the subsurface formation.', '15.', 'A method according to claim 1, wherein the salinity of formation water of the subsurface formation is used to determine the production plan for the subsurface formation.', '16.', 'A method according to claim 1, wherein the salinity of formation water of the subsurface formation is used to determine the field development plan and the production plan for the subsurface formation.', '17.', 'A method for characterizing a subsurface formation, comprising:\ni) obtaining multifrequency permittivity data that characterizes permittivity of the subsurface formation over a set of frequencies less than 1 MHz with a processor;\nii) processing the multifrequency permittivity data with the processor to determine salinity of formation water of the subsurface formation, wherein the processing of ii) involves: calculating derivatives of the multifrequency permittivity data; using such derivatives to determine a slope representing change in permittivity relative to change in frequency; using the slope as an input to a first calibration equation that relates the slope to a calibration parameter, wherein a value for the calibration parameter is determined by solving the first calibration equation given the slope as input; and using the value of the calibration parameter as input to a second calibration equation that relates the calibration parameter to salinity of the formation water of the subsurface formation, wherein a value for the salinity of the formation water is determined by solving the second calibration equation given the calibration parameter as input; and\n(iii) using the salinity of formation water of the subsurface formation to determine at least one of a field development plan for the subsurface formation and a production plan for the subsurface formation.', '18.', 'A method according to claim 17, wherein:\nthe set of frequencies includes frequencies between 1 MHz and 1 KHz; and/or\nthe set of frequencies includes frequencies between 1 KHz and 100 Hz; and/or\nthe set of frequencies includes frequencies between 100 Hz and 10 Hz.\n\n\n\n\n\n\n19.', 'A method according to claim 17, wherein:\nthe at least one processor is further configured to determine at least one additional formation property based on the salinity of the formation water of the subsurface formation.', '20.', 'A method according to claim 17, wherein:\nthe multifrequency permittivity data is derived from multifrequency electromagnetic measurements performed by a downhole logging tool selected from the group consisting of a wireline logging tool, a logging-while-drilling logging tool, a measurement-while-drilling logging tool, and a tripping-while-drilling logging tool.']

['FIGS.', '1A, 1B and 1C depict plots of relative permittivity computed as a function of frequency (in Hz) for a shaly sand formation rock containing 10% illite under different water volumes (including 4%, 20% and 36%) and different formation water salinities of 30 ppk (FIG.', '1A), 60 ppk (FIG.', '1B) and 150 ppk (FIG.', '1C);;', 'FIGS.', '2A, 2B and 2C depict plots of relative permittivity computed as a function of frequency (in Hz) for a shaly sand formation rock containing different clay volumes (including 1%, 5%, 10%, 20% and 30%) with a water volume of 24% and different formation water salinities of 30 ppk (FIG.', '2A), 60 ppk (FIG.', '2B) and 150 ppk (FIG.', '2C).', 'FIGS.', '2A, 2B and 2C also include horizontal dashed lines depicting relative permittivity computed as a function of frequency (in Hz) for a clay-free shaly sand formation rock (0% clay) with a water volume of 24% and different formation water salinities of 30 ppk (FIG. 2A), 60 ppk (FIG.', '2B) and 150 ppk (FIG.', '2C);; FIGS.', '3A, 3B and 3C depict plots of the derivatives of the relative permittivity as a function of frequency (in Hz) of FIGS.', '2A, 2B and 2C for the shaly sand formation rock containing different clay volumes (including 1%, 5%, 10%, 20% and 30%) with a water volume of 24% and different formation water salinities of 30 ppk (FIG.', '3A), 60 ppk (FIG.', '3B) and 150 ppk (FIG.', '3C);; FIG.', '4 depicts correlation curves between the calibration parameter a of the calibration equation (1) as described herein to formation water salinity (in ppk) for four different formation temperatures of 100° F., 200° F., 300° F., and 400° F.;; FIG.', '5 is a flowchart illustrating a methodology for measuring multifrequency permittivity data of a subsurface formation from downhole electromagnetic measurements.', 'The multifrequency permittivity data is processed to estimate salinity of the formation water of the subsurface formation.', 'Other useful formation properties (such as formation water saturation) can be determined based on the estimate of salinity of the formation water; and; FIG.', '6 is a block diagram of a computer processing system, which can be used to embody parts of the methodology for quantification of formation water salinity and other useful formation properties based thereon.;', 'FIGS.', '1A, 1B and 1C show calculations of relative permittivity εr as a function of frequency ω (in Hz) for a shaly sand matrix under different water volumes of 4%, 20% and 36%.', 'The shaly sand matrix of the three examples includes 90% sandstone and 10% illite assuming spherical grains.', 'Three different water salinities are used in the calculations.', 'Specifically, the calculations of FIG.', '1A employ a water salinity of 30 parts per thousand (ppk), the calculations of FIG.', '1B employ a water salinity of 60 parts per thousand (ppk), and the calculations of FIG.', '1C employ a water salinity of 150 parts per thousand (ppk).', 'Based on the plots, the characteristics of the relative permittivity εr as a function of frequency ω (in Hz) can be summarized as follows: strong dispersions in relative permittivity below 10 kHz; the dispersions in relative permittivity do not depend on water volume; the relative permittivity decreases with the increased water salinity; and above 100 kHz, there is no dispersion and the relative permittivity depends on water volume.; FIG.', '5 depicts a workflow that uses downhole electromagnetic measurements at frequencies below 1 MHz of a subsurface formation of interest to determine multifrequency permittivity data (or permittivity dispersion data) for the formation of interest over a range of low frequencies (below 1 MHz).', 'The multifrequency permittivity data of the subsurface formation of interest is processed to determine or quantify salinity of formation water contained in the subsurface formation of interest.', 'Other useful formation properties (such as formation water saturation) can be determined based on the formation water salinity.', '; FIG.', '6 illustrates an example device 2500, with a processor 2502 and memory 2504 that can be configured to implement various embodiments of the methods and workflows as discussed in this disclosure.', 'Memory 2504 can also host one or more databases and can include one or more forms of volatile data storage media such as random-access memory (RAM), and/or one or more forms of nonvolatile storage media (such as read-only memory (ROM), flash memory, and so forth).']

US11834931

Wellbore planner

Aug 21, 2022

Valerian Guillot, Ho Bun Lau, John Morrison Whyte, Florian Karpfinger

Schlumberger Technology Corporation

NPL References not found.

20030079912; May 1, 2003; Leuchtenberg; 20090299714; December 3, 2009; Kelkar; 20100181073; July 22, 2010; Dupriest et al.; 20130341093; December 26, 2013; Jardine; 20170052272; February 23, 2017; Maeso; 20190323332; October 24, 2019; Cuellar; 20200174152; June 4, 2020; Kesserwan et al.

Foreign Citations not found.

['A downhole wellbore planner builds a fracture model of a wellbore using fracture data identified from geological information.', 'Using the fracture model and a target wellbore location at the formation, the wellbore planner may identify or select one or more lost circulation materials (LCMs).', 'The drilling operator may then procure the LCMs before drilling the wellbore.', 'In this manner, the impact of a lost circulation event may be reduced by having the LCMs on site or nearby.']

['Description\n\n\n\n\n\n\nCROSS-REFERENCE TO RELATED APPLICATIONS', 'This application claims the benefit of, and priority to, U.S. Patent Application Ser.', 'No. 63/260,448, filed Aug. 20, 2022, which application is expressly incorporated herein by this reference in its entirety.', 'BACKGROUND\n \nTraditional wellbore drilling practices attempted to drill wells as near to the vertical as possible; however, it is now common to drill directional or deviated wells by directing a drill bit along a defined trajectory to a predetermined target.', 'With increased directional drilling capabilities, there has been an increased desire for directional drilling, and directional drilling is being applied in myriad applications and formations, causing wellbore trajectories to become increasingly more complex.', 'Wellbore trajectory planning can be accomplished by, for instance, plotting together a series of curve and hold sections, and then reviewing and repeating this for the sections until well planners obtain a satisfactory trajectory.', 'During this process, trajectories may be evaluated based on formation, drilling, or trajectory parameters such as formation type and properties, dog-leg severity, torque, drag, and drilling rig requirements or limitations.', 'After drilling commences, it may be realized that the tools may have deviated from the plan or that the pre-planned trajectory may not arrive at the desired target, and that a trajectory correction should be applied.', 'Alternatively, it may be determined that the desired target has changed, and that the trajectory should change to reach the new target.', 'Trajectory planning may therefore occur offline before drilling starts, but also in near real-time to control or re-plan the trajectory.', 'SUMMARY\n \nIn some embodiments, a method for wellbore planning includes receiving geological information about a formation.', 'Fracture characteristics are identified in the formation using the geological information.', 'A fracture model of the formation is built using the fracture characteristics.', 'Based at least in part on the fracture model, one or more lost circulation treatments are identified to mitigate a lost circulation event.', 'In some embodiments, a method for wellbore planning includes, before performing a drilling operating, building a fracture model of a formation through which a wellbore will be drilled.', 'The fracture model includes fracture characteristics that are extrapolated from one or more offset wellbores.', 'A target wellbore path is identified through the formation.', 'Expected fracture properties are identified for the target wellbore path from the fracture model.', 'Based at least in part on the expected fracture properties, one or more lost circulation materials are identified for the target wellbore path.', 'This summary is provided to introduce a selection of concepts that are further described in the detailed description.', 'This summary is not intended to identify key or essential features of the claimed subject matter, nor is it intended to be used as an aid in limiting the scope of the claimed subject matter.', 'Additional features and aspects of embodiments of the disclosure will be set forth herein, and in part will be obvious from the description, or may be learned by the practice of such embodiments.', 'BRIEF DESCRIPTION OF THE DRAWINGS', 'In order to describe the manner in which the above-recited and other features of the disclosure can be obtained, a more particular description will be rendered by reference to specific embodiments thereof which are illustrated in the appended drawings.', 'For better understanding, the like elements have been designated by like reference numbers throughout the various accompanying figures.', 'While some of the drawings may be schematic or exaggerated representations of concepts, at least some of the drawings may be drawn to scale.', 'Understanding that the drawings depict some example embodiments, the embodiments will be described and explained with additional specificity and detail through the use of the accompanying drawings in which:\n \nFIG.', '1\n is a representation of a drilling system, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n1\n is a representation of geological information used to create a fracture model, according to at least one embodiment of the present disclosure;\n \nFIG.', '2\n-\n2\n is a representation of a fracture model generated from the geological information of \nFIG.', '2\n-\n1\n;\n \nFIG.', '3\n is a representation of a series of use maps, according to at least one embodiment of the present disclosure;\n \nFIG.', '4\n is a representation of a wellbore planner, according to at least one embodiment of the present disclosure;\n \nFIG.', '5\n is a representation of a machine learning model, according to at least one embodiment of the present disclosure;\n \nFIG.', '6\n is a flowchart of a method for planning a wellbore, according to at least one embodiment of the present disclosure;\n \nFIG.', '7\n is a flowchart of a method for planning a wellbore, according to at least one embodiment of the present disclosure; and\n \nFIG.', '8\n is a representation of a computing system, according to at least one embodiment of the present disclosure.', 'DETAILED DESCRIPTION', 'This disclosure generally relates to devices, systems, and methods for wellbore planning and lost circulation event mitigation.', 'Using geological information from offset wellbores, a fracture model may be developed for a formation.', 'The fracture model may include fracture characteristics, such as fracture thickness, width, depth, dip, strike, and so forth.', 'Using the fracture model, a wellbore planner may identify, recommend, or select one or more lost circulation materials (LCMs) for use in a lost circulation event.', 'The fracture model and LCM recommendation may be performed before the wellbore is drilled.', 'In this manner, the drilling operator may have the identified LCM on site, thereby limiting the impact of a lost circulation event.\n \nFIG.', '1\n shows one example of a drilling system \n100\n for drilling an earth formation \n101\n to form a wellbore \n102\n.', 'The drilling system \n100\n includes a drill rig \n103\n used to turn a downhole drilling tool assembly \n104\n which extends downward into the wellbore \n102\n.', 'The downhole drilling tool assembly \n104\n may include a drill string \n105\n, a bottomhole assembly (BHA) \n106\n, and a bit \n110\n, attached to the downhole end of drill string \n105\n.', 'In some embodiments, the downhole drilling tool assembly \n104\n, or elements of the downhole drilling tool assembly \n104\n, may be configured to erode the formation.', 'For example, the bit \n110\n, a reamer, a casing cutter, any other downhole drilling tool, and combinations thereof may be configured to erode or degrade the formation to advance the wellbore and/or make a change to a dimension or other part of the wellbore.', 'The drill string \n105\n may include several joints of drill pipe \n108\n connected end-to-end through tool joints \n109\n.', 'The drill string \n105\n transmits drilling fluid through a central bore and transmits rotational power from the drill rig \n103\n to the BHA \n106\n.', 'In some embodiments, the drill string \n105\n may further include additional components such as subs, pup joints, etc.', 'The drill pipe \n108\n provides a hydraulic passage through which drilling fluid is pumped from the surface.', 'The drilling fluid discharges through selected-size nozzles, jets, or other orifices in the bit \n110\n for the purposes of cooling the bit \n110\n and cutting structures thereon, and for lifting cuttings out of the wellbore \n102\n as it is being drilled.', 'The BHA \n106\n may include the bit \n110\n or other components.', 'An example BHA \n106\n may include additional or other components (e.g., coupled between to the drill string \n105\n and the bit \n110\n).', 'Examples of additional BHA components include drill collars, stabilizers, measurement-while-drilling (MWD) tools, logging-while-drilling (LWD) tools, downhole motors, underreamers, section mills, hydraulic disconnects, jars, vibration or dampening tools, other components, or combinations of the foregoing.', 'The BHA \n106\n may further include a rotary steerable system (RSS).', 'The RSS may include directional drilling tools that change a direction of the bit \n110\n, and thereby the trajectory of the wellbore.', 'At least a portion of the RSS may maintain a geostationary position relative to an absolute reference frame, such as gravity, magnetic north, and/or true north.', 'Using measurements obtained with the geostationary position, the RSS may locate the bit \n110\n, change the course of the bit \n110\n, and direct the directional drilling tools on a projected trajectory.', 'In general, the drilling system \n100\n may include other drilling components and accessories, such as special valves (e.g., kelly cocks, blowout preventers, and safety valves).', 'Additional components included in the drilling system \n100\n may be considered a part of the downhole drilling tool assembly \n104\n, the drill string \n105\n, or a part of the BHA \n106\n depending on their locations in the drilling system \n100\n.', 'The bit \n110\n in the BHA \n106\n may be any type of bit suitable for degrading downhole materials.', 'For instance, the bit \n110\n may be a drill bit suitable for drilling the earth formation \n101\n.', 'Example types of drill bits used for drilling earth formations are fixed cutter or drag bits.', 'In other embodiments, the bit \n110\n may be a mill used for removing metal, composite, elastomer, other materials downhole, or combinations thereof.', 'For instance, the bit \n110\n may be used with a whipstock to mill into casing \n107\n lining the wellbore \n102\n.', 'The bit \n110\n may also be a junk mill used to mill away tools, plugs, cement, other materials within the wellbore \n102\n, or combinations thereof.', 'Swarf or other cuttings formed by use of a mill may be lifted to surface, or may be allowed to fall downhole.', 'In some situations, during drilling operations, the formation may include one or more fractures \n112\n or fracture networks.', 'A fracture \n112\n may be any break, fracture, fissure, hole, void, karst, or other space in a rock or series of rocks.', 'An individual fracture \n112\n may have a thickness, a width, a length, a strike, and a dip.', 'The thickness, width, and length may the geometrical properties of the fracture \n112\n, with the thickness being the shortest distance between opposing sides of the fracture \n112\n, and width and length being the geographical extent in directions transverse to the thickness.', 'For simplicity of description, thickness may be considered the extent of the fracture \n112\n in the z-axis, width the extent of the fracture \n112\n in the x-axis, and length the extent of the fracture \n112\n in the y-axis.', 'The dip may be the angle that the fracture \n112\n is oriented from horizontal, and the strike may be the horizontal orientation of the fracture \n112\n.', 'The thickness, length, and/or width of the fracture \n112\n may impact how much fluid may travel through the fracture \n112\n.', 'A fracture \n112\n having a greater thickness may transmit more fluid, and a fracture \n112\n having a greater length and/or width may transmit fluid further and/or transmit more fluid.', 'In some situations, if a wellbore intersects a fracture \n112\n, drilling fluid in the wellbore may travel into and/or through the fracture \n112\n.', 'For example, as the wellbore advances, the bit may intersect one or more fractures \n112\n, or a fracture network that includes a plurality of interconnected or fluidly connected fractures \n112\n.', 'Drilling fluid may enter the fracture \n112\n that intersects the wellbore.', 'The drilling fluid may then be transmitted to adjacent fractures in fluid communication with the intersecting fractures.', 'In some situations, the drilling fluid may travel into the formation and be “lost,” or be removed from circulation.', 'In some situations, circulation of the drilling fluid may be partially or fully lost in a lost circulation event, meaning that drilling fluid that is pumped into the wellbore is not returned to the surface.', 'This may result in a reduced in drilling efficiency and/or drilling effectiveness, and may result in damage to downhole tools.', 'To mitigate a lost circulation event, a drilling operator may implement a lost circulation treatment.', 'Lost circulation treatments may include changing one or more drilling parameters to attempt to restore circulation.', 'Such drilling parameters may include changing properties of the drilling fluid, such as drilling fluid density, viscosity, composition, any other drilling fluid property, and combinations thereof.', 'In some situations, a lost circulation treatment may include the introduction of a lost circulation material (LCM).', 'An LCM may be a material that infiltrates the one or more fractures \n112\n and reduces the transmissibility of the drilling fluid.', 'LCMs may plug the fractures in many different ways, including physically and/or chemically.', 'A chemical LCM may be a fluid or series of suspended that infiltrates the fractures \n112\n.', 'A chemical reaction may cause the fluid to solidify, thereby plugging the fractures \n112\n.', 'A physical LCM may include particles of a particular size and/or composition that may infiltrate the fractures \n112\n.', 'Stacking of the particles may partially or fully plug the fracture.', 'In accordance with embodiments of the present disclosure, a drilling operator, using data collected from offset wellbores that intersect the target formation, may generate a fracture model of the fracture network in the formation.', 'The fracture model may be extrapolated from the data collected from the offset wellbores.', 'In some embodiments, the fracture model may include the extrapolated thickness, width, length, dip, and azimuth, and other features of the fractures.', 'In some embodiments, the fracture model may include the interconnectivity of individual fractures in the fracture network.', 'In some embodiments, using the fracture model, the drilling operator may identify one or more LCMs to use if a lost circulation event occurs.', 'For example, a drilling operator may have a list of available LCMs.', 'Each LCM has particular properties that may optimize that LCM for a fracture \n112\n or fracture network.', 'For example, the particle size of the LCM may be selected based on the thickness of the fracture \n112\n.', 'The drilling operator may select a particle size of LCM that is small enough to fit in the fracture \n112\n, but large enough to become lodged in the fracture \n112\n.', 'In this manner, the LCM may plug the fracture \n112\n.', 'Selecting an LCM based on the fracture model may allow the drilling operator to plug the fracture network with the first LCM attempt, rather than working through LCMs on a trial-and-error basis.', 'This may reduce downtime due to a lost circulation event and/or reduce the cost associated with a lost circulation treatment.', 'In some embodiments, the fracture model may be generated using geological information about the formation through which the target wellbore will be drilled.', 'For example, the fracture model may be generated geological information from offset wellbores that drilled through the same formation.', 'Offset wellbores may include any type of wellbores, including exploration wellbores, core holes, production wellbores, any other wellbore, and combinations thereof.', 'In some embodiments, the geological information may include any type of geological information.', 'For example, the geological information may include visual information (e.g., visual information obtained from borehole images, borehole scopes, and so forth), seismic information, resistivity information (e.g., a difference in resistivity between a fracture \n112\n and the solid formation), rock type, rock density, information about lost circulation events in the formation, any other type of geological information, and combinations thereof.', 'The geological information may be used to identify the fractures \n112\n, including identifying the fracture thickness, width, length, dip, strike, fracture density, and so forth.', 'As may be seen in \nFIG.', '2\n-\n1\n, geological data from a series of offset wellbores (collectively \n214\n) may be used to identify trends and/or patterns between fractures \n212\n of a formation \n216\n.', 'It should be understood that the offset wellbores \n214\n may be located at any distance and any azimuth away from each other and a target wellbore.', 'Each of the offset wellbores \n214\n intersect and/or include geological information about the formation \n216\n.', 'The geological information may be used to identify characteristics of the fractures \n212\n.', 'For ease of illustration, the fractures \n212\n are shown having a length, orientation, and a line thickness.', 'The length and orientation may represent the extent and direction of the fracture \n212\n, respectively, while the line thickness may be representative of the thickness of the fracture \n212\n.', 'A drilling operator and/or fracture model generator may analyze the fractures \n212\n in the formation \n216\n between the different offset wellbores \n214\n and identify patterns between the fractures \n212\n identified in different wellbores.', 'For example, the fracture model generator may identify that the fractures in the formation \n216\n generally have a low thickness and have a steep orientation (represented by the generally thin lines representing the fractures \n212\n and the generally vertical orientation).', 'The fracture model generator may develop a fracture model indicating averages of fracture size and density.', 'As may be seen, size, density, and/or orientation of the fractures \n212\n may vary between offset wellbores \n214\n.', 'For example, in the embodiment shown, the fractures \n212\n in a first offset wellbore \n214\n-\n1\n may have a higher fracture density (e.g., more fractures per vertical and/or horizontal extent) than the fractures \n212\n of the second offset wellbore \n214\n-\n2\n.', 'The fractures \n212\n in the second offset wellbore \n214\n-\n2\n may, in turn, have a higher fracture density than the fractures \n212\n in a third offset wellbore \n214\n-\n3\n, which may have a higher fracture density than the fractures \n212\n in a fourth offset wellbore \n214\n-\n4\n.', 'The fractures \n212\n in a fifth offset wellbore \n214\n-\n5\n may have a larger thickness than the fractures in the sixth offset wellbore \n214\n-\n6\n.', 'While fracture density and/or fracture thickness have been discussed and shown herein, it should be understood that any other fracture property may be inferred or determined from the geological information shown in the offset wellbores.', 'Using the identified fractures \n212\n and their properties, the fracture network generator may generate a fracture network.', 'In some embodiments, the generated fracture network may be generated for the formation \n216\n.', 'In some embodiments, the generated fracture network may be generated for a series of formations or strata.', 'For example, a series of formations or strata may include similar fractures and/or share a fracture network.', 'The fracture network may be used to develop a fracture network map, such as the fracture network map \n218\n shown in \nFIG.', '2\n-\n2\n.', 'The fracture network map \n218\n may be calibrated to show in color or grayscale a particular fracture network property, such as average fracture thickness, maximum fracture thickness, average fracture density, fracture connectivity, fracture orientation (e.g., dip and/or strike), fracture length and/or width, any other fracture network property, and combinations thereof.', 'In some embodiments, the fracture network may include fracture network properties for particular geographical coordinates.', 'In some embodiments, the fracture network property may include drilling fluid transmissibility.', 'Drilling fluid transmissibility may be a measure of how well drilling fluid may travel through the fracture network, with a high transmissibility being associated with more drilling fluid traveling through the fracture network.', 'In some embodiments, drilling fluid transmissibility may be determined using a combination of other fracture network properties.', 'For example, a fracture network having a high fracture density and a high fracture connectivity may have a high transmissibility.', 'A fracture network having a high average fracture thickness and a low fracture connectivity may have high or medium transmissibility.', 'Drilling fluid transmissibility may be related to many different fracture network properties.', 'In some embodiments, the drilling fluid transmissibility may be associated with the risk of a wellbore having a lost circulation event.', 'For example, a high drilling fluid transmissibility may be associated with a high risk of a lost circulation event.', 'If a target wellbore passes through a zone having a high risk of a lost circulation event, then the target wellbore may therefore be at risk of a lost circulation event.', 'If the target wellbore is at risk of a lost circulation event, the drilling operator may be able to prepare to mitigate the lost circulation event with a lost circulation treatment, such as an LCM.', 'In some embodiments, an LCM identifier may identify one or more LCMs from a list of LCMs that may be effective in the event of a lost circulation event.', 'The LCM identifier may take into account the properties of the various LCMs and compare them to the fracture network properties.', 'For example, the LCM identifier may analyze properties from a table such as Table 1, which includes a list of particle diameters for various LCMs, in micrometers.', 'In Table 1, the values in column d10 are the particle size that 10% of the particles of the LCM are equal to or less than, the values in column d25 are the particle size that 25% of the particles of the LCM are equal to or less than, and so forth.', 'The LCM identifier may then identify or recommend one or more LCMs that may be appropriate or effective for a lost circulation event.', 'For example, the LCM identifier may analyze the particle size distribution of an LCM from Table 1 and compare it to the average thickness and/or thickness profile (e.g., the range of thicknesses of fractures) of the fracture network.', 'If the particle size distribution is complementary to the average thickness (e.g., the particles of the LCM may enter the fractures to clog the fractures), then the LCM may be recommended for the target wellbore.', 'In some examples, the LCM identifier may analyze other LCM properties, such as particle shape, maximum particle size, minimum particle size, any other LCM property, and combinations thereof to provide recommendations for the wellbore.\n \n \n \n \n \n \n \n \nTABLE 1\n \n \n \n \n \n \n \n \nParticle size distribution of various LCMs\n \n \n \n \n \n \n \n \n \n \n \n \n \nLCM\n \nd10\n \nd25\n \nd50\n \nd75\n \nd90\n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \n \nLCM 1\n \n2\n \n5\n \n10\n \n13\n \n20\n \n \n \nLCM 2\n \n100\n \n110\n \n180\n \n230\n \n300\n \n \n \nLCM 3\n \n10\n \n15\n \n25\n \n35\n \n55\n \n \n \nLCM 4\n \n2\n \n20\n \n60\n \n90\n \n120\n \n \n \nLCM 5\n \n5\n \n \n80\n \n \n240\n \n \n \n \n \n \n \n \n \n \nIn some embodiments, a drilling operator may procure the identified and/or recommended LCM prior to drilling the wellbore or performing drilling operations.', 'The drilling operator may store the recommended LCM on site.', 'If a lost circulation event occurs, the drilling operator may utilize the LCM that is on site to mitigate the lost circulation event.', 'Because the LCM is on site, and has been selected based on the fracture model, there is an increased chance that the LCM will be effective.', 'This may help to reduce the impact of an LCM on the overall drilling rate, which may reduce the cost of the wellbore.', 'This may further help to reduce the cost of lost circulation treatments.', 'In some embodiments, this may help to prevent the loss of the wellbore due to lost circulation.', 'In some embodiments, the LCM identifier may provide one or more use maps that provide an indication how well a particular LCM will perform at a particular location of the fracture network map \n218\n.', 'In \nFIG. \n3\n, the fracture network map \n218\n of \nFIG.', '2\n has been converted to a use map (collectively \n320\n) for various LCMs.', 'Using the fracture network map \n218\n, the LCM identifier may determine whether a particular LCM will be effective for at different locations.', 'For example, a first use map \n320\n-\n1\n may be associated with a first LCM, where white is an indication of where the first LCM will likely be effective and black is an indication of where the first LCM will likely be ineffective.', 'Using a target wellbore location \n322\n, which may be a location in the formation through which a target wellbore is projected to travel, the drilling operator may determine whether the LCM will be effective if a lost circulation event occurs.', 'As may be seen, the first use map \n320\n-\n1\n indicates that the first LCM will likely be ineffective at the target wellbore location \n322\n.', 'Reviewing the second use map \n320\n-\n2\n of a second LCM, there are more areas where the second LCM will likely be effective.', 'However, at the target wellbore location \n322\n, the second LCM will still likely not be effective.', 'In the third use map \n320\n-\n3\n, different areas of effectiveness are shown, with the target wellbore location still being likely ineffective.', 'In the fourth use map \n320\n-\n4\n, the fourth LCM appears to be effective in all locations, including at the target wellbore location \n322\n.', 'Using the use maps \n320\n of \nFIG. \n3\n, the drilling operator may determine or select which LCM to use, procure, or otherwise maintain in stock for drilling operations.', 'For example, using the use maps \n320\n of \nFIG.', '3\n, the drilling operator may determine that the fourth LCM will likely be the most effective for the formation shown at the target wellbore location \n322\n.', 'In this manner, a drilling operator may be able to procure in advance and/or maintain in stock the appropriate LCM for a wellbore.', 'Furthermore, in the event of a lost circulation event, the drilling operator may be able to sooner utilize the appropriate LCM to mitigate the lost circulation event.', 'In this manner, the drilling operator may mitigate the lost circulation event sooner, thereby reducing the amount of downtime caused by the lost circulation event.', 'This may save time, money, and may prevent the loss of a wellbore due to a lost circulation event.', 'While the use maps \n320\n of \nFIG.', '3\n are shown as binary systems, where the LCM mapped is either effective or ineffective, it should be understood that different use maps \n320\n may be generated.', 'For example, one or more use maps may be generated of a heat map of the predicted effectiveness of the selected LCM.', 'The heat map may provide the probability of mitigating the LCM at a particular location along the formation.', 'In some embodiments, the use map may include different colors or other identifiers for regions where a particular LCM may be effective so that a user may analyze a single use map and identify which LCM to use for a target wellbore location.\n \nFIG.', '4\n is a representation of a wellbore planner \n424\n, according to at least one embodiment of the present disclosure.', 'The wellbore planner \n424\n includes a fracture identifier \n426\n, which may take geological information, such as from offset wellbores, and identify one or more fractures.', 'The fracture identifier \n426\n may identify fractures from any type of geological information, including visual information (e.g., visual information obtained from borehole images, borehole scopes, and so forth), seismic information, resistivity information, information about lost circulation events in the formation, any other type of geological information, and combinations thereof.', 'The fracture identifier \n426\n may identify fracture characteristics of the fractures, such as fracture thickness, width, length, dip, strike, any other fracture characteristics, and combinations thereof.', 'Using the fracture information from the fracture identifier, a fracture model generator \n428\n may generate one or more fracture models for a particular formation, stratum, groups of formations, strata, and combinations thereof.', 'The fracture model may utilize fracture information from multiple offset wellbores to generate trends and/or averages of fracture information across an area of the formation.', 'The fracture model may be generated as a 2 or 3 dimensional map of the formation based on any of the fracture properties.', 'Using the fracture model, an LCM identifier \n430\n may analyze the averages and trends of fracture properties of the fractures and identify one or more LCMs that may be suitable and/or effective as a lost circulation treatment for a lost circulation event.', 'The LCM identifier \n430\n may create one or more use maps that may identify areas of the formation where an LCM may be effective.', 'For example, multiple use maps may be created by the LCM identifier for multiple different LCMs.', 'A drilling operator may analyze a target wellbore location for a target wellbore on the use map and determine whether the LCM will be effective.', 'In some embodiments, the use map may include multiple LCMs on the same map, with different locations on the map being associated with the LCM that may be identified as the most effective for that particular location.', 'In some embodiments, the LCM identifier \n430\n may generate a recommendation for which LCM to use for a particular target wellbore location.', 'For example, the LCM identifier \n430\n may analyze a table or other database of LCMs and select or recommend a particular LCM or set of LCMs for a particular target wellbore.', 'This may help the drilling operator to prepare for a lost circulation event while drilling the wellbore, thereby reducing the potential impact of a lost circulation event on the wellbore.', 'In some embodiments, the LCM identifier \n430\n may provide a prediction regarding the amount of LCM that may be used to mitigate a lost circulation event.', 'A prediction of the amount of LCM to be used may further help the drilling operator to procure and/or stock the appropriate amount of LCM to mitigate a lost circulation event.', 'In accordance with embodiments of the present disclosure, the wellbore planner may include one or more machine learning (ML) models \n432\n.', 'For example, the fracture identifier \n426\n may use a ML model \n432\n to identify fractures using geological information.', 'The ML model \n432\n may be refined using measured observations associated with the geological information.', 'In some embodiments, the fracture model generator \n428\n may utilize a ML model \n432\n to generate the fracture models.', 'For example, the fracture model generator \n428\n may generate a fracture model using the fracture information from the fracture identifier \n426\n.', 'When the wellbore is drilled through the fracture model, the predictions from the model may be compared to the observed conditions of the wellbore.', 'The ML model \n432\n may be refined using the observed conditions by comparing the observed conditions to the predicted conditions.', 'In some embodiments, the LCM identifier \n430\n may use a ML model \n432\n to provide recommendations or predictions for the effectiveness of a particular LCM.', 'Put another way, the ML model \n432\n identifies the LCM to be used in the formation.', 'If an LCM is used to mitigate a lost circulation event, the effectiveness of the LCM may be compared to the recommended effectiveness.', 'This comparison may, in turn, be used to update the ML model \n432\n.', 'Utilizing a ML model \n432\n may help to provide more representative recommendations and/or predictions by the fracture identifier \n426\n, the fracture model generator \n428\n, and/or the LCM identifier \n430\n.\n \nFIG.', '5\n is a representation of a ML model \n534\n to be used by a wellbore planning system, according to at least one embodiment of the present disclosure.', 'The ML model \n534\n may be implemented by the wellbore planner \n424\n of \nFIG.', '4\n.', 'Put another way, one or more elements of the wellbore planner \n424\n of \nFIG.', '4\n may implement the ML model \n534\n.', 'The ML model \n534\n includes a fracture model generator \n536\n which may receive offset wellbore data \n538\n as input.', 'The offset wellbore data \n538\n may include geological information about a formation through which the wellbore may be drilled, as discussed herein.', 'Using the offset wellbore data \n538\n, the fracture model generator \n536\n may generate a fracture model \n540\n.', 'The fracture model \n540\n may be used by an LCM identifier \n542\n.', 'The LCM identifier \n542\n may analyze the fracture model \n540\n and provide recommendations for one or more LCMs to use in a lost circulation event.', 'In some embodiments, the LCM identifier \n542\n may receive a target wellbore location \n544\n of a target wellbore at the formation for which the fracture model \n540\n has been generated.', 'Using the fracture model \n540\n and the target wellbore location \n544\n, the LCM identifier \n542\n may generate one or more use maps that provide an analysis and/or recommendation of LCMs to use at a particular location.', 'In some embodiments, the LCM identifier may select one or more selected LCMs \n546\n.', 'The selected LCMs \n546\n may then be used in a lost circulation event \n548\n.', 'The drilling operator may collect usage data \n550\n of the performance of the selected LCMs \n546\n.', 'The usage data \n550\n may include the effectiveness of the particular LCM to mitigate the lost circulation event \n548\n.', 'The LCM identifier \n542\n may be modified to a refined LCM identifier \n542\n, which may produce refined selected LCMs \n546\n to use on the next wellbore and/or lost circulation event.', 'Furthermore, when the target wellbore has been drilled, updated wellbore data \n552\n may be developed.', 'When planning the next target wellbore, the fracture model generator \n536\n may use the updated wellbore data \n552\n to produce a refined fracture model \n540\n.', 'Using both the updated wellbore data \n552\n and the usage data \n550\n of the LCM, the ML model \n534\n may be refined and produce more representative recommendations of the LCM to be used, thereby further reducing the impact of a lost circulation event.', 'FIG.', '6\n is a flowchart of a method \n656\n for planning a wellbore, according to at least one embodiment of the present disclosure.', 'The method \n656\n includes receiving geological information about a formation at \n658\n.', 'As discussed herein, the geological information may include any geological information, including survey information, seismic information, visual information (e.g., visual information obtained from borehole images, borehole scopes, and so forth), resistivity information, information about lost circulation events in the formation, and so forth.', 'Using the geological information, fracture characteristics about the formation may be identified at \n660\n.', 'The fracture characteristics may then be used to develop a fracture model of the formation at \n662\n.', 'Based at least in part on the fracture model, one or more lost circulation treatments may be identified to mitigate a lost circulation event.', 'In some embodiments, the method \n656\n may include selecting a lost circulation treatment from the identified lost circulation treatments.', 'In some embodiments, the identified lost circulation treatments may include one or more LCMs to be used in case of a lost circulation event, and selecting the lost circulation treatment may include selecting an LCM from the one or more identified LCMs.', 'This may provide the operator with selections of suitable treatments and/or LCMs, and select the best treatment or LCM for the user.', 'In some embodiments, the LCM may be selected based on a particle size of the LCM and a thickness of the fracture.', 'In some embodiments, the method \n656\n may be performed prior to drilling the wellbore, or in the wellbore planning phase.', 'This may allow the drilling operator to procure and stockpile the selected LCM before drilling.', 'If the selected LCM is on site or nearby while drilling, the impact of the lost circulation event may be reduced.', 'For example, the down time resulting from the lost circulation event may be reduced, thereby allowing drilling of the wellbore to recommence without delay.', 'In some embodiments, building the fracture model may include extrapolating the fracture characteristics between offset wellbores.', 'In some embodiments, building the fracture model may include identifying one or more risk areas or zones.', 'For example, based on the fracture properties in the fracture model, the drilling operator may identify one or more risk zones associated with the fracture properties.', 'In some embodiments, receiving the geological information includes receiving offset wellbore data of lost circulation events in the formation.\n \nFIG.', '7\n is a flowchart of a method \n766\n for planning a wellbore, according to at least one embodiment of the present disclosure.', 'The method \n766\n includes, before performing a drilling operation, building a fracture model of a formation through which a wellbore will be drilled at \n768\n.', 'The fracture model may include fracture characteristics that are extrapolated from one or more offset wellbores.', 'The fracture characteristics may be extrapolated using survey data obtained from the one or more offset wellbores.', 'In some embodiments, a target wellbore path may be identified that passes through the formation at a particular location at \n770\n.', 'In some embodiments, using the fracture model, the method \n766\n may include identifying expected fracture properties for the target wellbore path at \n772\n.', 'For example, using the location of where the target wellbore path intersects the formation and the fracture characteristics of the fracture model at the intersection location, expected fracture properties of the formation may be identified.', 'Based at least in part on the expected fracture properties, one or more LCMs may be identified for the target wellbore path at \n774\n.', 'The LCMs may be used in case of a lost circulation event.', 'The method \n766\n may further include procuring the identified one or more LCMs prior to drilling the wellbore and/or utilizing the LCMs in case of a lost circulation event.\n \nFIG.', '8\n illustrates certain components that may be included within a computer system \n819\n.', 'One or more computer systems \n819\n may be used to implement the various devices, components, and systems described herein.', 'The computer system \n819\n includes a processor \n801\n.', 'The processor \n801\n may be a general-purpose single or multi-chip microprocessor (e.g., an Advanced RISC (Reduced Instruction Set Computer) Machine (ARM)), a special purpose microprocessor (e.g., a digital signal processor (DSP)), a microcontroller, a programmable gate array, etc.', 'The processor \n801\n may be referred to as a central processing unit (CPU).', 'Although just a single processor \n801\n is shown in the computer system \n819\n of \nFIG.', '8\n, in an alternative configuration, a combination of processors (e.g., an ARM and DSP) could be used.', 'The computer system \n819\n also includes computer-readable media such as memory \n803\n in electronic communication with the processor \n801\n.', 'The memory \n803\n may be any electronic component capable of storing electronic information, and may be local or remote relative to the processor \n801\n.', 'In some embodiments, the memory \n803\n may be embodied as random access memory (RAM), read-only memory (ROM), magnetic disk storage media, optical storage media, flash memory devices in RAM, on-board memory included with the processor, erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM) memory, registers, and so forth, including combinations thereof.', 'Memory \n803\n may also be referred to as computer-readable storage media.', 'Additional or alternative types of computer-readable media may also be used.', 'For instance, communication links, carrier waves, and other types of computer-readable communication media may be used.', 'Computer-readable communication media is distinct from computer-readable storage media; however, computer-readable media may encompass and include both computer-readable storage media and computer-readable communication media.', 'Instructions \n805\n and data \n807\n may be stored in the memory \n803\n or otherwise provided by the computer-readable media for access by the processor \n801\n.', 'When accessed by the processor \n801\n, the instructions \n805\n may be executable by the processor \n801\n to implement some or all of the functionality disclosed herein.', 'Executing the instructions \n805\n may involve the use of the data \n807\n that is stored in the memory \n803\n or accessible through other computer-readable media.', 'Any of the various examples of modules and components described herein may be implemented, partially or wholly, as instructions \n805\n stored in memory \n803\n or accessible in computer-readable media and executed by the processor \n801\n.', 'Any of the various examples of data described herein may be among the data \n807\n that is stored in memory \n803\n or accessed from other computer-readable media and used during execution of the instructions \n805\n by the processor \n801\n.', 'A computer system \n819\n may also include one or more communication interfaces \n809\n for communicating with various electronic devices.', 'The communication interface(s) \n809\n may be based on wired communication technology, wireless communication technology, or both.', 'Some examples of communication interfaces \n809\n include a Universal Serial Bus (USB), an Ethernet adapter, a wireless adapter that operates in accordance with an Institute of Electrical and Electronics Engineers (IEEE) 802.11 wireless communication protocol, a BLUETOOTH® wireless communication adapter, and an infrared (IR) communication port.', 'In some embodiments, the communication interfaces \n809\n may allow a processor \n801\n to communicate with remote computer-readable media such as memory \n803\n, or with remote computing systems that include memory \n803\n or other computer-readable media.', 'A computer system \n819\n may also include one or more input devices \n811\n and one or more output devices \n813\n.', 'Some examples of input devices \n811\n include a keyboard, mouse, microphone, remote control device, button, joystick, trackball, touchpad, and lightpen.', 'Some examples of output devices \n813\n include a speaker and a printer.', 'One specific type of output device that is typically included in a computer system \n819\n is a display device \n815\n.', 'Display devices \n815\n used with embodiments disclosed herein may utilize any suitable image projection technology, such as liquid crystal display (LCD), light-emitting diode (LED), gas plasma, electroluminescence, or the like.', 'A display controller \n817\n may also be provided, for converting data \n807\n stored in the memory \n803\n into text, graphics, and/or moving images (as appropriate) shown on the display device \n815\n.', 'The various components of the computer system \n819\n may be coupled together by one or more buses, which may include a power bus, a control signal bus, a status signal bus, a data bus, etc.', 'For the sake of clarity, the various buses are illustrated in \nFIG.', '8\n as a bus system \n819\n.', 'The embodiments of the wellbore planner have been primarily described with reference to wellbore drilling operations; the wellbore planners described herein may be used in applications other than the drilling of a wellbore.', 'In other embodiments, wellbore planners according to the present disclosure may be used outside a wellbore or other downhole environment used for the exploration or production of natural resources.', 'For instance, wellbore planners of the present disclosure may be used in a borehole used for placement of utility lines.', 'Accordingly, the terms “wellbore,” “borehole” and the like should not be interpreted to limit tools, systems, assemblies, or methods of the present disclosure to any particular industry, field, or environment.', 'One or more specific embodiments of the present disclosure are described herein.', 'These described embodiments are examples of the presently disclosed techniques.', 'Additionally, in an effort to provide a concise description of these embodiments, not all features of an actual embodiment may be described in the specification.', "It should be appreciated that in the development of any such actual implementation, as in any engineering or design project, numerous embodiment-specific decisions will be made to achieve the developers' specific goals, such as compliance with system-related and business-related constraints, which may vary from one embodiment to another.", 'Moreover, it should be appreciated that such a development effort might be complex and time consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those of ordinary skill having the benefit of this disclosure.', 'Additionally, it should be understood that references to “one embodiment” or “an embodiment” of the present disclosure are not intended to be interpreted as excluding the existence of additional embodiments that also incorporate the recited features.', 'For example, any element described in relation to an embodiment herein may be combinable with any element of any other embodiment described herein.', 'Numbers, percentages, ratios, or other values stated herein are intended to include that value, and also other values that are “about” or “approximately” the stated value, as would be appreciated by one of ordinary skill in the art encompassed by embodiments of the present disclosure.', 'A stated value should therefore be interpreted broadly enough to encompass values that are at least close enough to the stated value to perform a desired function or achieve a desired result.', 'The stated values include at least the variation to be expected in a suitable manufacturing or production process, and may include values that are within 5%, within 1%, within 0.1%, or within 0.01% of a stated value.', 'A person having ordinary skill in the art should realize in view of the present disclosure that equivalent constructions do not depart from the spirit and scope of the present disclosure, and that various changes, substitutions, and alterations may be made to embodiments disclosed herein without departing from the spirit and scope of the present disclosure.', 'Equivalent constructions, including functional “means-plus-function” clauses are intended to cover the structures described herein as performing the recited function, including both structural equivalents that operate in the same manner, and equivalent structures that provide the same function.', 'It is the express intention of the applicant not to invoke means-plus-function or other functional claiming for any claim except for those in which the words ‘means for’ appear together with an associated function.', 'Each addition, deletion, and modification to the embodiments that falls within the meaning and scope of the claims is to be embraced by the claims.', 'The terms “approximately,” “about,” and “substantially” as used herein represent an amount close to the stated amount that is within standard manufacturing or process tolerances, or which still performs a desired function or achieves a desired result.', 'For example, the terms “approximately,” “about,” and “substantially” may refer to an amount that is within less than 5% of, within less than 1% of, within less than 0.1% of, and within less than 0.01% of a stated amount.', 'Further, it should be understood that any directions or reference frames in the preceding description are merely relative directions or movements.', 'For example, any references to “up” and “down” or “above” or “below” are merely descriptive of the relative position or movement of the related elements.', 'The present disclosure may be embodied in other specific forms without departing from its spirit or characteristics.', 'The described embodiments are to be considered as illustrative and not restrictive.', 'The scope of the disclosure is, therefore, indicated by the appended claims rather than by the foregoing description.', 'Changes that come within the meaning and range of equivalency of the claims are to be embraced within their scope.']

['1.', 'A method for drilling a wellbore in a formation, comprising:\ni) receiving geological information about the formation;\nii} identifying fracture characteristics in the formation using the geological information of i);\niii) building a fracture model of the formation using the fracture characteristics of ii), wherein the fracture model includes a) at least one fracture property associated with fractures in the formation and b) fracture network properties associated with a fracture network in the formation for particular geographical coordinates, wherein the fracture network properties of b) relate to fracture size, fracture density, fracture connectivity, and drilling fluid transmissibility, wherein the drilling fluid transmissibility is determined from the fracture density and the fracture connectivity; and\niv) after the building the fracture model of iii), drilling the wellbore, and, when the drilling passes through a risk zone in the formation which is at risk for lost circulation as characterized by the fracture network properties of the fracture model of iii), using lost circulation material in the drilling to mitigate a lost circulation event, wherein the lost circulation material is selected by comparing at least one fracture network property of the fracture model that is related to fracture size to physical properties of different lost circulation materials.', '2.', 'The method of claim 1, wherein the receiving the geological information includes receiving the geological information from a borehole image.', '3.', 'The method of claim 1, wherein the geological information includes at least one of seismic information or resistivity information.', '4.', 'The method of claim 3, wherein the geological information includes the resistivity information, and wherein the resistivity information includes a difference in resistivity between a fracture of the fractures in the formation and a solid formation.', '5.', 'The method of claim 1, wherein the at least one fracture property further includes at least one of a thickness, a width, a direction, a dip, or a strike.', '6.', 'The method of claim 1, wherein the at least one fracture network property of the fracture model that is related to fracture size comprise an average thickness or a thickness profile of the fracture network.', '7.', 'The method of claim 6, wherein the physical properties of different lost circulation materials include a particle size distribution.', '8.', 'The method of claim 1, further comprising procuring, prior to the drilling of iv), the selected lost circulation material.', '9.', 'The method of claim 1, wherein the building a fracture model of iii) includes extrapolating the fracture characteristics between offset wellbores.', '10.', 'The method of claim 1, wherein the receiving geological information about the formation of i) includes receiving offset wellbore data of other lost circulation events in the formation.', '11.', 'The method of claim 1, wherein the properties of various lost circulation materials include at least one of particle shape, maximum particle size, or minimum particle size.\n\n\n\n\n\n\n12.', 'The method of claim 1, wherein the selection of the lost circulation material employs a machine learning model.\n\n\n\n\n\n\n13.', 'The method of claim 1, wherein the building of the fracture model of iii) employs a machine learning model.\n\n\n\n\n\n\n14.', 'The method of claim 1, wherein the identifying of the fracture characteristics of ii) employs a machine learning model.']

['FIG.', '1 is a representation of a drilling system, according to at least one embodiment of the present disclosure;; FIG.', '2-1 is a representation of geological information used to create a fracture model, according to at least one embodiment of the present disclosure;; FIG.', '2-2 is a representation of a fracture model generated from the geological information of FIG.', '2-1;; FIG. 3 is a representation of a series of use maps, according to at least one embodiment of the present disclosure;; FIG.', '4 is a representation of a wellbore planner, according to at least one embodiment of the present disclosure;; FIG.', '5 is a representation of a machine learning model, according to at least one embodiment of the present disclosure;; FIG.', '6 is a flowchart of a method for planning a wellbore, according to at least one embodiment of the present disclosure;; FIG. 7 is a flowchart of a method for planning a wellbore, according to at least one embodiment of the present disclosure; and; FIG. 8 is a representation of a computing system, according to at least one embodiment of the present disclosure.; FIG.', '1 shows one example of a drilling system 100 for drilling an earth formation 101 to form a wellbore 102.', 'The drilling system 100 includes a drill rig 103 used to turn a downhole drilling tool assembly 104 which extends downward into the wellbore 102.', 'The downhole drilling tool assembly 104 may include a drill string 105, a bottomhole assembly (BHA) 106, and a bit 110, attached to the downhole end of drill string 105.', 'In some embodiments, the downhole drilling tool assembly 104, or elements of the downhole drilling tool assembly 104, may be configured to erode the formation.', 'For example, the bit 110, a reamer, a casing cutter, any other downhole drilling tool, and combinations thereof may be configured to erode or degrade the formation to advance the wellbore and/or make a change to a dimension or other part of the wellbore.; FIG. 4 is a representation of a wellbore planner 424, according to at least one embodiment of the present disclosure.', 'The wellbore planner 424 includes a fracture identifier 426, which may take geological information, such as from offset wellbores, and identify one or more fractures.', 'The fracture identifier 426 may identify fractures from any type of geological information, including visual information (e.g., visual information obtained from borehole images, borehole scopes, and so forth), seismic information, resistivity information, information about lost circulation events in the formation, any other type of geological information, and combinations thereof.', 'The fracture identifier 426 may identify fracture characteristics of the fractures, such as fracture thickness, width, length, dip, strike, any other fracture characteristics, and combinations thereof.; FIG.', '5 is a representation of a ML model 534 to be used by a wellbore planning system, according to at least one embodiment of the present disclosure.', 'The ML model 534 may be implemented by the wellbore planner 424 of FIG.', '4. Put another way, one or more elements of the wellbore planner 424 of FIG.', '4 may implement the ML model 534.; FIG.', '6 is a flowchart of a method 656 for planning a wellbore, according to at least one embodiment of the present disclosure.', 'The method 656 includes receiving geological information about a formation at 658.', 'As discussed herein, the geological information may include any geological information, including survey information, seismic information, visual information (e.g., visual information obtained from borehole images, borehole scopes, and so forth), resistivity information, information about lost circulation events in the formation, and so forth.', 'Using the geological information, fracture characteristics about the formation may be identified at 660.', 'The fracture characteristics may then be used to develop a fracture model of the formation at 662.', 'Based at least in part on the fracture model, one or more lost circulation treatments may be identified to mitigate a lost circulation event.; FIG. 7 is a flowchart of a method 766 for planning a wellbore, according to at least one embodiment of the present disclosure.', 'The method 766 includes, before performing a drilling operation, building a fracture model of a formation through which a wellbore will be drilled at 768.', 'The fracture model may include fracture characteristics that are extrapolated from one or more offset wellbores.', 'The fracture characteristics may be extrapolated using survey data obtained from the one or more offset wellbores.', '; FIG.', '8 illustrates certain components that may be included within a computer system 819.', 'One or more computer systems 819 may be used to implement the various devices, components, and systems described herein.']